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Text

Environ Rept,Vol 2
	ML19318B675
Person / Time
Site:	Perry
Issue date:	06/20/1980
From:	; CLEVELAND ELECTRIC ILLUMINATING CO.
To:	;
Shared Package
ML19318B667	List: ML19318B666; ML19318B668; ML19318B675;
References
	ENVR-800620-01, ENVR-800620-1, NUDOCS 8006270285
	Download: ML19318B675 (350)
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PERRY NUCLEAR POWER PLANT :

UNITS 1 & 2 hNVIRONMENTAL , @EPORT o OPERATING LICENSE STAGE i Volume 2 THE CLEVELAND ELECTRIC ILLUMINATING CO. O 8006270

CONTENTS Section Page 1.0 OBJECTIVES OF THE PROPOSED FACILITY 1.1-1 1.1 Requirement for Power 1.1-2 1.1.1 Demand Characteristics 1.1-2 1.1.1.1 CAPCO Load Forecasting 1.1-3 1.1.1.2 Load-Forecasting Techniques 1.1-3 1.1.1.3 System Peak Hour Demand, Energy, 1.1-4 and Load Factors 1.1.1.4 Load Duration Curves 1.1-4 1.1.2 Power Supply 1.1-5 1.1.2.1 Capacity Resources 1.1-5 1.1.2.2 Reserve Margin 1.1-6 ! 1.1.3 CAPCO Construction Schedule 1.1-9 REFERENCES FOR SECTION 1.1 1.1-13 (~N 1.2 Other Objectives 1.2-1 1.3 Consequences of Delay 1.3-1 1.3.1 Scope and General Considerations , 1.3-1 1.3.2 Effect of Delay on Reliability of 1.3-1 Power Supply 1.3.2.1 Dependence on Supplemental 1.3-1 Capacity Resources (DSCR) i 1.3.2.2 Capacity Mix and Percent Reserve 1.3-2 1.3.2.3 Effect of PNPP Delay on Reserves 1.3-3 l in the ECAR Region j 1.3.2.4 Conclusions on Effect of Delay on 1.3-7 Reliability 1.3.2.5 Effects of Inadequate Reserve 1.3-11 Capacity 1.3.3 Economic Cost of Delaying the PNPP 1.3-13 1.3.3.1 Introduction 1.3-13 1.3.3.2 Period of Study 1.3-14 1.3.3.3 Plant Cost Estimates 1.3-14 [} ii

4 CONTENTS (Continued) Section Pag 3 i l 1.3.3.4 Annual Fixed Charges on Investment 1.3-15 1.3.3.5 Fuel Cost 1.3-16 l I 1.3.3.6 Operation and Maintenance Excluding 1.3-17 Fuel 1.3.3.7 Summary of Economic Analysis of 1.3-17 Delaying the PNPP REFERENCES FOR SECTION 1.3 1.3-19 A.l.1 Appendix: Extract from ECAR Load Forecasting Al.1-1 I Summary-1979 { 2.0 THE SITE AND ENVIRONMENTAL INTERFACES 2.1-1 2.1 Geography and Demography 2.1-1 2.1.1 Site Location and Description 2.1-1 2.1.1.1 Specificatien of Location 2.1-1 2.1.1.2 Site Area Maps 2.1-2 (} 2.1.1.3 Boundaries for Establishing Effluent 1 Release Limits 2.1-2 2.1.2 Population Distribution 2.1-3 2.1.2.1 Population Within 10 Miles 2.1-3 2.1.2.2 Population Between 10 and 50 Miles 2.1-5 ) 2.1.2.3 Transient Population 2.1-6 2.1.3 Uses of Adjacent Lands and Waters 2.1-6 l 2.1.3.1 Use of Land Immediately Adjacent to the PNPP 2.1-6 2.1.3.2 Nearest Meat and Milk Animals, Gardens, and Residences 2.1-7

2.1.3.3 Present and Future Use of Land Within 5 Miles of the PNPP 2.1-8 2.1.3.4 Agricultural Activities 2.1-10 2.1.3.4.1 Area Within 10 Miles of the PNPP 2.1-10 2.1.3.4.2 Area Within 50 Miles of the PNPP 2.1-11

{J 2.1.3.5 Commercial and Recreational Fishing and Hunting 2.1-12 4 iii 4 a - -

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l fs CONTENTS (Continued) U Section Page 2.1.3.5.1 Commercial Fishing 2.1-12 i 2.1.3.5.2 Recreational Fishing 2.1-13 2.1.3.5.3 Hunting 2.1-14 2.1.3.6 Coordination of Plant Activities with Uses of Adjacent Lands and Water 2.1-15 2.1.3.7 Uses of Water Within 50 Miles of the PNPP 2.1-16 i 2.1.3.7.1 Water Supplies 2.1-17 2.1.3.7.2 Irrigation Uses 2.1-18 2.1.3.7.3 Recreational Uses 2.1-18 2.1.3.7.4 Transportation Uses 2.1-18 2.1.3.7.5 Wells 2.1-18 2.1.3.7.6 Regional Consumptive Uses of Water 2.1-19 REFERENCES FOR SECTION 2.1 2.1-20 C-- 2.2 ECOLOGY 2.2-1

2. 2. l' Aquatic Ecology 2.2-1 2

2.2.1.1 Water Chemistry 2.2-1 7 2.1.2 Temperature, Dissolved Oxygen, and pH 2.2-1'

2.2.1.3 Biochemical Oxygen Demand 2.2-2 2.2.1.4 Nitrate 2.2-2 2.2.1.5 Total Phosphorus 2.2-2 2.2.1.6 Solids 2.2-3 2.2.1.7 Jils 2.2-3 2.2.1.8 Turbidity 2.2-3 2.2.1.9 Bacteria 2.2-4 l

2.2.2 Terrestrial Ecology 2.2-4 l 2.2.2.1 Vegetation 2.2-4 2.2.2.2 Fauna 2.2-7 i l iv _ __._ -_. . . . _ . - , , . - ~

                                                                                              , ~ . . . ..

i CONTENTS (Continued) ) O

 \/   Section                                                   Page 2.2.2.2.1             Mammals                             2.2-7 2.2.2.2.2             Birds                               2.2-8 2.2.2.2.3             Reptiles and Amphibians             2.2-9 REFERENCES FOR SECTION 2.2                      2.2-10 2.3       METEOROLOGY                                     2.3-1

] 2.3.1 Regional Climatology 2.3-1 2.3.2 Local Meteorology 2.3-1 2.3.2.1 Wind Direction and Speed 2.3-1 2.3.2.2 Ambient Temperature 2.3-3 2.3.2.3 Atmospheric Water Vapor 2.3-4 2.3.2.4 Precipitation 2.3-5 2.3.2.5 Fog 2.3-6 2.3.2.6 Atmospheric Stability 2.3-6 2.3.3 Atmospheric Dispersion Estimates 2.3-7 REFERENCES FOR SECTION 2.3 2.3-9

s/ 2.4 HYDROLOGY 2.4-1 2.5 GEOLOGY 2.5-1 2.6 REGIONAL HISTORIC, ARCHAEOLOGICAL, ARCHITECTURAL, SCENIC, CULTURAL, AND NATURAL FEATURES 2.6-1 REFERENCES FOR SECTION 2.6 2.6-2 2.7 NOISE 2.7-1 REFERENCES FOR SECTION 2.7 2.7-3 3.0 THE STATION 3.1-1 3.1 External Appearance 3.1-1 3.2 Reactor and Steam-Electric System 3.2-1 3.2.1 Nuclear Boiler System 3.2-1 3.2.2 Steam and Power Conversion System 3.2-1 1 3.3 Plant Water Use 3.3-1 1 V

CONTENTS (Continued) O Section Page 3.4 Heat Dissipation System 3.4-1 3.4.1 Water Source 3.4-1 3.4.2 System Requirements 3.4-1 3.4.3 Heat Load 3.4-3 3.4.4 Intake and Discharge Structures 3.4-4 i REFERENCE FOR SECTION 3.4 3.4-7 3.5 Radwaste Systems and Source Terms 3.5-1 3.5.1 Source Terms 3.5-1 3.5.1.1 Primary Coolant Radic Jtivity 3.5-1 3.5.1.2 Tritium 3.5-1 3.5.1.3 Fuel Pool 3.5-1 3.5.1.3.1 Description 3.5-1 , 3.5.1.3.2 Management of Water Inventories During Refuleing 3.5-2 3.5.1.3.3 Radioactivity 3.5-4 (T 3.5.2 Liquid Radwaste Systems 3.5-5 3.5.2.1 Design Objective 3.5-5 3.5.2.2 System Description 3.5-5 3.5.2.2.1 High-Purity / Low-Conductivity Wastewater Subsystem 3.5-6 ! 3.5.2.2.2 Medium- to Low-Purity /High-Conductivity Wastewater Subsystem 3.5-6 3.5.2.2.3 Chemical Waste Subsystem 3.5-7 3.5.2.2.4 Detergent-Drain Subsystem 3.5-7 3.5.2.2.5 Collection of Spent Resins and 4 Filter /Demineralizer, and Filter Sludge 3.5-8 3.5.2.3 Operating Procedures 3.5-9 3.5.2.3.1 Operation 3.5-9

3.5.2.3.2 Discharge 3.5-9 3.5.2.4 Computation Description 3.5-10 3.5.2.5 Radioactivity Releases 3.5-15 O

vi

CONTENTS (Continued) Section Page 3.5.3 Gaseous Radwaste Systems 3.5-16 3.5.3.1 Design Objective 3.5-16 3.5.3.2 System Description and Operating Procedures 3.5-16 3.5.3.2.1 The Condenser Air-Ejector Offgas System 3.5-17 3.5.2.2.2 Plant Building Ventilation Systems 3.5-18 3.5.2.2.2.1 Reactor-Building-Complex Ventilation Systems 3.5-18 3.5.3.2.2.1.1 Annulus Exhaust Gas Treatment System 3.5-19 3.5.3.2.2.1.2 Containment Purge system 3.5-19 3.5.3.2.2.1.3 Drywell Purge System 3.5-19 3.5.3,2,2.2 Turbine Building Ventilation System 3.5-20 () 3.5.3.2.2.3 Radwaste Building Ventilation System 3.5-20 3.5.3.2.2.4 Offgas Building Ventilation System 3.5-20 3.5.3.2.2.5 Other Plant Building Ventilation Systems 3.5-20 3.5.3.3 Radioactivity Releases 3.5-21 3.5.4 Solid-Waste Disposal System 3.5-21 3.5.4.1 Design Objective 3.5-21 3.5.4.2 System Description 3.5-22 3.5.4.3 Operating Procedure 3.5-24 3.5.4.4 Expected Volumes and Activities 3.5-25 3.5.4.5 Packaging 3.5-25 3.5.4.6 Storage Facilities 3.5-26 3.5.4.7 Shipment 3.5-26 ($) vii I

CONTENTS (Continued) O Section Page 3.5.5 Process and Effluent Radiological Monitoring and Sampling Systems 3.5-26 3.5.5.1 Design Bases 3.5-27 3.5.5.1.1 Systems Required for Safety 3.5-27 3.5.5.1.2 Systems Required for Plant Operation 3.5-27 3.5.5.2 Inspection, Calibration, and Maintenance 3.5-29 3.5.5.2.1 Inspection and Tests 3.5-29 3.5.5.2.2 Calibration 3.5-30 3.5.5.2.3 Maintenance 3.5-30 3.5.5.3 Effluent Monitoring and Sampling 3.5-31 3.5.5.4 Process Monitoring and Sampling 3.5-32

,                REFERENCES FOR SECTION 3.5                    3.5-34 i

A3.5 Appendix: Data Needed for Radioactive Source

  /~'\                     Term Calculations                   A3.5-1
' U    3.6       Chemical and Biocide Waste Systems            3.6-1 3.6.1         Chemical Waste Systems                    3.6-1 3.6.1.1           Cycle-Makeup Demineralizer            3.6-1 3.6.1.2           Chemical Cleaning Wastes (Preoperational Cleaning)           3.6-2 3.6.2         Biocide Waste System                      3.6-3 i

3.7 Sanitary and Other Waste Systems 3.7-1 3.7.1 Sanitary Waste System 3.7-1 3.7.2 Other Waste Systems 3.7-2 3.7.2.1 Diesel-Generator Exhaust 3.7-2 3.7.2.2 Auxiliary Boiler Flue Gases 3.7-3 3.7.2.3 Miscellaneous 3.7-3 ! 3.8 Reporting of Radioactive Material Movement 3.8-1 l 3.9 Transmission Line Facilities 3.9-1 l REFERENCES FOR SECTION 3.9 3.9-2 , ($) viii

CONTENTS (Continued)

  %i Section                                                   Page 4.0        EN1?IRONMENTAL EFFECTS OF SITE PREPARATION, ELANT CONSTRUCTION, AND TRANSMISSION FACILITIES CONSTRUCTION                      4.1-1 5.0        ENVIRONMENTAL EFFECTS OF STATION OPERATION     5.1-1 5.1        Effects of Operation of Heat-Dissipation System                                       5.1-1 5.1.1           Effluent Limitations and Water Quality Standards                               5.1-2 5.1.141             Water Quality Limits                  5.1-2 5.1.1.2             Temperature Limits                    5.1-2 5.1.1.3             Discharge Limits                      5.1-3 5.1.1.4             Radioactive Materials                 5.1-3 5.1.2           Physical Effects                          5.1-3 5.1.2.1             Sources and Volume of Heat Influx     5.1-3
  .I) 5.1.2.2             Thermal Plume Analysis                5.1-4
  \_/

5.1.2.2.1 Plume Modeling 5.1-4 5.1.2.2.2 Model Input 5.1-5 5.1.2.3 Thermal Plume Characteristics 5.1-5 5.1.2.4 Far-Field Transport 5.1-5 5.1.3 Biological Effects 5.1-7 5.1.3.1 Impact of Intake on Fish and Ichthyoplankton 5.1-7 5.1.3.2 Impact of Discharge on Fish and Ichthyoplankton 5.1-8 5.1.4 .Ef fects of Heat-Dissipation Facilities 5.1-9 5.1.4.1 Fogging and Icing 5.1-10 5.1.4.1.1 Effects on Ground Transportation 5.1-11 5.1.4.1.2 Effects on Air Transportation 5.1-11 l 5.1.4.1.3 Effects on Water Transportation 5.1-11

'iX

CONTENTS (Continued) (O ~i . Section Page 5.1.4.2 Elevated Visible Plumes 5.1-12 5.1.4.2.1 Maximum Frequency of Elevated Visible Plumes 5.1-12 5.1.4.2.2 Occurrence of Elevated Visible Plumes at Airports 5.1-12 5.1.4.2.3 Occurrence of Elevated Visible Plumes at Surrounding Population Centers 5.1-12 5.1.4.2.4 Occurrence of Elevated Visible Plumes by Month 5.1-13 5.1.4.3 Solids Discharged from the Cooling System 5.1-13 5.1.4.3.1 Dissolved-Solids Deposition 5.1-14 5.1.4.3.2 Airborne Concentration of Dry Drift Particles 5.1-14 () 5.1.4.4 Increased Ground-Level Temperature 5.1-14 5.1.4.5 Increased Ground-Level Relative Humidity 5.1-15 5.1.4.6 Cooling-Tower Plume Behavior 5.1-15 5.1.4.7 Parametric Study of Plume Rise 5.1-17 5.1.4.8 Noise 5.1-18 5.1.4.9 Aesthetics 5.1-18 REFERENCES FOR SECTION 5.1 5.1-20 A5.1 Appendix: Mathematical Model Used for Thermal Plume Analysis A5.1-1 5.2 Radiological Impact from Routine Operation 5.2-1 5.2.1 Exposure Pathways 5.2-1 5.2.2 Radioactivity in the Environment 5.2-1 5.2.3 Dose Rate Estimates for Biota Other Than Man 5.2-3 5.2.3.1 Radiation Exposure of Terrestrial Biota 5.2-3 X l

i l CONTENTS (Continued) O Section Page 5.2.3.2 Radiation Exposure of the Aquatic Biosystem 5.2-4 5.2.4 Dose Rate Estimates for Man . 5.2-5 5.2.4.1 Liquid Pathways 5.2-6 5.2.4.2 Airborne Pathways 5.2-7 5.2.4.3 Direct Radiation from Facility 5.2-8 5.2.4.4 Annual Population Doses 5.2-9 5.2.5 Compliance with 40 CFR 190 5.2-9 REFERENCES FOR SECTION 5.2 5.2-11 5.' EFFECTS OF CHEMICAL AND BIOCIDAL DISCHARGES 5.3-1 5.3.1 System Discharges 5.3-1 5.3.1.1 Direct System Discharges to Cooling Water 5.3-1 5.3.1.2 Discharges to Cooling Water via Chemical Waste Lagoon 5.3-1 () 5.3.1.3 5.3.1.3.1 Seasonal Effect.s Dissolved Oxygen 5.3-1 5.3-2 l 5.3.1.3.2 Biochemical Oxygen Demand 5.3-2 s' 5.3.1.3.3 Dissolved Solids and Suspended l Solids 5.3-4 5.3.2 Biological Effects of Chemical and Biocidal Discharge 5.3-4 f 5.4 EFFECTS OF .lANITARY WASTE DISCHARGES - 5.4-1 5.5 EFFECTS OF OPERATION AND MAINTENANCE OF THE TRANSMISSION SYSTEM 5.5-1 3 5.6 OTHER EFFECTS 5.6-1 5.6.1 Sources of Noise During Operation 5.6-1 5.6.1.1 Natural Draft Cooling Towers 5.6-1 5.6.1.2 Transformers and Switchyard 5.6-1 5.6.1.3 Heating, Ventilating, and Air Conditioning System 5.6-2 5.6.1.4 Steam Turbines and Generator 5.6-3 () 5.6.1.5 5.6.1.6 Motors and Pumps Overall Plant Noise 5.6-3 5.6-4 xi

CONTENTS (Continued) D O Section Page 5.6.2 Operation Noise Impact 5.6-4 5.6.3 Operation Noise Mitigating Measures 5.6-5 5.6.4 Other-Than-Noise Effects 5.6-5 PEFERENCES FOR SECTION 5.6 5.6-6 5.7 RESOURCES COMMITTED 5.7-1 5.7.1 Environmental Resources 5.7-1 5.7.2 Material Resources 5.7-1 5.8 DECOMMISSIONING AND DISMANTLING 'i.8-1 REFERENCES FOR SECTION 5.8 5.8-3 5.9 THE URANIUM FUEL CYCLE 5.9-1 REFERENCES FOR SECTION 5.9 5.9-3 6.0 EFFLUENT AND ENVIRONMENTAL MEASUREMENTS AND MONITORING PROGRAMS 6.1-1 6.1 Preoperational Environmental Programs 6.1-1 6.1.1 Surface Waters 6.1-1 ( ) 6.1.2 Groundwater 6.1-1 6.1.3 Air 6.1-2 6.1.3.1 Meteorology 6.1-2 6.1.3.1.1 Offsite Data 6.1-2 6.1.3.1.2 Onsite Meteorological Measurements Program 6.1-3 6.1.3.1.2.1 System Description 6.1-3 6.1.3.1.2.2 Meteorological Data Reduction 6.1-6 6.1.3.1.2.3 Meteorological Data Recovery 6.1-7 1 6.1.3.1.3 Models 6.1-7 6.1.3.1.3.1 Realistic Accident Diffusion Esti ates 6.1-7

6.1.3.1.3.2 Long Term (Routine Release)

Diffusion Estimates 6.1-10 6.1.3.2- Cooling-Tower Effects 6.1-13 6.1.3.2.1 Induced Ground-Level Fogging 6.1-13 (} 6.1.3.2.2 Horizontal and Vertical Icing 6.1-15 xii l

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CONTENTS (Continued) Section Page 6.1.3.2.3 Elevated Visible Plumes 6.1-16 6.1.3.2.4 Drift Analysis 6.1-16 6.1.3.2.5 Detailed Plume Analysis 6.1-18 6.1.3.3 Noice 6.1-18 6.1.3.3.1 Characteristics of Sound 6.1-19 6.1.3.3.2 Regulations and Criteria 6.1-22 6.1.3.3.3 Survey Methodology 6.1-24 6.1.3.3.4 Analysis Methodology 6.1-27 6.1.4 Land 6.1-28 6.1.4.1 Geology and Soils 6.1-28 6.1.4.2 Land-Use and Demography 6.1-28 6.1.4.3 Ecological Parameters 6.1-28 6.1.5 Radiation 6.1-29 ' 6.1.5.1 Airborne 6.1-32 6.1.5.2 Direct Radiation 6.1-33 6.1.5.3 Waterborne 6.1-33 (} 6.1.5.3.1 Surface Water and Drinking Water 6.1-33 6.1.5.3.2 Groundwater 6.1-34 6.1.5.4 Sediment for Shoreline 6.1-34 6.1.5.5 Milk 6.1-34 6.1.5.6 Fish 6.1-35 6.1.5.7 Summary 6.1-35 REFERENCES FOR SECTION 6.1 6.1-36 6.2 Proposed Operation *al Monitoring Programs 6.2-1 6.2.1 Environmental Radiation Monitoring 6.2-1 6.2.2 Nonradiological Surveillance 6.2-2 REFERENCES FOR SECTION 6.2 6.2-3 6.3 Related Environmental Measurement and Monitoring Programs 6.3-1 6.4 Preoperational Environmental Radiation l Monitoring Data 6.4-1 7.0 ENVIRONMENTAL EFFECTS OF ACCIDENTS 7.1-1 (]) xiii l

CONTENTS (Continued) Section Page 7.1 Station Accidents Involving Radioactivity 7.1-1 REFERENCES FOR SECTION 7.1 7.1-3 7.2 Transportation Accidents Involving Radioactivity 7.2-1 i 7.3 Other Accidents 7.3-1 8.0 ECONOMIC AND SOCIAL EFFECTS OF PLANT OPERATION 8.1-1 8.1 Benefits 8.1-1 8 .1. .. Primary Benefits 8.1-1 8.1.2 Other Social and Economic Benefits 8.1-3 8.1.2.1 Property Tax Revenues 8.1-3 8.1.2.2 Payrolls and Employment 8.1-4 8.1.2.3 Enhancement of Environmental, Aesthetic, and Recreational () 8.1.2.4 Values, and Improvements of Roads Fuel Oil Conservation 8.1-5 8.1-5 8.2 Costs 8.2-1 8.2.1 Internal Costs 8.2-1 , 8.2.2 External Costs 8.2-2 REFERENCE FOR SECTION 8.2 8.2-4 1 9.0 ALTERNATIVE ENERGY SOURCES AND SITES 9.1-1 9.1 Alternatives Not Requiring the Creation of New Generating Capacity 9.1-1 9.1.1 Purchase of Energy Requirements 9.1-1 9.1.2 Use of Facilities Presently Within the System 9.1-1 9.1.3 Conservation 9.1-2 9.2 Alternatives Requiring the Creation of New Generating Capacity 9.2-1 O (_/ xiv

  .-    _.         . - - .                           . . _ .                          . - . - . _ - _ . - _ _ ~ _ .--

1 i CONTENTS (Concluded) } Section Page 4 9.3 Cost-Effectiveness Analysis of Candidate Site-Plant Alternatives 9.3-1 9.4 Costs of Alternative Power-Generation Methods 9.4-1 L 10.0 STATION DESIGN ALTERNATIVES 10.1-1 i 11.0

SUMMARY

COST-BENEFIT ANALYSIS 11.1-1 11.1 Introduction 11.1-1 11.2 Benefits 11.2-1 11.2.1 Direct Benefits 11.2-1 11.2.2 Indirect Benefits 11.2-1 l l 11.3 Costs 11.3-1 ! 11.3.1 Direct Costs 11.3-1

11.3.2 Indirect Costs 11.3-1 i

() 11.3.2.1 11.3.2.2 Socioeconomic Impacts Environmental Impacts 11.3-1 11.3-1 t l 11.4 Conclusion 11.4-1 12.0 ENVIRONMENTAL APPROVALS AND CONSULTATION 12.1-1 ) i 4 i 1 O XV ? - , . - -...--.,...- ,. --..,.._ -- -. - -, ._ - .-,-. --

1 TABLES

( }' Number Page 1.1-1 Sales to Ultimate Customers for 1979 1.1-14 1.1-2 Distribution of Electric Energy Sales 1.1-15 to Ultimate Customers by Class of Service for 1979 1.1-3 Annual Peak Electrical Demand for 1963 to 1.1-16 1990 1.1-4 Net Energy Supplied to Service Area for 1.1-17 l 1963 to 1990 1.1-5 Load Factors for 1963 to 1979 1.1-18 1.1-6 Annual CAPCO Load Duration Data for 1972 1.1-19 to 1979 1.1-7 Projected Generating Capacity Resources 1.1-22 1 at Time of Annual Combined Annual Peak by Year (1984 to 1988) ( 1.1-8 Jointly Committed CAPCO Generating Capacity 1.1-27 i Additions 1.1-9 Individual CAPCO Company Capacity Added or 1.1-28 Uprated (1973 to 1988) into Capacity Models for Generation Planning 1.1-10 Individual CAPCO Company Capacity Deleted 1.1-29 or Rerated (1973 to 1988) from Capacity Models for Generation Planning 1.1-11 Projection of CAPCO Dependence on Supple- 1.1-31 mental Capacity Resources with PNPP on Schedule 1.1-12 Expected Dependence on Supplemental Capacity 1.1-32 Resources in 1984 with PNPP on Schedule 1.3-1 Effect of Delay of PNPP 1 on the Supple- 1.3-20 mental Capacity Resources i O xvi ,

TABLES (Continued) Number Page 1.3-2 CAPCO Capacity Mix (1984 to 1988) as a 1.3-21 Function of PNPP Schedule 1.3-3 CAPCO System Demand and Resource 1.3-25 Capability Comparison (1968 to 1988) Showing Projected Effect of Change in PNPP Schedule 1.3-4 CAPCO System Reserve Margin (1968 to 1988) 1.3-26 Showing Projected Effect of Change in PNPP Schedule 1.3-5 CAPCO Summer Reserves (1984 to 1988) 1.3-27 Showing Effect of Change in PNPP Schedule 1.3-6 CAPCO Winter Reserves (1984 to 1989) 1.3-29 Showing Effect of Change in PNPP Schedule () 1.3-7 ECAR Region Summer Reserves (1984 to 1988) Showing Effect of Change in PNPP Schedule 1.3-31 i 1.3-8 ECAR Winter Reserves (1984 to 1989) Showing 1.3-33 Effect of Change in PNPP Schedule 1.3-9 History of CAPCO Pool Power Purchase to 1.3-35 Maintain Spinning Reserve of 3 Percent of Peak Load for January 1, 1975 to August 31, 1980 1.3-10 Summer Season Projected Peak Load, 1.3-36 Generating Capacity Resources, and Computer Summer Reserves of ECAR and Four Adjacent NERC Regions with PNPP on Schedule 1.3-11 Winter Season Project Peak Load, 1.3-37 Generating Capacity Resources, and Computed Winter Reserves of ECAR and I Four Adjacent NERC Regions with PNPP I (} on Schedule xvii

I \ l l I I TABLES (Continued) Page Number _ 1.3-38 1.3-12 Plant Cost Estimates Used in Computing Cost Delay of PNPP 1.3-39 1.3-13 Yearly Fixed Charge Rates Used in PNPP Delay Study 1.3-40 Difference in Annual PNPP Revenue Require-1.3-14 ments Between 1-Year and No-Delay Cases 1.3-41 Difference in Annual PNPP Revenue Require-1.3-15 ments Between 2-Year and No-Delay Cases 1.3-42 1.3-16 Difference in Annual PNPP Revenue Require-ments Between 3-Year and No-Delay Cases 1.3-43 1.3-17 Impact of PNPP Delay on Oil Consumption fot CAPCO Projected on a Single-System Basis 2.1-25 2.1-1 Towns and Cities Within 50 Miles of the PNPP 2.1-29 2.1-2 Major Camps and Parks Within 10 Miles of the PNPP 2.1-30 Nearest Milk and Meat Animals, Residences, 2.1-3 and Gardens 2.1-31 2.1-4 Distances to Site Boundary Points from Units 1 and 2 2.1-32 2.1-5 Milk Cows Within 5 Miles of the PNPP 2.1-33 2.1-6 Meat, Milk, and Vegetable Production Statis-tics for the Area Within 50 Miles of the PNPP 2.1-36 2.1-7 Major Shoreline Recreational Water Areas Within 50 Miles of the PNPP 2.1-38 2.1-8 Ohio Huf. ting Harvest Data for 1977-1978 2.1-39 in 1976 2.1-9 Pen:sylvania Big-Game Harvest 2.1-40 2.1-10 Lake Erie Potable Water Facilities and Intakes Within 50 Miles of the PNPP O

                                                                                                    .:viii

(} TABLES (Continued) Number Page 2.2-1 Water Chemistry, February Through December 2.2-12 Transect 1 (Composite Surface Samples) 1977 2.2-2 Water Chemistry, February Through December 2.2-13 Transect 5 (Composite Surface Samples) 1977 4 2.2-3 Water Choidistry, February Through December 2.2-14 Transect 9 (Composite Surface Samples) 1977 2.2-4 Water Quality and Bacteria in Samples from 2 2-15 Transect 5 2.2-5 Water Quality in Samples from Transect 5 2.2-16

,        2.2-6 Mean Bacteria Concentrations in Samples from            2.2-17 Transect 5 2.2-7 Mammals or Their Sign Observed at the PNPP Site         2.2-18 1972 and 1976-1978

() 2.2-8 Birds Observed at the PNPP Site, 1972 and 1976-1978 2.2-19 2.2-9 Reptiles and Amphibians Observed at the PNPP 2.2-23 Site, 1972 and 1976-1978 2.3-1 Monthly and Annual Average Wind Speed 2.3-11 for PNPP Region (Site Years and Long-Term) 2.3-2 Annual Average Wind Speeds for PNPP 2.3-12 Region 2.3-3 PNPP Area Monthly and Annual Means and Extremes 2.3-13 of Temperature for Three Site Years 2.3-4 PNPP Area Long-Term Annual Means and Extremes 2.3-14 of Temperature 2.3-5 Annual PNPP Diurnal Variations of Temperature, 2.3-15 Dew Point, Relative Humidity, and Absolute Humidity for Three Site Years 2.3-6 Monthly and Annual Means of Relative Humidity, 2.3-16 Absolut. Humidity, and Dew Point for PNPP i () Area for Three Site Years xix

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, TABLES (Continued) O Number Page 1 2.3-7 Long-Term Values of Relative Humidity, 2.3-17 Absolute Humidity, and Dew Point for PNPP Area 2.3-8 PNPP Monthly and Annual Greatest Precipitation 2.3-18 by Time Interval ror Three Site Years 2.3-9a Annual Precipitation Intensity-Duration for 2.3-19 PNPP May 1, 1972 - April 30, 1973 2.3-9b Annual Precipitation Intensity-Duration for PNPP 2.3-20 l May 1, 1973 - April 30, 1974 2.3-9c Annual Precipitation Intensity-Duration for PNPP 2.3-21 September 1, 1977 - August 31, 1978 2.3-10 PNPP Area Greatest 24-H Precipitation for Three 2.3-22 i Site Years j 2.3-11 PNPP Area Average Total Precipitation for Three 2.3-23 Site Years

2.3-12 Long-Term Total Precipitation Values for PNPP 2.3-24 Area

 .       2.3-13   PNPP Stability Class Distributions by Month           2.3-25 for Three Site Years 2.3-14   PNPP Area Annual Stability Class Distributions        2.3-26 2.3-15   PNPP Stability Distributions by Hour of Day           2.3-27

for Three Site Years 2.3-16 PNPP Stability Persistence for Three Site 2.3-28 l

Years 2.3-17 PNPP Short-Term (Accident) X/Q Values at the 2.3-29 Exclusion Area Boundary (863m) Based on Three Site Years 2.3-18 PNPP Terrain Adjustment Factors 2.3-30 2.3-19 PNPP Annual Average Site Boundary X/Q and D/Q 2.3-31 I Values for Three Site Years 2.3-20 PNPP Annual Average X/Q Values 2.3-32 (} (Undepleted) for a Ground Level Release for Three Site Years XX t

TABLES (Continued) O Number Page 2.3-21 PNPP Annual Average X/Q Values (Depleted) for 2.3-33 a Ground Level Release for Three Years 2.3-22 PNPP Annual Average D/0 Values for 2.3-34 a Ground Level Release for Three Site Years 2.3-23 PNPP Annual Average X/Q Values 2.3-35 (Undepleted) for a Ground Level Release for the Grazing Season, May-October, for Three Site Years 2.3-24 PNPP Annual Average X/Q Values 2.3-36 (Depleted) for a Ground Level Release for the Grazing Season, May-October, for Three Site Years 2.3-25 PNPP Annual Average D/Q Values 2.3-37 for a Ground Level Release for the Grazing ( Season, May-October, for Three Site Years

2.3-26 PNPP Realistic Short-Term Accident X/Q Values 2.3-38 by Sector Based on Three Site Years 2.4-1 Monthly Average Water Temperatures 2.4-3 2.4-2 Lake Erie Current Roses at the Perry Site 2.4-4 2.6-1 Historic Places in Lake County 2.6-3 2.6-2 Natural Landmarks in Lake County 2.6-4 2.7-1 Sound-Pressure Level Measurements at the PNPP 2.7-4 Site, July 19-20, 1974 2.7-2 Sound-Pressure Level Measurements at the PNPP 2.7-5 Site, November 22-23, 1974 3.3-1 Estimated System Flow Ratos per Unit 3.3-2 3.4-1 Estimated Cooling-Water Flows and Temperatures 3.4-8 3.4-2 Pumps in Pumphouses 3.4-9 3.5-1 Isotope Inventory of the PNPP Primary Coolant 3.5-35 as Calculated by the BWR-GALE Code A V XXi

TABLES (Continued) l O Number Page 3.5-2 Calculated Releases of Radioactive Materials 3.5-37 in Gaseous Effluents--PNPP Unit 1 3.5-3 Calculated Releases of Radioactive Materials 3.5-38 in Gaseous Effluents--PNPP Unit 2 3.5-4 Calculatcd Rc' eases of Radioactive Materials 3.5-39 in PNPP Liquid Effluents 3.5-5 PNPP Influent Streams 3.5-40 3.5-6 Quantities of Solid Radioactive Waste Generated 3.5-44 at the PNPP 3.5-7 Isotope Inventory of Liquid-Radwaste-Systeth 3.5-45 Sludges Delivered to the Solid-Radwaste Treatment System 3.5-8 Isotope Inventory of Chemical Waste 3.5-46 Concentrates Delivered to the Solid-

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3.5-9 Radwaste Treatment System Isotope Inventory of RWCU Filter /Demineralizer 3.5-47 Sludge, Condensate Demineralizer Resins, and Radwaste Demineralizer Resins 3.5-10 Gaseous and Airborne Process and Effluent 3.5-49 Radiation Monitor 3.5-11 Liquid Process and Effluent Radiation Monitors 3.5-51 3.5-12 Process and Effluent Radiation Monitoring 3.5-52 System Characteristics 2.5-13 Radiological Analysis Summary of Liquid 3.5-54 Process Samples 3.5-14 Padiological Analysis Summary of Gaseous 3.5-55 Process Samples 3.5-15 Radiological Analysis Summary of Liquid 3.5-56 Effluent Samples 3.5-16 Radiological Analysis Summary of Gaseous 3.5-57 Effluent Samples n Xxii

TABLES (Continued) () Number Page 3.5-17 Process Sampling System 3.5-58 3.6-1 Expected Chemical Use and Waste Flow in Cycle- 3.6-7 Makeup Demineralizer 3.6-2 Water-Quality Effect of Cycle-Makeup 3.6-8 Regeneration Waste 3.6-3 Water-Quality Effect of Chemical Cleaning 3.6-9 Waste 3.6-4 Estimated Biocide and Chemical Use in Cooling 3.6-10 Water and Cooling-Water Discharge 3.6-5 Water-Quality Effect of Biocide and Chemical 3.6-11 Use in Cooling-Waters and Cooling-Water Discharge 3.7-1 Estimated Concentration of Raw and Treated 3.7-4 Sanitary Waste i n ( ). . 5.1-1 Design Parameters for the PNPP Natural 5.1-22 Draft Cooling-Towers Analyses 5.1-2 Water Quality Limits for Lake Erie 5.1-23 5.1-3 Temperature Limits for Lake Erie 5.1-26 5.1-4 Monthly Average Water Loss, Blowdown, and 5.1-27 Makeup for Each of the Two PNPP Natural Draft Cooling Towers 5.1-5 Lake Temperatures, Plant Blowdown Water 5.1-28 Flows, and Temperatures for Units 1 and 2 5.1-6 Spring Average Dilution Factors for Lake 5.1-29 Water Intakes Within 50 Miles of PNPP 5.1-7 Summer Average Dilution Factors for Lake 5.1-30 Water Intakes Within 50 Miles of PNPP 5.1-8 Fall Average Dilution Factors for Lake 5.1-31 Water Intakes Within 50 Miles of PNPP 5.1-9 Winter Average Dilution Factors for Lake 5.1-32 Water Intakes Within 50 Miles of PNPP (j 5.1-10 Annual Average Dilution Factors for Lake 5.1-33 Water Intakes Within 50 Miles of PNPP xxiii

TABLES (Continued) Number Page 5.1-11 Swim Speeds of Some Lake Erie Central Basin 5.1-34 Fish Species 5.1-12 Major Roadways, Commercial Shipping Ports, 5.1-35 Lakes, and Rivers in the Vicinity of the PNPP Site 5.1-13 Airports and Population Centers in the 5.1-36 Vicinity of the PNPP Site 5.1-14 Maximum Monthly Frequencies of Visible Plumes 5.1-37 Longer than 0.25 Mile 5.2-1 Estimated Acute Exposures Required to Affect 5.2-13 Dominants of Major North American Vegetation 5.2-2 Maximum Dose to an Individual Due to the Release 5.2-15 of Liquid Radioactive Effluents from Both Units of PNPP 5.2-3 Fifty-Mile Population Dose Due to the Release 5.2-16 (} of Liquid Radioactive Effluents from Both Units of PNPP 5.2-4 Maximum Dose Received by an Individual from 5.2-17 the Release of Iodine and Farticulates from Both Units of the PNPP 5.2-5 Integrated Dose Received by the Population 5.2-18 Within 50 Miles of the PNPP from Gaseous Emissions 5.2-6 Dose Results Showing Compliance with 40 CFR 190 5.2-19 5.6-1 Equipment and Sound-Power-Level Spectra Modeled 5.6-8 in Operation-Noise Impact Analysis 5.7-1 Material Expenditures over the Life of the PNPP 5.7-2 6.1-1 PNPP Meteorological System Equipment 6.1-40 Specifications ('h

\-)

xxiv

f TABLES (Concluded) Number Page 6.1-2 Meteorological Data Recovery at the PNPP 6.1-42 6.1-3 PNPP Preoperational Environmental Radiological 6.1-44 Monitoring Program 7.1-1 Summary of Doses Due to Accidents 7.1-4 8.1-1 CAPCO (Combined) Generation and Revenue 8.1-6 Forecast by Customer Class (1984 to 1988) 8.1-2 CAPCO (by Company) Sales Forecast by Customer 8.1-7 Class (1984 to 1988) 8.1-3 PNPP Generation and Revenue Forecast by 0.1-9 Customer Class (1984 to 1988) 8.1-4 Annual Benefits from PNPP Units 1 and 2 8.1-10 1 8.1-5 Estimated Real and Personal Property Taxes 8.1-11 for PNPP (} 8.2-1 PNPP Internal Costs Over 30-Year Operational 8.2-5 Life 11.3-1 Predicted Impacts of PNPP Operation on the 11.3-2 Environment , .l i l 1 xxv l

{} FIGURES Number Page 1.1-1 CAPCO Annual Load Duration Curves 1.1-33 1.3-1 Map of National Electric Reliability Council 1.1-44 (NERC) 1.3-2 Annual Cost of Delay of PNPP Compared to 1.1-45 Base (No Delay) Case 2.1-3 General Area Map 2.1-42 2.1-2 Area Topography Within 5 Mile Radius 2.1-43 2.1-3 Topography Within the Plant Site Boundary 2.1-44 2.1-4 Plant Site Aerial Photograph 2.1-45 2.1-5 Acquisition of Land and Mineral Rights 2.1-46 2.1-6 Area within 10 Miles of PNPP 2.1-47 2.1-7 Area Within 50 Miles of PNPP 2.1-48

  / 2.1-8  1978 Permanent Resident "opulation                                 2.1-49 V)  2.1-9  1980 Permanent Ri    3nt P;pulation                                2.1-50 2.1-10 1983 Permanent Resident Populatic,                                 2.1-51 2.1-11 1984 Permanent Resident Population                                 2.1-52 1

2.1-12 1985 Permanent Resident Population 2.1-53 2.1-13 1986 Permanent Resident Population 2.1-54

!     2.1-14 1990 Permanent Resident Population                                 2.1-55

, 2.1-15 2000 Permanent Resident Population 2.1-56 2.1-16 2010 Permanent Resident Population 2.1-57 2.1-17 2020 Permanent Resident Population 2.1-58 2.1-18 Existing Land Use in Nearby Environs 2.1-59 j 2.1-19 Existing Land Use Within 5 Miles 2.1-60 2.1-20 Projected Land Used Within 5 Miles 2.1-61 2.1-21 Intakes and Shoreline Recreation Areas Within 2.1-62 50 Miles of PNPP (I XXVi

FIGURES (Continued) O Number Page 2.2-1 Transccts for Aquatic Surveys 2.2-24 2.2-2 Vegetation Map 1978 2.2-25 2.2-3 Location of Crane-Fly Orchid Population, 1978 2.2-26 2.2-4 Raptor Survey, 1978 2.2-27 2.3-1 Plant Site and Meteorological Tower Location 2.3-48 2.3-2 January to April Monthly Wind Roses for 2.3-49 the Perry Site-10m and 60m Lt is 2.3-3 May to August Monthly Wind Roses for the 2.3-50 Perry Site-10m and 60m Levels 2.3-4 September to December Monthly Wind Roses for 2.3-51 the Perry Site-10m and 60m Levels 2.3-5 Annual Wind Roses for the Perry Site 2.3-52 (10m and 60m Levels) 3-Yr. Combined 2.3-6 Cleveland and Erie Annual Wind Roses 2.3-53 2.3-7 Wind Direction Persistence Probability for 2.3-54 One 22 Sector for PNPP Region ( 2.3-8 Offsite and Onsite Maximum Directional 2.3-55 Wind Persistence Roses 2.3-9 January to April Monthly Precipitation Wind 2.3-56 Roses for the Perry Site (10m) 2.3-10 May to August Monthly Precipitation Wind 2.3-57 Roses for the Perry Site (10m) 2 . ? -1,1 September to December Monthly Precipitation 2.3-58 Wind Roses for the Perry Site (10m) 2.3-12 Annual Precipitation Wind Rose for the 2.3-59 Perry Site (10m) 2.7-1 Background Soun3 Level Survey Sampling 2.7-6 Points 2.7-2 Summer Daytime Background L 50 S und Level . ' -7 Isopleths 2.7-3 Summer Nighttime Background L 50 Sound 2.7-8 Level Isopleths xxvii l _ __. _ _ . _ . _ _ _ _ _ - _ - _ , - _

FIGURES (Continued) O Number Page 2.7-4 Winter Daytime Background L 50 S und 2.7-9 Level Isopleths 2.7-5 Winter Nighttime Background L 50 S und 2.7-10 Level Isopleths 3.1-1 Architectural Renderings of the PNPP 3.1-3 3.1-2 Plot Plan 3.1-4 3.1-3 Plant Area 3.1-5 3.1-4 Vertical Cross-Section of PNPP 3.1-6 3.1-5 Vertical Cross-Section of PNPP 3.1-7 3.2-1 Operating Conditions of the Boiling Water 3.2-3 Reactor 3.3-1 Plant Water Use 3.3-3 3.4-1 Offshore Intake and Eischarge Structures 3.4-10 3.5-1 Liquid Radwaste Treatm'nt System Flow Diagram 3.5-61 ( 3.5-2 Summary of Process Flow ?aths for Estimating 3.5-62

Annual Radwaste Liquid Releases 1 3.5-3 Condenser Offgas Low-Temperature Rechar 3.5-63 System Flow Diagram ] j 3.5-4 Gaseous Radwaste System Flow Diagram 3.5-64 l 3.5-5 Solid-Waste Disposal System Flow Diagram 3.5-65 j 3.5-6 Plant Radiation Monitoring System: Containment 3.5-66

!               Ventilation Exhaust and Main Steamline Radiation Monitoring Subsystems 3.5-7   Liquid Pfocess Streams                                 3.5-67 3.6-1   Nonradioactive Chemical Waste Discharge                3.6-12 Systems 3.9-1   Vicinity Map                                           3.9-3 3.9-2  -Modification in Project 1 Route                        3.9-4 5.1-1   Performance Curves for Exit Air Flow Rate              5.1-38  I vs Wet-Bulb Temperature and Relative Humidity

(} i l xxviii

FIGURES (Continued) Number Page 5.1-2 Performance Curves for Effluent Air Tempera- 5.1-39 tures vs Wet-Bulb Temperature and Relative numidity 5.1-3 Horizontal Temperature Profile at the 5.1-40 Confining Boundary, Spring Conditions 5.1-4 Horizontal Temperature Profile at the 5.1-41 Confining Boundary, Summer Conditions 5.1-5 Horizontal Temperature Profile at the 5.1-42 Confining Boundary, Fall Conditions 5.1-6 Horizontal Temperature Profile at the 5.1-43 Confining Boundary, Winter Conditions 5.1-7 Predicted Temperature Profiles, Vertical 5.1-44 Cross-Section, Spring Conditions 5.1-8 Predicted Temperature Profiles, Vertical 5.1-45 Cross-Section, Sumner Conditions 4 5.1-9 Predicted Temperature Profiles, Vertical 5.1-46

Cross-Sectica, Fall Conditions 5.1-10 Predicted Temper ature Profiles, Vertical 5.1-47 Cross-Section, Winter Conditions 5.1-11 Predicted Temperature and Velocity Profiles 5.1-48 Within 120 Feet of Discharge Point, Vertical Cross-Section, Spring Conditions 5.1-12 Predicted Temperature and Velocity Profiles 5.1-49 Within 120 Feet of Discharge Point,. Vertical Cross-Section, Summer Conditions 5.1-13 Predicted Temperature and Velocity Profiles 5.1-50 Within 120 Feet of Discharge Point, Vertical Cross-Section, Fall Conditions 5.1-14 Predicted Temperature and Velocity Profiles 5.1-5~ Within 120 Feet of Discharge Point, Vertical Cross-Section, Winter Conditions 5.1-15 Annual Frequency of Occurrence- of Elevated 5.1-52 (~T Visible Plumes V xxix

FIGURES (Concluded) O Number Page 5.1-16 Annual Ground Deposition of Dissolved 5.1-53 Solids in Circulating Cooling Water 5.1-17 Plume Parameter Variations, Average Winter 5.1-54 Morning Conditions 5 .1-l 'J Plume Parameter Variations, Average Summer 5.1-55 Morning Conditions 5.1-19 Excess Relative Humidity, Average Winter 5.1-56 Morning Conditions 5.1-20 Excess Relative Humidity, Average Summer 5.1-57 Morning Conditions 5.1-21 Variation of Cooling-Tower Plume Height With 5.1-58 Ambient Vertical Temperature Gradient (Stability) 5.1-22 Variations of Cooling-Tower Plume Height 5.1-59 with Tower Top Wind Speed 5.2-1 Generalized Exposure Pathways for Organisms 5.2-20

/)

Other Than Man 1 5.2-2 Generalized Exposure Pathways for Man 5.2-21 5.6-1 Operational Sound Levels for the PNPP 5.6-9 6.1-1 Groundwater Contour and Well Location Map 6.1-47 6.1-2 PNPP Preoperational Environmental Radiological 6.1-48 Monitoring Program Sampling Locations Within 5 Miles of Site

;    6.1-3     PNPP Preoperational Environmental Radiological    6.1-49 l                Monitoring Program Sampling Locations >5 Miles From Site i

(a i p I xxX

CHAPTER 3

}                           THE STATION This chapter is essentially unchanged from that presented in the ER/CP except for those systems and effluents that have been modified by the use of natural-draf t cooling towers instead of once-through cooling. Unchanged portions of.the plant description have been included to provide a context for the description of the new cooling system and to provide a ready reference within the ER/OL when evaluating plant impacts.

3.1 EXTERNAL APPEARANCE The external appearance differs from that described in the ER/CP because of the design change from once-through cooling to cooling by two 515-foot-tall natural-draft hyperbolic cooling towers. The building complex of the Perry Nuclear Power Plant rests on a plateau approximately 50 feet above Lake Erie. Mature growths of trees about 50 feet high visually shield much of the site from both the lake and U.S. Route 20. The architectural treatment defines and emphasizes the func-tional logic of the major structures and imparts an aesthetic quality to the complex. The clean and crisp geometric lines articulating the facades are created by a contrasting, yet unifying, relationship of metal, glass, and concrete. The smooth hyperbolic contours of the two concrete cooling towers dominate the site.

1 The original landscape will be preserved as much as practicable. New open areas will be seeded, and new shrubs and trees will be planted to accent, define, or separate the landscape. O l 3.1-1 1

Two architectural renderings, a view from the lake and a view {) from the approach road, are shown in Figure 3.1-1. A plot plan of the site area showing the layout of buildings, locations and elevations of effluent release points, exclusion area boundaries, and site boundaries is presented in Figure

3.1-2. A plan view of the immediate plant area is shown in Figure 3.1-3; elevation sections of Figure 3.1-3 are shown as Figures 3.1-4 and 3.1-5.

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3.2 REACTOR AND STEAM-ELECTRIC SYSTEM The reactor and steam-electric system is essentially the same as described in the 7:P CP. f The PNPP is a two-unit plant. Both Unit 1 and Unit 2 have a boiling-water-reactor nuclear steam-supply system (NSSS) and a steam-driven turbine generator. The plant, including the reactor containment, is designed by Gilbert Associates, Inc., of Reading, Pennsylvania. 3.2.1 NUCLEAR BOILER SYSTEM The nuclear boilers are designed and supplied by the General Electric Company and are of the BWR/6 type. The fuel is uranium dioxide with an average uranium-235 enrichment of approximately 1.9 percent; the fuel rods are clad with Zircaloy 2 tubing. g Some rods contain small percentages of gadolinium oxide (Gd 0 ) 23 'l mixed with uranium dioxide as a burnable poison. The initial fuel loading contains 341,640 pounds of uranium per unit. The rated core thermal power of each unit is 3579 MWt, and the design power is 3758 MWt. The reactor complex is of the Mark III design, with a free-standing steel containment surrounded by a concrete shield building. A schematic diagram and table of operating conditions are shown in Figure 3.2-1. 3.2.2 STEAM AND POWER CONVERSION SYSTEM The steam and power-conversion system for the PNPP consists of two similar syste.ms, one per nuclear boiler system, each rated at a gross electrical output of 1300 MWe and an estimated net output of 1205 MWe. An 1800-rpm, six-flow, tandem compound reheat turbine with 43-inch last-stage blades will drive a 1,446,700-kVA, 1800-rpm, direct-connected, 22,000-volt, three-phase, 60-Hz, conductor-cooled synchronous generator. Equipment O 3.2-1 l
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'l the power-conversion system. Main steam from the nuclear boiler system flows to the main turbine generator through four main-steam lines. Steam is diverted from the main steam for reheating purposes, for the generation of nonradioactive seal steam for offgas system preheating, for the reactor-feed-pump turbines during startup, and for the steam-jet air ejectors. Main steam enters the high-pressure turbine, flows through the blade paths, and exhausts to the moisture-separator reheaters, where moisture is removed and the steam is superheated. Steam then enters the three low-pressure turbines, flows through the blade paths, and exhausts to the three shells of the condenser. Steam is extracted at six points in the main turbine cycfa for regenerative feedwater heating, for driving the reactor-feed-pump turbines, and for the seal steam evaporator during Os N- normal operation. Extraction steam is also used for plant heating. Water for condensing the stear. in the condenser is continuously recirculated by three circulating-water pumps through a natural-draft cooling tower as described in Section 3.4. A turbine-bypass system capable of bypassing a portion of the main steam flow directly to the condenser is provided for startup and load-changing operation. O 3.2-2
PR ESSURE FLOW TEMPERATURE ENTHALPY (psia) (ib/hr) (* F) (Bru/lb) 6 1.COREINLET 1075 104.0 x 10 533 527.7 6 (,/ 2. CORE OUTLET 1050 104.0 x 10 551 645.0 6
3. SEPAR ATOR OUTLET (STEAM DOME) 1040 15.4 x 10 549 1190.8 6

4. STEAM LINE (2ND ISOLATION VALVE) 985 15.4 x 10 543 1190.8 6

5. FEEDWATER INLET (INCLUDES 1065 15.5 x 10 420 397.8 RETURN FLOW) 6

6. RECIRC PUMP SUCTION 1040 31.7 x 10 533 527.5 0

7. RECIRC PUMP DISCHARGE 1296 31.7 x 10 534 528.6
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l l 3.3 PLANT WATER USE ! Plant water use is changed from that described in the ER/CP because of the change in the cooling system. Water use during the average full-load operation of PNPP Units 1 and 2 is shown in Figure 3.3-1. A tabulation of water use (per unit) for full-load and other conditions is presented in Table 3.3-1.
All water required for plant operation will be drawn from j Lake Erie. Much of the water will be returned to the lake, including blowdown from the cooling towers, diluted with the service water discharge. Potable water is obtained directly from the Ohio Water Service Company water main, which is ex-tended onto the plant site.
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, ESTIMATED SYSTEM FLOW RATES PER UNIT Flow Rate (gpm) Full-Power Minimum Power Shutdown Item Operation Operation Condition Condenser cooling 545,400 545,400 -- Service water 35,000 10,400 8,000 Emergency service water 0 0 21,800 i Cycle makeup (a) (a) (a) Radwaste (a) (a) (a) Industrial waste (a) (a) (a) Potable water (a) (a) (a) (a) Flow is dependent on the functional requirements of the system. O t 1
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% 200 GPM (21 h CYCLE MAKEUP DEMINERALIZER R ADw AST E 150 GPM g,) 10 GPM (t) /\
REGENERATION WASTE NEUT. SLUDGE i. AGOONS TANK 17,182 GPD a) I _ ClTY WATER LAGOONSLUDGE' TRUCKED OFFSITE FIRE WATER 8.000 GPD 8,000 GPD ROOF DRAIN 5 YARD DRAINS (S) (H MAXIMUM DISCHARGE RATE 200 GPM (4) 3.000 GPM WMEN USED (7) MAXIMUM FLOW RATE 300 GPM MINIMUM DISCHARGE RATE O I GPM AVERAGE FLOW RATE 150 GPM (2) MAXlRIUM SMTAKE 400 GPM PER HOUR AVERAGE IMTAKE 200 GPM (3) MAXIMUM FLOW 34,364 GPD (4 AVERAGE MAKEUP RATE 41.750 GPM PLANT WATER USE AVERAGE SLOWDOWN RATE 14.540 GPM Avf eAG: now i7.ie: Geo PERRY NUCLEAR POWER PLANT 1 & 2 THE CLEVELAND ELECTRIC ILLUMINATING COMPANY FIGURE 3.3-1
3.4 HEAT DISSIPATION SYSTEM
)
This raction is revised from the corresponding section in the ER/CP in accordance with the present design of cooling via natural-draft cooling towers. 3.4.1 WATER SOURCE Lake Erie will be the source of all water for the PNPP, except for potable water. In addition, the lake will be used to dissipate heat from the emergency service-water system and the service-water system. The atmosphere will be used to dissipate heat from the circulating-water system. As indicated in Figure 3.3-1, approximately 70,000 gallons per minute (155 cubic feet per second) will be withdrawn from the lake under normal operation. In the plant, the water will be used for a variety of purposes. Approximately 65 percent of the with-drawn water will then be returned to the lake, the balance being evaporated in the cooling towers. 3.4.2 SYSTEM REQUIREMENTS The cooling requirements are broken down into three major systems: the circulating-water system, the service-water system, and the emergency service-water system. All of the normal plant inflow will be heated 15 F in passing through the service-water system. Normally the emergency service-water system is not needed. Makeup to the cooling towers will be from the service-water system discharge. The circulating-water system for each unit removes 8.3 x 10 9 Btu per hour of nonrecoverable heat from the main condensers and reactor-feed-pump turbine condensers and dissipates this heat to the atmosphere through che cooling towers. The circu-lating-water system is a closed-loop cooling-water system 3.4-1
with makeup to replace evaporation losses and blowdown to {} limit solids concentrations. There is one hyperbolic natural draft cooling tower for each unit. Each cooling tower is designed to cool 545,400 gallons per minute from 124.6 to 94.0 F when the atmospheric wet-bulb temperature is 76 P. The maximum drift loss is 0.01 percent of the water flow rate. The cooling-tower blowdown is mixed with the service-water discharge before it reaches the discharge-tunnel entrance. Each cooling tower is 514 feet high and 395 feet in diameter at the basin. The cold-water basin has a storage capacity of 2.7 million gallons. The orientation of the towers on the site is shown in Figure 3.1-2. The service-water system provides water for the turbine-building cooling requirements and for the non-safety-related nuclear cooling requirements. Specifically, this system takes heat from the nuclear closed-cooling-system heat exchangers, the turbine-building closed-coolin9-system heat exchangers, and (~'i the turbine lubricating-oil heat exchangers. The nuclear
'~') closed-cooling system picks up heat from the various heat loads in the nuclear area, including the fuel-pool heat exchangers, control complex chillers, evaporator condensers, containment chillers, nonregenerative heat exchangers, etc., and transfers this heat to the service-water system. The turbine-building closed cooling system picks up heat from the various heat loads in the turbine building, and from the balance-of-plant equipment, including the hydrogen coolers, the generator stator coolers, the exciter coolers, compressor intercoolers and aftercoolers, the electrohydraulic control coolers, etc.,
and transf er s this heat to the service-water system. These closed systema are constant-temperature systems in which the service-water system flow is modulated to maintain this constant temper ature . The emergency service-water system consists of two independent
~~loops per unit. Each loop consists of a residual-heat-removal pJ ;~~
3.4-2
(RHR) heat exchanger, a diesel-generator heat exchanger, and j an emergency closed-cooling heat exchanger. The system is l (]) required for the plant conditions of hot standby, shutdown, ar.d post-accident. In all cases, the major heat load dissi.ated ! to the emergency service-water comes from the RHR heat exchanger. 3.4.3 HEAT LOAD The temperature of the water discharged from the plant will vary, as shown in Table 3.4-1, due to changes in atmospheric conditions and intake lake water temperatures.III This table takes into account the effect of cooling-tower evaporation and blowdown on the plant discharge. Because cooling-tower evaporation and blowdown are aff ected by the atmospheric wet-bulb temperature, the unit overflow and temperature will vary accordingly. Although safety-related systems are designed to remove all decay heat after a reactor scram, normally the circulating-(} water pumps continue to run efter a reactor scram, without any change in operation. It is mandatory that they continue to operate until the reactor has been partially depressurized to allow the turbine bypass system to operate. After depressuri-zation, they may or may not be turned off, depending on the predicted length of unit outage. Normally, at least one pump would be left running throughout the outage unless work is required on equipment that would require shutdown of the circu-lating-water system. The time to shut down the plant under normal circumstances will be approximately 6 hours. The number and flow capacity of the pumps for these cooling-water systems are shown in Table 3.4-2. Required flows and expected heat loads for normal operation are shown in Table 3.4-1. O 3.4-3
3.4.4 INTAKE AND DISCHARGE STRUCTURES O# To minimize the environmental impact of the cooling system, the facilities for withdrawal and return of cooling water are located near the lake bottom, more than one-quarter of a mile off the shore. Excavated tunnels for conveying the flow allow the nearshore littoral drift to continue unimpeded, and provision for at least 12 feet of clearance from the Lake Erie low water datum (LWD-USGS) to the submerged structure ensures that there will be no hindrance to local navigation. The structures are about 1.8 statute miles from charted shipping lanes. Figure 3.4-1 shows the design of the intake and discharge structures. The two submerged intake structures are located in 21 feet of water (LWD-USGS), approximately 2550 feet off the shore. The intake structures have an impermeable roof and vertical (~'}
\/ inflow ports around the periphery. Inflow to the ports is expected to be predominantly horizontal, except in the zones near the top and bottom of the port openings, where the stream lines will have a more vertical orientation.
The diameter of each intake structure is 36 feet to provide a velocity of approach to the structures of less than 0.5 foot per second. Inflo" will be through eight ports around the perira' nr of each ci;cular structure. The ports, each
~~3. 62 f eet rag?. by 12 feet wide, are located 3 feet above the lake bottom.~~
Because floating debris is not expected to enter the intakes, trash racks or bar screens are not planned for the intake openings. However, insert channels have been constructed around each port to accommodate trash racks, should they be i G 3.4-4 l
required in the future. Debris entering the intake tunnel will be remcred by traveling screens in the pumphouse forebays. ({} Blockage of the water intake would be detected by level alarms in the service-water pumphouse and the emergency service-water pumphouse. At a predetermined minimum level, the plant would be shut down. Investigation of the problem and clearing of the intake would be accomplished by divers and barge-mounted removal equipment. The maximum velocity in the 10-foot-diameter intake tunnel will be 2 feet per second. In the service-water pumphouse, four 23,500-gpm pumps (one on standby) will be installed for the service-water system. The safety-class emergency service-water pumphouse will contain three 11,500-gpm pumps per unit. Flow in both pumphouses will pass through small-mesh traveling screens sized at an approach velocity of 0.5 foot per second or less (with all screens operating). Two traveling screens are provided in the emergency service-water pumphouse, each
\_
approximately 6 feet wide by 49 feet high, with a 3/8-inch mesh screen. The service-water pumphouse has two traveling screens, each approximately 8 feet wide by 37 feet high, with a 3/8-inch mesh screen. Each circulating-water pumphouse contains three 185,000-gpm pumps with two fixed screens pro-tecting the pumps from any debris that might fall into the cooling-tower basins. Normal outflow from all systems shown in Figure 3.3-1 (with the exception of roof and yard drains, which will be discharged to one of three sediment control dams located northeast and northwest of the plant, and the sanitary sewage treatment plant effluent, which will be discharged directly to the lake east of the barge-unloading slip) will be discharged to a common discharge tunnel entrance structure and be conveyed at approximately 1.4 feet per second through the 10-foot-diameter (7 discharge tunnel to the discharge nozzle. It will be discharged wJ l 3.4-5
~~l. __~~
t from the diffuser nozzle at a maximum velocity of 35 feet per second. The discharge structure is located in about 19 (} feet of water (LWD-USGS), 1650 feet off the shore. The jet diffuser provides a rapid temperature gradient and thus mini-mizes the thermally affected volume. No biocide treatment will be used in cleaning the main condensers. A mechanical cleaning (AMERTAP) system will be installed to keep the tubes clean. As described in Section 3.6.2, biocide (sodium hypochlorite)
~~) treatment will be used periodically to control algae and plant growth in the service-water system and cooling-towers.~~
l 1 l l () 3.4-6
l' i ! ! F Q REFERENCE FOR SECTION 3.4 l i j 1. Singley, Wayne G., Near-Shore Water Temperatures and Currents in Lake Erie, NUS-1183, NUS Corporation, May 1974. t ) i i f i iO
~~! I 1~~
~~l 1~~
~~1 4~~
f t ! l 1 l I ! 3.4-7 I .
TABLE 3.4-1 ESTIMATED COOLING WATER FLOWS AND TEMPERATURES FOR PNPP UNITS 1 AND 2 (NORMAL OPERATION - MONTHLY OR SEMI-MONTHLY AVERAGES) (a,b) Discharge Discharge Discharge Water Inlet Lake Water Water Temperature Water Temp. Intake Water Flow Temp. Rise Time Period (OF) Flow (gpm) (gpm) (OF) (OF) Jan. 35 69,400 49,600 55.3 20.3 Feb. 34 69,400 50,400 53.6 19.6 Mar. (1-15) 36 69,400 48,000 57.6 21.6 Mar. (16-31) 39 69,400 48,000 59.7 20.7 Apr. (1-15) 41 69,400 46,400 62.1 21.1 Apr. (16-30) 45 69,400 46,400 64.8 19.8 May (1-15) 52 69,400 45,000 71.3 19.3 May (16-31) 51 69,400 45,000 71.9 20.9 June (1-15) 64 69,400 43,800 81.7 17.7 June (16-30) 70 69,400 43,800 85.4 15.4 July 71 69,400 43,000 86.0 15.0 Aug. 74 69,400 43,000 87.8 13.8 Sept. (1-15) 73 69,400 43,600 87.2 14.2 Sept. (16-30) 67 69,400 43,600 83.6 16.6 Oct. (1-15) 65 69,400 45,400 80.2 15.2 s Oct. (16-31) 57 69,400 45,400 74.9 17.9 ('~')s Nov. Dec. 47 38 69,400 69,400 47,000 49,000 65.1 58.0 18.1 20.0 (a) Based on three years of site meteorological data, as described in Section 2.3. (b) Water temperatures based on data presented in Reference 1. i
3.4-8

j. TABLE 3.4-2 PUMPS IN PUMPHOUSES (Total for Tro Units)
Circulating-water pumphouse Number of pumps Installed 6 (b) For normal operation 6 (b) Capacity, gpm each Design 185,000 Required (a) 176,300 j Service-water pumphouse i Number of pumps l Installed 4 For normal operation 3 Capacity, gpm each Design 23,500 Operating 23,500 Emergency service-water pumphouse Number of pumps Installed 3 O For normal operation Capacity, gpm each Design 11,500 0 Operating 10,900 (a) Design flow for condenser performance. (b)Each unit served by three pumps. 1
~~.O 3.4-9 i~~
6'O.D. OR 7 'O.D. ICE PROTECTION CAISSON l (10 REQ'O PER STRUCTURE)
//
l i l % o [ , , a Re 33*
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~~(N.T.S.) /~~
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,_ \ iO' Dia ANGLE #7 / U STIFFENERS \
j I - (TY P) \ k' ' ~. f___._____ _ _ _ _ _ . _ _ _ _ _ _ _ l 36* (TYP.) l s hl 9'A
~~'d, x j PLAN INTAKE STRUCTURE (TYPICAL OF TWO)~~
STRUCTURE NO.I EL. 556.8 STRUCTURE NO.1 STRUCTURE NO.2 EL.557.8 _ T'-O" DI A ; STRUCTURE NO.2 TOP PLATE OPENING ((VELOCITY CAP _) l k '7'$I STL~ ili l 'il' Il I ! ij i t t i}i i l l t PIPE GUSSETSh
~~ANGLE " l ll 8~~
, I CASING ! 's STIFFENERS I
, , l l , u u u , G U , I l l I l CONCRETE -- COUNTERWEIGHT' L l 5 18 d l, l i s' 7Nr f I '
~~, CONCRETE q I?\ ,.~~
~~sh . s gu 3~~
~~. l_______j "% E Mil !~~
~~t d AI il 2'- o' l~~
% , i eh .d MW h #12 2'-e il f r W 9 l l 17mp;ux i- u. s pg avF@ LCONI
~~! $ l 1 i < "4 DW L ' S MAT.~~
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l{ g o l i r l REINF. CONC. CAISSON ,6'-O DI A _ j - N 1 l s 3 12'- 0" 1. D.
~~" l l _~~
l______J SECTION A-A INTAKE STRUCTURE (TYPICAL OF TWO)
( 6'-O"NA. DISCHARGE RISER SHAFT COORDINATES *4 BARS @ l*- 6" N 783,204A3 ' E 2,368.802.34 A .Q. ' y m / s, #4 BARS @ l'-6" g
/ \ / g / '4 y * 'O' \ / r,~ -
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s / g \ IO BARS EQUALLY SPACE D g #10 BARS EOUALLY SPACED 'p -d,'
~~30'~~
. ._ s / L -------- * ' , ,_ , i %e.. #4 BARS @ l'-6" '.. .T 5/8" STEEL PL ATE ,, p DISCHARGE STRUCTURE th0" DIA. DISCHARGE RISER SHAFT PLAN DISCHARGE STRUCTURE 8 ALTERNATE EMERGENCY SERVICE WATER INTAKE g LOW WATER DATUM EL. 570.5 (U.S.G.S.)
~~j. . wA=n --~~
% *-# ( DISCHARGE STRUCTURE 12'- 2 1/2"q (TYP) , j7 6 @ l2 E.W. fEL. 558.3 h I' OL 'E
~~T D NOZZLE 5/tf ~~~~
~~STL. PLATE ~ 4610 B ARS- g ...- r EL.55 4.3 y 't:-~~
,' .I.) N g.,p O rEL. 551.5 I LAKE BOTTOM SEDIMENT JL. 556.2 -d Tsyia S 9 EL 548. 6
~~JL 557.2 - 1 P- i~~
* '- L > T_. *--# 01 BArtS
~~( TOP CF SURFACE PLATE~~
,5 5/8" STL. PLAT #4 B ARS k 5 S RE . ' --5" _ _ O 10'- 7 " AL AROUND w a . .,.s APPROX. LAKE BOTTOM & .g "# 4 BARS ly:
f TOP OF ROCK ; p' STRUCTURE NO. I EL.548.8 ' STRUCTURE NO. 2 EL. 549.8 f ( DISCHARGE RISER SHAFT cm.s i.. . p_ _ 4'_ o uig , SECT 10N B-B h METE C'.CKING P O ,' 5' 10' 15' OFFSHORE INTAKE AND DISCHARGE STRUCTURES PERRY NUCLEAR POWER PLANT 1 & 2 THE CLEVELAND ELECTRIC ILLUMIN ATING COMPANY FIGURE 3.4-1 3.4-10
3.5 RADWASTE SYSTEMS AND SOURCE TERMS
/}
The radwaste systems are similar to those described in the ER/CP . Source terms presented here reflect present NRC guid-ance. 3.5.1 SOURCE TERMS 3.5.1.1 Primary Coolant Radioactivity The radioactivity in the primary (reactor) coolant is given by isotope in Table 3.5-1. The calculational model used in determining the isotope content is the BWR-GALE code III speci-fled in NRC Regulatory Guide 1.112. The values used in deriving the source terms are consistent with the assumptions and parame-ters given in Reference 1 and in Appendix A3.5. 3.5.1.2 Tritium [} The release of tritium to the environment from operating General Electric BWRs has always been well below the limits specified in 10 CFR 20. Release points and the quantities of tritium released through the gaseous and liquid pathways are given in Tables 3.5-2, 3.5-3, and 3.5-4. 3.5.1.3 Fuel Pool 3.5.1.3.1 Description The piping and instrumentation diagrams for the fuel pool cooling and cleanup system are given in Section 9.1.3 of the FSAR. The diagram for the fuel-handling area ventilation ! system is shown in Figure 9.4-4 of the FSAR. O 3.5-1
The fuel pools and their volumes are identified as follows:
~~} Fuel Pool Volume * (cubic feet)~~
Intermediate building Cask pit 10,800 Spent fuel pool 39,100 Fuel transfer pool 11,000 Fuel preparation pool 31,640 Reactor building Separator storage pool 20,020 Reactor well 19,840 Dryer storage pool ** 27,080 Fuel transfer pool 5,850
~~Gross volume of normal water level.~~
** Including the fuel storage pool.
Ch V The source of makeup water for the cask pit and the containment pools is the condensate transfer and storage system; the source for the fuel storage pools is normally the condensate transfer and storage system. A backup water source is available from the emergency service water system. 3.5.1.3.2 Management of Water Inventories During Refueling The refueling of a unit will involve two drain-and-fill opera-tions in the containment upper pool. The reactor well must first be drained to permit removal of the drywell head, vessel head, and steam dryer. The pool will then be refilled to remove the steam separator and to refuel the reactor. After refueling, the steam separator must be installed and the reactor well drained to replace the vessel head and drywell head. i The containn.ent upper pool must then be reflooded. l l () 3.5-2
The volume of water to be removed from the reactor well will be 208,000 gallons for the first drain operation and 305,000 ('T gallons for the second drain operation, when the drywell head is not in place. Drainage and refilling of the containment pool for the refueling operation can be accomplished in the following sequence:
1. Align the proper valves in the condensate transfer system, the condensate system, and the fuel pool cooling and cleanup system to permit drainage of the containment pools through the 10-inch drain line in the reactor well. Approximately 208,000 gallons of water from the reactor well and separator storage pool will drain to the main condenser shells.

2. Set up the condensate system to recirculate the contain-ment upper pool water through the condensate demineralizer system. Continue this operation until the water reaches condensate quality or until the drywell head, vessel
~}
~~x' head, and steam dryer have been removed.~~
3. After removal of the drywell head, vessel head, and steam dryer, transfer 208,000 gallons from the condenser shells in the containment pool using the main cycle flow path to the reactor with one hotwell pump and one feedwater pump in series. Simultaneously, makeup 97,000 gallons from the condensate storage tank to the containment upper pool using both transfer pumps and the containment upper pool fill valves.

4. Remove steam separators and refuel reactor.

5. After refueling and reinstallation of the steam separa-tors, drain the 305,000 gallons from the containment upper pool back to the condenser shells by aligning the valves as in step 1. After the containment upper 3.5-3 l
I
pool has drained to the condenser shells, it can be cleaned up as in step 2, if necessary. C,
~~6. After installing the reactor vessel head and drywell head, reflood the containment upper pool with 208,000 gallons from the condensers.~~
During refueling, approximately 1000 gallons of water will be transferred from the upper fuel transfer pool to the surge tank because of the draining of the fuel transfer tube during each transfer cycle. This transfer of water will be accommo-dated by the surge tanks by keeping the level in the tanks : 1 at least 3 to 4 feet below the overflow. If the additional l flow from the upper pool raises the level of the surge tank sufficiently, backflow will occur through the skimmer piping, thus equalizing the level of the pool and the tank and ensuring l that the surge tank will not overflow. However, repeated operation of the fuel transfer mechanism could result in a ('] \- large net transfer of water from the upper to the lower pools. Corrective action will be taken to move the water back up l to the upper pools by adjusting the flow-control valves for the fuel-pool cooling and cleanup system. 3.5.1.3.3 Radioactivity The fuel pool cooling and cleanup system is designed to remove decay heat from the spent fuel pool and to clean and purify radioactive contaminants from the water in the spent fuel pool and the upper fuel pools in the containment. The purity and clarity of the water will be maintained at acceptable levels by using a combined filtration and demineralization system. Release of radioactive materials in gaseous effluents from all sources is given in Tables 3.5-4 and 3.5-5. ( 3.5-4
i 3.5.2 LIQUID RADWASTE SYSTEMS 3.5.2.1 Design Objective The liquid radwaste treatment (LRW) system is designed to receive and process simultaneously, for reuse or disposal, the radioactive liquid-waste streams from both PNPP units. The LRW system is so designed that the annual release of radio-activity to the environment will be a small percentage of the quantities allowed in applicable regulations and will be as low as reasonably achievable. 3.5.2.2 System Description The LRW system is divided into four subsystems for processing the following categories of liquid wastes: high-purity / low-conductivity wastewater, medium- to low-purity / medium-conductivity wastewater, high conductivity chemical wastes, and detergent () drains. The LRW system also provides for collection of the spent demineralizer resins, filter /demineralizer and filter sludges, and evaporator bottoms, before treatment in the solid-radwaste disposal system. The streams have provision for discharge to the lake after processing and sampling. These streams are normally recycled within the plant (condensate-storage tanks) or in the radwaste system. When the processing of liquid radwastes is required, it will be accomplished by the appropriate combination of filtration, ion exchange, and evaporation, depending on the type and amount of radioactive contamination present. A schematic flow diagram showing the origins, treatment, and disposal of liquid radio-active wastes generated in the plant is presented in Figure 3.5-1. Figure 3.5-2 is a summary of the process flow paths used for estimating liquid-radwaste releases to the environment. t The piping and instrumentation diagram for this system is l (} presented in Figure 11.2-1 of the PNPP FSAR. 3.5-5 l l
3.5.2.2.1 High-Purity / Low-Conductivity Wastewater Subsystem O This subsystem consists of equipment drains, cask pit area drain suppression pool water (normally directed to the suppres-sion pool cleanup system), blowdown of reactor water via the RWCU system (normally directed to hotwell), rinse water from the condensate mixed-bed demineralizers, and residual heat removal system flush / test water. With the exception of equip-ment drains, the waste streams can be diverted to the medium-to-low purity subsystem if the water quality or flow conditions warrant. These wastes will be collected in one of two waste-collector tanks (on an alternating basis) each sized to hold the normal daily input; they will be processed as a batch by being passed through a traveling belt filter to remove suspended solids and a mixed-bed demineralizer to remove dis-solved solids. Two waste sample tanks, each sized to hold one batch of waste, are provided for sampling, mixing, and temporarily storing the treated effluent. After sampling, () the batch may either be recycled to the waste-collector tank for further treatment, sent to the condensate-storage system (normal path), or discharged. For greater reliability, this subsystem is cross-connected with identical equipment in the medium- to low-purity subsystem. 3.5.2.2.2 Medium- to Low-Purity /High-Conductivity Wastewater Subsystem This subsystem collects radioactive floor drainage, decantate from all the sludge-settling tanks, backwash from the radwaste demineralizers, and the decantate fi;om the solid radwaste disposal system. With the exception of the floor drainage, the wash streams can be diverted to the high purity subsystem, l if water quality or flow conditions warrant. The waste will i be collected in one of two collector tanks each sized to hold ! the normal input of 3 days; it will be processed as a batch l by a filter and demineralizer identical with those described I (V'i l above for 3.5-6
the high-purity wastes. Two floor-drain sample tanks, each sized to hold one batch of waste, are provided for sampling, (]) mixing, and temporarily storing treated effluent. After sampling, the batch may be recycled to the floor-drain collector tank for further treatment, sent to the condensate-storage system (normal path), or discharged. This subsystem is cross-connected with identical equipment in the high-purity subsystem. 3.5.2.2.3 Chemical Waste Subsystem This subsystem treats laboratory drains and regeneration solu-tions from the mixed-bed condensate-polishing demineralizers. The wastes will be collected in one of two chemical waste tanks, each sized to hold the regeneration solutions from one mixed-bed demineralizer. They will be processed in a 30-gallon-per-minute horizontal waste evaporator, sized to handle a batch in 10.5 hours. Before entering the evaporator, the wastes will be sampled and the pH level will be monitored. A i i The pH will be maintained at a level of 7 to 10 for optimum V evaporator performance. Bottoms from the evaporator will be pumped to one of two concentrated-waste tanks and then transferred f rom these tanks to the solid-waste treatment system. Distillate from the evaporators will be temporarily stored in one of two chemical waste distillate tanks. After sampling, the distillate can be further processed through the floor drainage demineralizer, pumped to the condensate-storage system (normal path), or discharged. , 3.5.2.2.4 Detergent-Drains Subsystem This subsystem handles miscellaneous nonradioactive floor drains from the control complex, and personnel decontamination l station drains. The waste will be collected in one of two detergent drainage tanks. After sampling, the waste will l be filtered and discharged via the sanitary waste treatment sy s tem. ({} 3.5-7
s It is expected that this system will normally contain negligible amounts of radioactive material; however, should significant activity levels occur in the detergent drainage tanks, the waste can be processed in the waste evaporator before discharge. Contaminated clothing will be either shipped to an offsite commercial laundry licensed to handle such items or processed in an onsite dry-cleaning machine. The small amounts of contami-nated oil and filter elements produced by the dry-cleaning process will be packaged in the solid radwaste system for off-site burial. Clothing and other laundry containing a significant amount of radioactivity will be packaged for offsite burial rather than laundered. 3.5.2.2.5 Collection of Spent Resins, Filter /Demineralizer Sludge, and Filter Sludge Spent resins from the mixed-bed condensate demineralizers, g-~ the suppresion pool cleanup demineralizers, the waste demineral-
~~\_- izer, and the floor drains demineralizer will be collected in one of two spent-resin tanks. Each tank is sized to hold the spent resins form six condensate demineralizer vessels.~~
The spent resins will be transferred as a water slurry to the solid-waste treatment system. Backwash from the condensate filter backwash receiving tanks (located in the turbine buildings) and the BWCU filter /demineral-izer backwash receiving tanks (located in the reactor containment vessels) will be pumped to settling tanks in the radwaste building. The sludge will be allowed to settle to the bottom of these tanks, while relatively clean water will be drawn off the top and pumped to the floor-drain collector tank for j further processing. After 10.5 days for the condensate filter backwash and 60 days for the RWCU F/D backwash system, the sludge will be transferred to the solid-waste treatment system as a concentrated water slurry. 3.5-8
Backwash from the fuel pool filter /demineralizers will be () pumped to one of two fuel-pool filter /demineralizer backwash settling tanks. The sludge will be allowed to settle to the bottom of these tanks while relatively clean water will be drawn off the top and pumped to the floor-drains collector tank for further processing. Periodically, the sludge will be transferred to the solid-waste treatment system as a concen-trated water slurry. 3.5.2.3 Operating Procedures 3.5.2.3.1 Operation The LRW system is operated on a batch basis, with the equipment controlled semiautomatically. Mode switches are provided to automatically position valves and start and stop pumps for normal modes of operation. Cross-tying of pumps and tanks is done manually. For all normal and emergency operations, () all systems are designed for operation from a radwaste building control room rather than from local control panels or stations. Valves equipped with power operators are designed to fail closed if flow through the valves would result in sending the liquid radwaste further downstream in the waste-treatment system. 3.5.2.3.2 Discharge Except for detergent drainage, all effluents from the LRW system will notmally be sent to the condensate storage system or main condenser for reuse in the plant. This will be done on a batch basis after sampling to determine whether or not the effluents are suitable for rouse. If the sample does not meet quality standards for condensate makeup, the batch will be either recycled for further treatment or discharged via the Unit 1 emergency service water discharge, depending () on the chemical content and activity level. Detergent drains 3.5-9
i l l l are normally sampled, filtered, and sent to the sanitary waste j treatment system. The flow path to the discharge point for {"} each effluent stream is equipped with at least one air-operated j valve designed to fail closed. In addition, each discharge line has a manual valve normally locked closed and with position readout in the control room. All discharge lines are routed I through a flow control and monitoring station, where the flow rate is regulated and the activity level is monitored and recorded. On low dilution-water flow or high discharge radio-activity, the discharge control valve is automatically closed and an alarm signal is sent to the control room. 3.5.2.4 Computation Description l The release of radioactive materials in liquid effluents was calculated by means of the BWR-GALE code.( } The parameters used are consistent with those given in Reference 1 and Appendix A3.5. The activities in the solid-waste streams processed by the radwaste system were calculated with the use of a digital computer program. To determine the specific activity of each member in a three-member radioactive decay chain after a time of t seconds, the following equation was used: Time rate of change of activity = rate entering - rate decaying (3.5-1) The solutions used for the first, second, and third members of the chain are e (3.5-2) A1=A
~~<3 \>~~
~~3.5-10 i yr -~~
~A2D (e -At y-e -AD 2) +A e A2= 2 2 A{ 2 A 2 -Al (3.5-3) o 1
~~D ~A3D A By A b ~* I A 3=B(A2 2 3~~
~~~A ll IA 3 ~A1) 2 -A 3D ~~~
~~D B By A o Al (e -e 2)~~
~~+ 2 2 3 "Al l IA 3 ~A)~~
~~(A 2 2 g -At y -A D~~
~~+ U 2 ^3 A 2 (* ~* 3)~~
~~A 3 "A 2 o ~AD I~~
~~~AD 3 , B A A I* ~* I 3 3 l A~~
3
~~-A 1 + A e (3.5-4) whcre Ag = specific activity of isotope i at time t (pCi/cc)~~
~~O A = specific activity of isotope i at time 0 (pCi/cc) A 1~~
~~= decay constant of isotope i (sec )~~
By = fraction of first member that decays to second member of chain D = fr ct.lun of second member that decays to third 2 member of chain B = fraction of first member that decays directly 3 to third member of chain. While a tank is being filled with liquid radioactive wastes, decay is also occurring. The time rate of change of activity is described by Equation 3.5-1, with an additional production term to account for addition by water flow. The equations 3.5-11
l l used to determine the specific activity of each member of 4 C a three-member decay chain in a tank as a function of filling time are t Ay = Wy (1 - e i) (3.5-5) t A 2
~~IW 2 + BW) yy (1 - e 2) (3.5-6) 2 -e -A D D~~
~~+ By A W1 2 (e I)~~
~~(A 2 -A) 1 A 3~~
~~W3 + B 2 I 2~~
+ BW) yy +BW31 (1 - e X3.5-7) " ~ -AD 3 -e-AD I + BB y2 A 2 A3 W1 + 8A33 W 1 I* I i (A 3 -A} l (A 2 -A ll A3 Al i : - + W1 1 2 A3 B A (W2+BW) 2 3 yy -A 2D -A D , _, 3)
~~A 3~~
~~-A 2 l where A~~
o Wf = l t i and all other variables are as defined above. Certain impurities are removed from a liquid as it passes through a filter or a demineralizer. The equation describing l this removal is l 3.5-12
t o A A = i I (3.5-8) (} DF g where Ag = specific activity of isotope i in the fluid after decontamination (pCi/cc)
~~= specific activity of isotope i in the fluid before A{~~
~~l decontamination (pCi/cc) DPg= decontamination factor for isotope i.~~
Resins in a filter or demineralizer become radioactive af ter i the removal of radionuclides from the fluid. The fraction of isotope i removed by the resins is given by p , DFg-1 DF* (3.5-9)
O O The total activity that enters a demineralizer is A V. There-fore, the activity retained on the resins, neglecting radio-active decay, is Ag = AfFV f (3.5-10) where Kg = activity of isotope i retained on resins, neglecting
~~decay, during time t (pci/cc) 1 I~~
3.5-13
U A = specific activity of isotope i entering the deminer-alizer (pCi/cc) V = volume of fluid passed through demineralizer in time t (cc). To calculate the activity on the resins, taking decay into account, the summation of a finite series of the following form is used:
~~-A 1Kt Af =~~
~~X [nK=1 i e (3.5-11) where Af~~
~~= activity of isotope i retained on resins at time t ( pCi) t = time for resins to accumulate activity A g (sec) n =~~
~~T/t The activity of isotope i on the resins is given by~~
~~-ADl -At Af = Ag + A (1 - e ) (3.5-12) i 1-e -At1 where Ag = activity Eg after decay time of t seconds as given by Equations 3.5-2, 3.5-3, and 3.5-4.~~
The specific activity of isotope i in the distillate and concen-trate of an evaporator is Af = A DF g (3.5-13) O 3.5-14
3 A = Ry P 3 A - R2 # 3
^
~~R 3 1 R 3 P 2 (3.5-14) where : Af~~
~~= specific acti.ity of isotope i in the feed (pCi/cc)~~
~~A = specific activity of isotope i in the distillate ( pCi/cc) Af~~
~~= specific activity of isotope i in the concentrate~~
~~( pCi/cc) l DFg= decontamination factor for isotope i in the evaporator Ry = flow rate of the feed R 2~~
= flow rate of the distillate O R 3 = 1 w rate of he concentrate py = density of the feed p2 = density of the distillate p3 = density of the concentrate 3.5.2.5 Radioactivity Releases Data on the influent streams are presented in Table 3.5-5.
All processing is on a batch basis; the batch time shown is the average time between batches. The volumes shown are the expected amounts during normal ste2dy-state operation of the two units. The input streams for t!'e waste collector and j floor drain collector tanks are broken down into the various ! (N equipment and floor drainages from the drywell, reactor building, ( O 3.5-15 l
turbine building, and radwaste building, with their estimated volumes. The liquid effluent streams capable of discharge are the waste collector, floor drains, and nemical waste distillate. Table 3.5-4 gives the calculated release of radioactive materials in liquid effluents. These values were calculated by means of the BWR-GALE code and the assumptions and parameters given in Reference 1 and Appendix A3.5. The detergent-drain discharges
~~will be negligible, as discussed in Section 3.5.2.2.4.~~
The collected filter sludges and demineralizer resins and evaporator bottoms will be pumped as slurries to the solid-radwaste system for solidification in drums and shipment off the site. 3.5.3 GASEOUS RADWASTE SYSTEMS 3.5.3.1 Design Objective The gaseous radwaste system is designed to process and control the release of radioactivity to the environment such that the annual emission from these releases is as low as reasonably achievable. 3.5.3.2 System Description and Operating Procedures The gaseous radwaste system is divided into two basic subsystems:
1. The condenser air ejector low temperature offgas system shown in Figure 3.5-3.

2. The plant building ventilation systems, consisting of the containment and drywell purge systems, the control complex ventilation system, the auxiliary O
3.5-16
building ventilation system, the fuel handling build-(} ing ventilation system, the intermediate building ventilation system, the turbine building ventilation system, and the offgas building ventilation system shown in Figure 3.5-4. The release elevations and release point locations discharging to the environment are shown in Figure 3.1-2. The effluent velocity from these systems is 3500 feet per minute, and the maximum temperature of the gases is 105 F. Enlarged views of the plant structures showing heights, shapes, and locations are given in Figures 3.1-3 through 3.1-5. 3.5.3.2.1 The Condenser Air-Ejector Offgas System The steam-jet ejector continuously removes the noncondensable gases from the turbine condenser. The air ejector discharge will be processed by the low-temperature RECHAR system. This offgas treatment system uses a catalytic recombiner to recombine [} radiolytically disassociated hydrogen and oxygen contained in the discharge of the air ejector. After the offgas is cooled to aoproximately 130 F to strip the condensables and reduce the volume, the remaining noncondensables (principally kryptons and xenons) will be delayed for 10 minutes in a holdup pipe. The outcoming gas will be cooled to 45 F and then filtered through a HEPA filter. The gas will then pass through a desiccant dryer that reduces its dew point to -90 F. Next, it will be chilled to 0 F. Charcoal adsorption beds, operating in a refrigerated vault 0 at about 0 F, will selectively dynamically adsorb and delay the xenons and kryptons from the bulk carrier gas (principally dry air) . (2) After this delay, the noble gases will again be passed through HEPA filters and discharged to the environment via the offgas building vent. The activity of the offgas () 3.5-17
will be continuously monitored on entering and leaving the treatment system. Because of the low operating pressure and the use of welded pipe, zero leakage valves, and vented instrument racks, leakage of gas from the system into the offgas building will be mini-mized. 3.5.3.2.2 Plant Building Ventilation Systems Ventilation and cooling are provided through the plant areas to accomplish the following:
a. Maintain the required ambient air temperature in all plant areas for the comfort and safety of the personnel and the cooling of process equipment.

b. Adequately meet the radiation control requirements of 10 CFR 20 and 50, to ensure the safety of plant O's operating personnel in the various plant areas and to ensure that the radioactive gaseous emissions from the plant to the environment are kept as low as reasonably achievable and below permissable dis-charge limits.

c. Direct air flow from areas of lesser radioactive contamination to areas of progressively higher contami-nation before final exhaust.
~~3.5.3.2.2.1 Reactor-Building-Complex Ventilation Systems. The reactor building complex ventilation systems that release ventilation air to the environment consist of three subsystems:~~
a. The annulus exhaust gas treatment system

b. The containment purge system f3 c. The drywell purge system l %-)
3.5-18 l _ . ._. _ _ _ ._
3.5.3.2.2.1.1 Annulus Exhaust Gas Treatment System. /"T The annulus exhaust gas treatment system is provided to collect V and process any air leakage from the containment vessel into the annulus. To accomplish this, the annulus exhaust treatment system operates continuously to maintain the annulus area at a negative pressure equal to or greater than 0.40-inch water gage. Air exhausted from the annulus will be treated by roughing filters, HEPA prefilters, activitated charcoal filters, and HEPA afterfilters before release to the plant vent. During normal plant operation, negligible activity will be released to the environs from this system. 3.5.3.2.2.1.2 Containment Purge System. The containment purge system is provided to reduce the activity inside contain-ment to a level safe enough to permit occupancy at any time during operation. This system also provides a means of purging and resupplying containment air during refueling. /~h Since the major source of airborne activity is confined to V the RWCU equipment rooms, these rooms are isolated and main-tained at a slight negative pressure by purging continuously with the containment purge fans. The containment volume proper is also purged continuously at a lower rate by the same fans. The purge air from the RWCU rooms and the containment is exhausted to the unit vent through roughing filters, HEPA prefilters, activated charcoal filters, and HEPA afterfilters. Fresh outside air is supplied continuously to the containment, main-taining it at essentially atmospheric pressure. 3.5.3.2.2.1.3 Drywell Purge System. The drywell purge system is provided to reduce airborne activity in the drywell to acceptable levels prior to short-term access at reactor hot standby and prior to access at reactor shutdown and refueling. To accomplish this, containment air is supplied to the drywell, and the drywell air is exhausted from the drywell to the contain-3.5-19
ment purge system. The drywell air is treated by the same {} filter train as that used by the containment purge system. 3.5.3.2.2.2 Turbine Building Ventilation System. Clean outside air is provided to the turbine building condenser bay area through supply roughing filters and heating and cooling coils. The air is allowed to flow up through the turbine building and is collected above the turbine operating floor, where it is discharged to the atmosphere through the turbine build-ing/ heater bay vent on the heater bay roof. The exhaust air is monitored for radioactivity prior to discharge to the abmos-phere. 3.5.3.2.2.3 Radwaste Building Ventilation System. The radwaste building ventilation air is supplied through a common roughing filter and heating coil. The building exhaust air is treated by roughing filters, HEPA prefilters, charcoal filters, and HEPA afterfilters before discharge to the unit vent. The radwaste building control room has its own independent ventila-tion system. 3.5.3.2.2.4 Offgas Building Ventilation System. The ventila-tion supply for the offgas building and for the offgas equipment room in the turbine building is supplied through roughing filters and heating coils. The exhaust from the offgas building and equipment rooms is treated by roughing filters, HEPA prefil-ters, charcoal filters, and HEPA afterfilters. Before discharge to the environment via the offgas building vent, the exhaust is mixed with the treated condenser offgas system discharge. 3.5.3.2.2.5 Other Plant Building Ventilation Systems. The - exhausted ventilation air from the control access area of the control complex, the auxiliary building, the fuel-pool cooling equipment rooms of the intermediate building, and the fuel handling building will contain negligible gaseous radioactivity during normal plant operation. However, the [} 3.5-20
discharges from these areas are treated by HEPA and charcoal g- filters before discharge to the unit vent. The exhaust ventila-tion air from the control room and equipment areas of the complex, the equipment areas of the intermediate buildings, and other plant buildings that do not contain radioactive systems is discharged directly to u. atmosphere. 3.5.3.3 Radioactivity Releases The release rate of radioactive materials in gaseous effluents is presented in Tables 3.5-2 and 3.5-3. The values are based on the assumptions and parameters provided in Reference 1 and Appendix A3.5. 3.5.4 SOLID-WASTE DISPOSAL SYSTEM 3.5.4.1 Design Obj ective r x. The solid-radwaste (SRW) disposal system (Figure 3.5-5) is k designed to collect and package all radioactive wastes that are to be shipped to offsite disposal (burial) facilities. The criteria used for accomplishing these objectives are:
a. The collection, packaging, and shipping will be done in a controlled, preplanned manner in compliance with all local, State, and Federal requirements.

b. No radioactive material handled by the system will be released to the environment during processing in the plant or during transfer of the wastes to the disposal facility.
i l c. Most types of wastes shipped off the site will be l in a solid form. Liquid wastes and solid wastes in slurry form to be shipped off the site will be i 3.5-21
solidified using a mixture of cement and sodium sili-cate as solidification agents. {
d. Waste handled by the SRW system will be shielded as necessary during processing and shipping in order to meet the applicable Nuclear Regulatory Commission (10 CFR 71) and Depar tment of Transportation (49 CFR 171-179) regulations for the protection of operating personnel and the general public.

e. The system will be designed to handle any anticipated type of waste produced in the plant, including spent resins, filter sludges, filter cartridges, evaporator bottoms and contaminated tools, equipment, and clothing.
3.5.4.2 System Description The SRW system is a packaged system supplied by United Nuclear Industries; it uses portland cement and sodium silicate to solidify liquid and slurry wastes. The system consists of waste mixing and dewatering tanks, waste feed pumps, decanting pumps, waste / cement mixing pumps, container fillports, cement and sodium silicate storage tanks and feed equipment, drum capper, drum swipe-test station, drum decontamination station, drum transfer cart, and overhead bridge crane. All portions of the system in contact with radioactive fluids are fully redundant. All operations will be performed remote manually or semiauto-matically from a centralized SRW system control panel. All drum handling, capping, and decontamination activities will also be done remotely from this panel. The system is designed to handle containers ranging in size from 55-gallon drums to 200-cubic-foot liners. (See PNPP FSAR Figure 11.4-1 for a piping and instrumentation diagram of this system.) ('% b 3.5-22
Waste to be solidified will be first pumped to the mixing /de-watering tank (in the case of radwaste filter cake, the cake 7 k/ falls by gravity through a chute connecting the tank to the filter). Excess free water will then be decanted and returned to the liquid-radwaste system for further processing. The remaining liquid or slurry waste will then be pumped to a mixing pump, where it will be mixed with cement. This mixture will be pumped from there to a retractable fillport located above the container to be filled. As the waste / cement mixture enters the container, sodium silicate will be sprayed into the mixture. This patented cement / sodium silicate process ensures against any free water by chemical reaction between the water and both the cement and sodium silicate. Further verification of monolithic, free-standing, water-free solid is obtained by recording the amounts of waste, cement and sodium silicate in the mixture. These proportions are then compared with proportions known from previous testing to yield the desired physical characteristics. I s_/ After the container is filled, the radiation level at the surface of the container will be measured remotely, and the reading will be logged in a record book, along with the quantity and type of waste in the container. The fillport will then be retracted and the container moved by a self-powered, remote-controlled transfer cart to a swipe-test and capper station, where it will be capped using a remote controlled capper; a swipe test will be taken remote manually. If the swipe [ test proves negative (no contamination), the container will be picked up by a remote-control overhead bridge crane and I placed in an in-plant, shielded storage vault. If the container has been contaminated during the filling operation, it will be moved by the transfer cart to a decontamination station, where it will be washed down remotely, dried by a remote controlled heater / blower, swipe-tested again, and then transferred by the bridge crane to the storage area. Wnen enough containers
~~,3 are filled to make a shipment, the bridge crane will remotely~~
(_) 3.5-23
l transfer the containers from the storage vault to a trailer in an adjacent in-plant truck bay. {~ } 3.5.4.3 Operating Procedure Spent resins, filter /demineralizer sludges, and evaporator bottoms will be pumped as water slurries through taps off recirculation lines on their respective storage tanks to the waste-metering station. At the waste-metering station, the solid wastes in slurry form will be partially dewatered and measured amounts of waste and solidification agent will be mixed together and pumped into shipping containers through a retractable fillport. Before being pumped to the waste-metering station, the waste will be measured for gross beta / gamma activity level so that a permanent record can be kept of what activity is shipped off the site. During filling, the activity level in the ship-
~~~'N ping container will be continuously monitored to provide an (O alarm and automatic shutoff of waste input on a high-radiation signal.~~
After the filling and mixing process is complete and the ship-ping container filled and capped, a swipe test will be performed remotely to determine whether there is any external contamina-tion. If there is, the container will be washed down remotely. The shipping container will then be picked up by a remotely operated crane and placed in a storage area to await offsite shipment. Compressible solid wastes (contaminated paper, clothing, rags, etc.) will be accumulated in 55-gallon drums. The contents of these drums will be compacted in the drum by the waste compactor when a sufficient amount of material has accumulated therein. The compacted waste will be stored until shipment to an offsite burial site. C' 3.5-24
The SRW system is designed to fill the shipping containers at 10 to 40 gallons per minute on a batch basis. The estimated (]) operating time for the complete processing of c_e 200-cubic-foot shipping container is 1 hour. Incompressible wastes (detergent-drain cartridge filters, air filters, contaminated tools, etc.) will be packaged in either 55-gallon drums, 50-cubic-foot shipping containers, or 110-cubic-fcct LSA boxes, depending on their size. Shielding will be provided around the shipping container as required; in some cases, highly radioactive materials may be placed in shipping containers and solidification agents added around them. 3.5.4.4 Expected volumes and Activities The expected volumes and activity of solid wastes to be shipped off the site for disposal are listed in Table 3.5-6. The () volumes in this table are based upon the normal flow quantities presented in Table 3.5-5. The activity is based on holdup times, as listed in this table. The isotope inventory of the solid waste to be shipped off the site is given in Tables 3.5-7, 3.5-8, and 3.5-9. 3.5.4.5 Packaging The SRW system is designed to package wastes in containers ranging in size from 55 gallons to 200 cubic feet. All shipping containers are provided with fill openings designed to fit standard ICC 17H 55-gallon-drum lids. These lids will be secured to the containers with a remotely controlled drum capper. The shipping containers conform to the applicable NRC (10 CFR 71) and DOT (49 CFR 171-179) regulations. Since filling and in-plant movement of shippin3 containers are done remotely from behind heavy shield walls, exposures l ({} 3.5-25
~~._. . ___ - - ~ _,~~
to personnel during these operations will be negligible for the expected levels of activity in the waste being processed. (]) However, to minimize shipping and burial costs, the amount of activity per shipping container will be, where possible, normally kept below low-specific-activity limits, as specified in 49 CFR 173. 3.5.4.6 Storage Facilities Shipping containers will be moved to and from the shielded storage area by a remotely controlled bridge crane. The storage area has the capability to store up to 1.7 month's production of waste. No credit is taken for any decay of radioactive isotopes during storage. 3.5.4.7 Shipment In general, the packaged solid radwaste material will be shipped () off the site in enclosed truck trailers, with additional shielding and container protection provided as necessary to meet NRC and DOT requirements. The remotely controlled bridge crane will be used to load the shipping containers onto the trailer, which will be parked in a truck bay adjacent to the container storage area. Compacted waste will be loaded onto the trailer by means of a forklift and the loading dock at the end of the truck bay. 3.5.5 PROCESS AND EFFLUENT RADIOLOGICAL MONITORING AND SAMPLING SYSTEMS The process and effluent radiological monitoring and sampling systems are provided to allow determination of the content of radioactive material in various gaseous and liquid process and effluent streams. The design objective and criteria are primarily determined by the system designation of either: l 3.5-26 l
~~a. Instrumentation systems required for safety, or~~
{} b. Instrumentation systems required for plant operation. 3.5.5.1 Design Bases 3.5.5.1.1 Systems Required for Safety The main objective of radiation monitoring systems required for safety is to initiate appropriate protective action to limit the potential release of radioactive materials from the reactor vessel and primary and secondary containment if predetermined radiation levels are exceeded in major process /ef-fluent streams. Additional objectives are to have these systems 1 available under all operating conditions, including accidents, and to provide control room personnel with an indication of the radiation levels in the major process / effluent streams plus alarm annunciation if high radiation levels are detected. Main steam line and containment ventilation exhaust radiation d(~N monitoring is provided to meet these objectives. Inf ormation on these systems is presented in Tables 3.5-10 and 3.5-12 and the arrangements are shown in Figure 3.5-6. 3.5.5.1.2 Systems Required for Plant Operation The main objective of radiation monitoring systems required for plant operation is to provide operating personnel with measurement of the content of radioactive material in all effluent and important process streams. This allows demonstra-tion of compliance with plant normal operational technical specifications by providing gross radiation level monitoring and collection of halogens and particulates on filters (gaseous effluents) as required by Regulatory Guide 1.21. Additional l objectives are to initiate discharge valve isolation on the off-gas or liquid radwaste systems if predetermined release C) 3.5-27
rates are exceeded and to provide for sampling at certain radiation monitor locations to allow determination of specific O- radionuclide content. The radiation monitoring provided to meet these objectives are:
a. For gaseous effluent streams

1. Plant vent

2. Off-gas vent pipe

3. Turbine Building / heater bay vent

b. For liquid effluent streams

1. Radwaste discharge

2. Underdrain
't
c. For gaseous process streams

1. Off-gas pretreatment
~~~% 2. Off-gas post-treatment 4~~
3. Carbon bed vault

4. Annulus exhuast

5. Steam packing exhauster

d. For liquid process streams

1. Emergency service water system (Loops A and B)

2. Nuclear closed cooling water Information on these systems is presented in Tables 3.5-10, 3.5-11 and 3.5-12, and Figures 3.5-4 and 3.5-7.
1 O 3.5-28
3.5.5.2 Jnspection, Calibration, and Maintenance O 3.5.5.2.1 Inspection and Tests During reactor operation, daily checks of system operability are made by observing channel behavior. At periodic intervals during reactor operation, the detector response (of each monitor provided with a remotely positioned check source) will be recorded together with the instrument background count rate to ensure proper functioning of the monitors. Any detector whose response cannot be verified by observation during normal operation or by using the remotely positioned check source will have its response checked with a portable check source. A record will be maintained showing the background radiation level and the detector response. The system has electronic testing and calibrating equipment which permits channel testing without relocating or dismounting () channel components. An internal trip test circuit, adjustable over the full range of the readout meter, is used for testing. Each channel is tested at least semiannually prior to performing a calibration check. Verification of valve operation, ventila-tion diversion, or other trip function will be done at this time if it can be done without jeopardizing the plant safety. The tests will be documented.
~~a. The following monitors have alarm trip circuits which can be tested by using test signals or portable gamma sources: ,~~
~~1 l~~
1. Main steam line l

2. Containment ventilation exhaust

3. Off-gas pretreatment

4. Carbon bed vault O
~~l 3.5-29 1~~
~~b. The following monitors include built-in check sources which can be operated from the control room:~~
)
1. Off-gas post-treatment

2. Annulus exhaust

3. Off-gas vent pipe

4. Plant vent

5. Turbine building / heater bay

6. Steam packing exhauster

7. Radwaste effluent to sanitary waste

8. Radwaste effluent to ESW discharge pipe

9. Emergency service water

10. Nuclear closed cooling water i

11. Underdrain 3.5.5.2.2 Calibration The radiation monitor's calibration is traceable to certified
~~) National Bureau of Standards or commercial radionuclide stan-dards. The source-detector geometry during primary calibration is identical to the sample-detector geometry in actual use.~~
Secondary standards which were counted in reproducible geometry during the primary calibration may be used with each monitor for calibration after installation. Each monitor is calibrated annually during plant operation or during the ref ueling outage if the detector is not readily accessible. A calibration can also be performed by using applicable liquid or gaseous radionuclide standards or by analyzing particulate, iodine, or gaseous grab samples with laboratory instruments. 3.5.5.2.3 Maintenance The detectors, electronics, recorders, and sample pumps are serviced and maintained on an annual basis or in accordance with manufacturer's recommendations to ensure reliable opera-
~~.tions. Such maintenance includes cleaning, lubrication, and 3.5-30 I~~
1
assurance of free movement of the recorder in addition to the replacement or adjustment of components required after ({} performing a test or calibration check. If work is performed which would affect the calibration, a recalibration is performed at the completion of the work. 3.5.5.3 Effluent Monitoring and Sampling All potentially radioactive effluent discharge paths are contin-uously monitored for gross radiation level. Liquid releases are monitored for gross gamma. Solid waste shipping containers are monitored with gamma sensitive portable survey instruments. Gaseous releases are monitored for gross gamma. The following gaseous effluent paths are sampled and monitored:
a. Plant vents

b. Off-gas vent pipe

c. Turbine Building / Heater Bay Ventilation System A
U The following liquid effluent paths are sampled and monitored: Liquid Radwaste System Underdrain System An isotopic analysis is performed periodically on samples obtained from each effluent release path in order to verify the adequacy of effluent processing to meet the discharge limits to unrestricted areas. This effluent monitoring and sampling program is utilized to provide the information for the effluent measuring and reporting programs required by 10 CFR 50 Section 36A, Appendix A, General Design Criterion 64, and Appendix I and Regulatory Guide 1.21 in semiannual reports to the NRC. The frequency of the periodic sampling and analysis described herein is a minimum and will be increased if effluent levels approach { 3.5-31
Technical Specification limits. Tables 3.5-13, 3.5-14, 3.5-15, and 3.5-16 present the sample schedules. 3.5.5.4 Process Monitoring and Sampling The potentially significant radioactive discharge paths are equipped with a control system to automatically isolate the discharge on indication of a high radiation level. These include:
a. Off-gas post-treatment

b. Containment ventilation exhaust

c. Liquid radwaste effluent The effluent isolation functions for each monitor are given in Tables 3.5-10 and 3.5-11.
~~Radiation levels in radioactive and potentially radioactive process streams are monitored by the following process monitors: O~~
a. Main steam line

b. Off-gas pretreatment

c. Off-gas post-treatment

d. Carbon bed valut

e. Nuclear closed cooling water

f. Emergency service water

g. Steam packing exhauster

h. Annulus exhaust Airborne radioactivity in the containment, drywell, fuel handling building, and other areas are monitored by Airborne Monitoring systems to monitor in-plant airborne radioactivity.
Area radiation monitors are used to detect abnormal radiation levels in the various process equipment rooms. (~) v 3.5-32
__ _ _ _ . . _ _ - . , _ . . _ . _ . . _ , _ . _ . _ . _ _ _ . . _ . _ _ _ _ _ . . . . _ . _ _ _ _ . ~ . _ _ . _ _ _ _ _ _ _ _ _ _ . _ . _ . 1 1. l 1 f Batch releases are sampled and analyzed prior to discharge 2 in addition to the continuous effluent monitoring. The radwaste process monitoring systems are listed in Table 3.5-11. The " gaseous and liquid process streams or effluent release points l i are monitored and sampled according to Table 3.5-17. j l l i I I t 4 i 1 I i i !O i i i i l l
~~.O 3.5-33 i~~
~~O REFERENCES FOR 3.5~~
1. Calculation of Releases of Radioactive Materials in Gaseous and Liquid Effluents From Boiling Water Reactors (BWR-GALE Code), NUREG-0016, U.S. Nuclear Regulatory Commission, Washing ton, D.C. , April 1976.

2. Experimental and Operational Confirmation of Off Gas System Design Parameters, NEDO-10751, General Electric Company, January 1973.
O
~~.o 3.5-34 l . _ . _ _ _ _ . _ - . . _ . _ . . . . . _ _ .--.___,_._,:_..,.-m~~
TABLE 3.5-1 () ISOTOPE INVENTORY OF THE PNPP PRIMARY COOLANT AS CALCULATED BY THE BWR-GALE CODE Concentration Isotope (gCi/ml)tal CORROSION AND ACTIVATION PRODUCTS Na-24 4.88-3 P-32 1.04-4 Cr-51 2.60-3 Mn-54 3.12-5 Fe-55 5.20-4 Fe-59 1.56-5 Co-58 1.04-4 Co-60 2.08-4 Cu-64 1.64-2 Zn-65 1.04-4 Np-239 3.69-3 FISSION PRODUCTS i Sr-89 5.21-5 Sr-90 3.12-6 Y-91 2.08-5 Nb-95 3.65-6 O- Mo-99 1.05-3 j Tc-99m 1.14-2 Ru-103 1.04-5 Ru-106 1.56-6 Ag-110m 5.20-7 Te-129m 2.08-5 I-131 7.37-4 I-133 3.02-3 Cs-134 1.56-5 I-135 3.18-3 Cs-136 1.04-5 Cs-137 3.64-5 Ba-140 2.09-4 Ce-141 1.56-5 Pr-143 2.09-5 Ce-144 1.56-6 NOBLE GASES , Kr-83m 1.1-3 Kr-85m 1.9-3 Kr-85 6.0-6 Kr-87 6.6-3 Kr-88 6.6-3 Kr-89 4.1-2 j () Xe-131m 4.7-6 1 3.5-35
TABLE 3.5-1 (Continued) , O 1SoTorE 1svEsToRv or TaE eure PRIMARY COOLANT AS CALCULATED BY THE BWR-GALE CODE
NOBLE GASES (Continued) 4 Concentration Isotope (gCi/ml)lal Xe-133m 9.0-5 Xe-133 2.6-3 Xe-135m 8.4-4 Xe-135 7.2-3

Xe-137 4.7-2 Xe-138 2.8-2 (a) Standard computer notation is used in this table; i.e.,
4.88-3 = 4.88 x 10-3, i l lO . 4 5 I O 3.5-36
TABLE 3.5-2 CALCULATED ELEASES OF RADIOACTIVE MATERIALS IN GASEOUS EFFLUENTS--PNPP UNIT 1 Release Rate (Ci/yr) (a) Turbin? Offgas Mech. Vacuum Isotope Plant Vent Building Bldg. Vent Pump Discharge Kr-83m (b) (b) (b) (b) Kr-85m 6 68 82 (b) Kr-85 (b) (b) 290 (b) Kr-87 6 130 (b) (b) Kr-88 6 230 5 (b) Kr-89 (b) (b) (b) (b) . Xc-131m (b) (b) 19 (b) Xe-133m (b) (b) (b) (b) Xe-133 142 250 470 2300 Xe-135m 92 650 (b) (b) Xe-135 113 630 (b) 350 Xe-137 (b) (b) (b) (b) Xe-138 14 1400 (b) (b) I-131 3.9-2 1.9-1 (b) 3.0-2 I-133 1.5-1 7.6-1 (b) (b) Cr-51 9.6-5 1.3-2 -- (b) Mn-54 3.6-4 6.0-4 -- (b)
~~<^ Fe-59 1.6-4 5.0-4 --~~
(b) ( ,}/ Co-58 5.7-5 6.0-4 -- (b) Co-60 1.1-3 2.0-3 -- (b) Zn-65 5.5-5 2.0-4 -- (b) Sr-89 6.3-6 6.0-3 -- (b) Sr-90 3.1-6 2.0-5 -- (b) zr-95 C.5-6 1.0-4 -- (b) Sb-124 4.7-6 3.0-4 -- (b) l Cs-134 1.3-4 3.0-4 -- 3.0-6 Cs-136 1.1-5 5.0-5 -- 2.0-6 Cs-137 2.0-4 6.0-4 -- 1.0-5 [ Ba-140 9.0-6 1.1-2 -- 1.1-5 Ce-141 2.8-5 6.0-4 -- (b) C-14 -- -- 9.5 -- Ar-41 25 -- -- -- H-3 47 -- -- -- (a) Standard computer notation is used in this table; i.e., 3.9-2 = 3.9 x 10-2, (b)Less than 1 Ci/yr noble gas, less than 10-4 Ci/yr iodine and particulates, f3 w.) 3.5-37
TABLE 3.5-3 CALCULATED RELEASES OF RADIOACTIVE MATERIALS IN GASEOUS EFFLUENTS--PNPP UNIT 2 Release Rate (Ci/yr) (a) Turbine Offgas Mech. Vacuum Isotope Plant Vent Building Bldg. Vent Pump Discharge Kr-83m (b) (b) (b) (b) Kr-85m 6 68 82 (b) Kr-85 (b) (b) 290 (b) Kr-87 6 130 (b) (b) Kr-88 6 230 5 (b) Kr-89 (b) (b) (b) (b) Xe-131m (b) (b) 19 (b) Xe-133m (b) (b) (b) (b) Xe-133 132 250 470 2300 Xe-135m 92 650 (b) (b) Xe-135 68 630 (b) 350 Xe-137 (b) (b) (b) (b) Xe-138 14 1400 (b) (b) I-131 3.4-2 1.9-1 (b) 3.0-2 I-133 1.4-1 7.6-1 (b) (b) Cr-51 6.0-6 1.3-2 -- (b) Mn-54 6.0-5 6.0-4 -- (b) Fe-59 8.0-6 5.0-4 -- (b) Co-58 1.2-5 6.0-4 (b) Os Co-60 2.0-4 2.0-3 -- (b) zn-65 4.0-5 2.0-4 -- (b) Sr-89 1.8-6 6.0-3 -- (b) Sr-90 1.0-7 2.0-5 -- (b) Zr-95 8.0-6 1.0-4 -- (b) Sb-124 4.0-6 3.0-4 -- (b) Cs-134 8.0-5 3.0-4 -- 3.0-6 Cs-136 6.0-6 5.0-5 -- 2.0-6 Cs-137 1.1-4 6.0-4 -- 1.0-5 Ba-140 8.0-6 1.1-2 -- 1.1-5 Ce-141 2.0-6 6.0-4 -- (b) C-14 -- -- 9.5 -- Ar-41 25 -- -- -- H-3 47 -- -- -- (a) Standard computer notation is used in this table; i.e., 3.4-2 = 3.4 x 10-2, (b)Less than 1 Ci/yr noble gas, less than 10-4 Ci/yr iodine and particulates. O 3.5-38
TABLE 3.5-4 4 O CatcoLATED Rete ^SzS or RADIOACTIVE MATERIALS IN PNPP LIQUID EFFLUENTS Isotope Release per (Ci/yr) (a) ., Na-24 4.0-5 P-32 1.7-4 Cr-51 5.9-3 Mn-54 1.0-4 Fe-55 1.8-3 Fe-59 4.0-5
Co-58 3.0-4 Co-60 7.1-4 Cu-64 1.1-4 Zn-65 3.4-4 Np-239 4.9-4 Sr-89 1.4-4 Sr-90 1.0-5 Y-91 1.0-4 Nb-95 1.0-5 Mo-99 1.6-4 Tc-99m 1.7-4 Ru-103 3.0-5 p Rh-103m 3.0-5 V Ru-106 1.0-5 Te-129m 5.0-5 Te-129 3.0-5 I-131 1.3-1 I-133 1.1-3 Cs-134 1.5-3 I-135 6.0-5 Cs-136 4.3-4 Cs-137 3.4-3
~~} Ba-137m 3.2-3 4~~
Ba-140 3.0-4 La-140 3.4-4 Ce-141 4.0-5 Pr-143 3.0-5 ! Ce-144 1.0-5 All others 1.0-4 (except H-3) Total 1, 'e -1 (except H-3) H-3 47 (a) Standard computer notation is usedinthistablg;i.e., {} 3.4-2 = 3.4 x 10 . 3.5-39
O n\s O TABLE 3.5-5 PNPP INFLUENT STREAMS Stream Batch Number of Fill and Decay Stream (a) Number (b) Time (days) Volume (gpd) Batches Scheme Waste Collector tanks (WCT): 1 (0-1 day) +0 Recirc. pumps and valves in 1-A 6192 drywell 3 team valves and coolers in 1-B 2408 drywell Misc. pumps, valves, and RCIC 1-C 5109 equipment in containment w
'm Steam valves in contali.=ent 1-D 964 $ RWCU sample drains in 1-E 2410 containment Radwaste bldg. equipment 1-F 500 drains Turbine bldg. equipment 1-G 11520 drains Floor drain collector tanks 3 (0-3 days) +0 (FDCT):
Drywell floor drains 4-A 1438 + Containment floor drains 4-B 1997 Radwaste bldg. floor drains 4-C 1000 Turbine b1dg. floor drains 4-D 4000
O ,
% O TABLE 3.5-5 (Continued) .PNPP INFLUElff STREAMS Stream Batch Number of Fill and Decay Stream (a) Number (b) Time (days) Volume (gpd) Batches Scheme 4
~~S3odges to SRW system: Condensate filter 42 389~~
~~.RWCU F/D 38 44 Fuel F/D 39 20 Spent resins to SRW system:~~
Condensate demin. 40-A 46 w Waste demin. , floor drains 40-B 120 a demin., supp. pool demin. A . H Waste collector effluent to 25 1 39200 0-1 day condenser 3 Floor drains effluent to 29 3 13207 0-3 days
~~condenser 1~~
~~Condensate filter backwash 11 1.5 3467 1 in 1.5 days~~
, FWCU F/D backwash 12 6.5 738 Fuel pool F/D backwash 18 395 1 Spent resins: ; Floor drain demin. 15 30.5 48 i Waste demin. 14 35 42 4
o o o TABLE 3.5-5 (Continued) PNPP INFLUENT STREAMS Stream Batch Number of Fill and Decay , Stream (a) Number (b) Time (days) Volume (gpd) Batches Scheme WCT or FDCT: Condensate demin rinse 3 5685 RHR flush / test 2720 Condensate F/D backwash decant 20 3073 Cask pit drawdown 10 2315 RWCU F/D backwash decant 41 708
~~. Decant fra FRW treatment 5 250~~
] y system a Fuel pool F/D backwash decant 21 395 Chemical waste tanks: 6 i Condensate demin. regen. 6 1781 solutions
~~! Personnel decontamination 9 500 solutions Evaporator:~~
1 Chemical waste distillate 19 6 2104 10-hour process l Bottoms to SRW system 33 30 98 5 (0-30 days)
~~+ 30 day i~~
_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ . . . _ . _ _ _ _ _ . . . . _ _ . _ _ _ _m - . . _ _ _ - . _ . ._._ _ . . . . _ _ . o o o TABLE 3.5-5 (Continued) PNPP INFLUENT STREAMS Stream Batch Number of Fill and Decay Stream (a) Number (b) Time (days) Volume (gpd) Batches Scheme Condensate demin. 13 45 Suppression pool demin. 30 58 Filter cake from floor drain 16 + 17 8.65 ft3 65/ month j filter and waste collector per month filter (a) Abbreviations: F/D, filter /demineralizer; RCIC, reactor core isolation cooling; RWCU, reactor water cleanup system; SRW, solid radwaste; WCT, waste collector tank; FDCT, floor drain collector tank; RHR, residual heat removal. 4 (b)See Figure 3.5-1 W e l
~~.c.~~
W 4 I i I 1 1 i . I
TABLE 3.5-6 QUANTITIES OF SOLID RADIOACTIVE WASTE GENERATED AT THE PNPP Max. Waste Max. Total Generation Volume Activity Rate-Max. Waste Type (ft3 /yr) (Ci/yr) (lb waste / year) Waste sludge from RWCU 4,800 47,520 316,800 filter /demineralizer Waste sludge from conden- 60,000 3,090 3,960,000 sate filter / demineralizer Waste evaporator bottoms 16,000 445 1,232,000 Spent resins from conden- 6,240 32.1 446,160 sate demineralizer Spent resins from waste 6,048 1,210 432,430 demin., floor drains i demineralizer, and supp. pool demin. Waste sludge from fuel 3,996 61.9 263,700 pool filter demin.
~~'~'~~
Filter cake from floor 103.8 1.61 5,294 drain filter, waste collector filter Compressed waste 1,000 1 66,667 l l l C) 3.5-44
TABLE 3.5-7 O ISOTOPE INVENTORY OF LIQUID-RADWASTE -SYSTEM SLUDGES DELIVERED TO THE SOLID-RADWASTE TREATMENT SYSTEM Activity (a) (gCi) Condensate Radwaste Isotope F/D Sludge (D) Filter Sludge (c) Na-24 9.3+3 (d) P-32 1.5+4 1.1+2 Cr-51 4.4+5 5.2+4 Mn-54 4.0+4 1.0+5 Co-58 4.6+6 4.2+6 Co-60 5.2+5 1.5+6 Fe-59 7.2+4 3.1+4
~~'sn-65 2.0+3 4.5+3 Zn-69m 1.0+2 (d)~~
() Ag-110m 6.0+4 1.4+5 Ag-110 6.0+4 1.4+5 W-187 6.6+4 (d) Total 5.9+6 6.2+6 (a) Standard computer notation is used in this table; i.e., 9.3+3 = 9.3 x 10+3, (b) Activity based on 4-day accumulation of eight batches of condensate filter /demineralizer (F/D) sludge, followed by a 2-day decay period. (c) Activity based on 100-day accumulation of 149 batches of filter sludge from the waste-collector and floor-drain systems, followed by a 100-day decay period. (d) Negligible O 3.5-45
l TABLE 3.5-8 () ISOTOPE INVENTORY OF CHEMICAL WASTE CONCENTRATES DELIVERED TO THE SOLID-RADWASTE TREATMENT SYSTEM Concentration (a , b) Concentration (a,b) Isotope (pCi/ml) Isotope (yCi/ml) P-32 4.0-6 Te-132 1.9-5 Cr-51 3.1-4 I-132 1.9-5 Mn-54 7.7-5 Cs-137 1.8-2 Co-58 6.7-3 Ba-137m 1.8-2 Co-60 1.1-3 Ba-140 1.0-2 Fe-59 8.0-5 La-140 1.2-2 2n -65 3.8-6 Pr-143 5.3-5 I-131 4.0-2 Ce-144 2.1-3 Sr-89 6.9-2 Pr-144 2.1-3 Cs-134 1.1-2 Nd-147 8.9-6 Cs-136 1.5-4 Pm-147 2.0-6 Sr-90 1.7-2 Np-239 3.1-6 Y-90 1.7+2 Pu-239 2.8-7 Mo-99 1.9-6 Y-91 6.4-4 Tc-99m 2.1-6 Zr-95 1.2-3 Ru-103 3.1-4 Nb-95m 2.4-5 Rh-103m 3.0-4 Nb-95 1.5-3 Ru-106 1.7-4 Te-129m 5.1-4 ~, Rh-106m 1.7-4 Ce-141 1.3-3 (}
~~\_,<~~
Ag-110m Ag-110 1.2-4 1.2-4 Total 2.3-1 (a) Standard computer notation is used in this table; i.e., 4.0-6 = 4.0 x 10-6, (b) Activity in concentrated-waste tank based on 36.5-day accumulation of five batches of evaporator concentrate, followed by a 36.~5-day decay period. t l O l 3.5-46
TABLE 3.5-9 O
~~'d ISOTOPE INVENTORY OF RWCU FILTER /DEMINERALIZER SLUDGE, CONDENSATE DEMINERALIZER RESINS, AND RADWASTE DEMINERALIZER RESINS Delivered to the Solid-Radwaste Treatment System Activity (a) ( Ci)~~
Condensate Radwaste Demineralizer Demineralizer Isotope RWCU b) Sludge F/(D Resins (c) Resins (d) P-32 6.0+4 (e) (e) Cr-51 1.0+7 (e) (e) Mn-54 6.0+6 (e) (e) Co-58 3.9+8 (e) (e) Co-60 9.0+7 (e) (e) Fe-59 3.8+6 (e) (e) Zn-65 3.0+5 (e) (e) Br-83 (e) (e) 2.9+3 Br-84 (e) (e) 5.5+2 I-131 6.3+5 6.2 1.3+6 I-134 (e) (e) 8.2+3 Sr-89 4.9+7 2.1+4 1.9+6 Tc-101 (e) (e) 1.0+3 Cs-134 7.8+6 1.7+4 2.4+5 O Cs-136 7.5+4 (e) 1.9+4 (- Cs-138 (e) (e) 3.4+3 Ba-139 (e) (e) 1.1+4 Sr-90 1.2+7 3.0+4 3.8+5 Y-90 1.2+7 3.0+4 3.0+5 Sr-92 (e) (e) 2.8+4 Y-92 (e) (e) 4.2+4 Mo-99 1.6+1 (e) 7.2+5 Tc-99m 1.8+1 (e) 3.8+5 Ru-103 2.2+5 5.2+1 9.7+3 Rh-103m 2.1+5 5.0+1 4.9+3 Ru-106 1.2+5 2.2+2 3.6+3
~~, Rh-106 1.2+5 2.2+2 2.8+3 i~~
Ag-110m 8.5+6 (e) (e) Ag-110 8.5+6 (e) (e) Te-132 3.6+2 (e) 1.8+6 I-132 3.8+2 (e) 1.1+5 I-135 (e) (e) 1.7+5 Cs-137 163+7 3.1+4 3.9+5 Ba-137m 1.3+7 3.1+4 3.1+5 Ba-140 4.8+6 1.2+1 1.5+6 La-140 5.5+6 1.4+1 3.0+5 Ba-142 (e) (e) 9.8+2 s La-142 (e) (e) 3.5+3 Ce-143 (e) (e) 4.9+2 Pr-143 2.7+4 (ei 6.9+3 Ce-144 1.5+6 2.6+3 4.5+4 , s- Pr-144 1.5+6 2.6+3 3.5+4 3.5-47
TABLE 3.5-9 (Continued)
,/
ISOTOPE INVENTORY OF RWCU FILTER /DEMINERALIZER SLUDGE, CONDENSATE DEMINERALIZER RESINS, AND RADWASTE DEMINERALIZER RESINS Delivered to the Solid-Radwaste Treatment System Activity (a) (gCi) Condensate Radwaste Demineralizer Demineralizer Isotope RWCU Sludge F/(Db) Resins (c) Res ins (d) Nd-147 4.0+3 (e) 1.9+3 Pm-147 6.7+3 3.3 1.2+2 Np-239 9.5 (e) 6.4+6 Pu-239 1.6+3 (e) 2.9+6 Pr-85 (e) (e) 4.4+1 Sr-91 (e) (e) 1.7+5 Y-31m (e) (e) 1.7+4 Y-91 9.5+5 1.8+2 1.2+6
Zr-95 8.1+5 4.9+2 2.9+4 Nb-95m 1.7+4 1.0+1 4.0+2 Nb-95 1.3+6 9.2+2 3.7+4 Zr-97 (e) (e) 1.9+2 Nb-97m (e) (e) 1.4+1 Nb-97 (e) (e) 2.3+1 O
O Te-129m 3.5+5 5.8+1 1.7+4 Te-129 (e) (e) 4.1+1 I-129 (e) (e) 2.2+1 I-133 (e) (e) 6.5+5 Ba-141 (e) (e) 1.6+3 La-141 (e) (e) 1.3+4 Ce-141 8.3+5 1.3+2 1.1+7 Total 6.4+8 1.7+5 3.3r7 (a) Standard computer notation is used in this table, i.e., 2.7+4 = 2.7 x 10+4 (b) Activity based on 60-day accumulation of 38 batches of RWCU filter /demineralizer (F/D) sludge, followed by a 60-day decay period. (c) Activity bacc a on 3-month accumulation of soluble isotopes in condensate demineralizer (decontamination factor = 100), fol-lowed by 183-day decay in spent-resin tank. l (d) Activity based on 183-day accumulation in spent-resin tank of 11 batches of resins from waste-collector and floor-drain systems. (e) Neglig ible . l 3.5-48
I /% ( v TABLE 3.5-10 GASECUS AND AIRBORNE PROCESS AND EFFLUENT RADIATION MONI'IOR Radiation Monitor Sample Point Instrument Channels Function Location 1D17K610 A,B,C,D Pipewells in steam Ion chambers - Control Room alarms Steam Tunnel, 2D17K610 A,B,C,D tunnel downstream redundant channels and indication Auxiliary Main steam line of outer isolation Isolates main steam Building valve line 615' 1D17K612 Sample from steam Geiger-Mueller Control Room alarms Turbine 2D17K612 jet air ejectors and indication Building Of f-Gas Pretreatment 577' 1D17K601 A,B Sample frren carbon Ion chambers with Control Room alarms Off-Gas 2D17K601 A,B vault di; charge sample pump and indication Building w Of f-Gas Post-Treatment Isolates Off-Gas 584' w System
$ 1D17K611 A,B Detectors in carbon Geiger-Mueller Control Room Off-Gas 2D17K611 A,B bed vaults A and B indication and Building Carbon bed vault alarms 584' 1D17K609 A,B,C,D Ventilation duct Geiger-Mueller Control Room Intermediate 2D17K609 A,B,C,D downstream of redundant channels indication and Building, Containment containment alarms. Close containment ventilation exhaust isolation valve containment and ventl. exh.
drywell purge duct ventl. system valves 672' 1D17K690 A,B Isokinetic sample Gas scintillation Local and Control Intermediate 2D17K690 A,B downstream of filter channel and sample Room alarms and Building i Annulus exhaust trains filters for indication 620' train A and train B particulate and halogen with sample pump
D (3 C NJ\ () 'b TABLE 3.5-10 (Continued) GASEOUS AND AIRBORNE PROCESS AND EFFLUENT RADIATION MONI'IOR Radiation Monitor Sample Point Instrument Channels Function Location 1D17K780 Isokinetic sample 3-Channel, gas- Local and Control Intermediate 2017K780 from plant vent halogen-particulate, Room alarms and Building Unit vent exhaust autokinetic sampler scintillation type indication 682' with sample pump 1D17K850 Isokinetic sample 3-Channel, gas- Local and Control Heater bay 2D17K850 from HB/TB stack halogen-particulate, Room alarms and equipment Turbine Building - autokinetic sampler scintillation type indication house 667' heater bay with sample pump lD17K830 Isokinetic sample 3-Channel, gas- Local and Control Turbine f 2D17K830 from off-gas vent halogen-particulate, alarms and Building vi Off-gas vent pipe scintillation type indication 620'
~~& with sample pump o~~
ID17K840 Steam packing In-line gas Control Room alarms Turbine 2Dl7K840 exhauster effluent scintillation and indication Building Steam packing line channel 624' exhauster NOTE: Tag numbers with 1D17K---are associated with Unit 1; 2D17K---are associated with Unit 2; and D17K---are common to Unit 1 and Unit 2.
\
v g \ TABLE 3.5-11 LIQUID PROCESS AND EFFLUENT RADIATION MONI'IORS Radiation Monitor Sample Point Instrument Channels Function Locatior. 1D17K604 - 2D17K604 ESW - Loop A Gamma - scint., Contro'. Room Auxiliary Emergency Service downstream of RHR offline indication and alarm Building Water Loop A Heat Exchanger with sample pump 568' - East and West ! ID17K605 - 2D17K605 ESW - Loop B Gamma - scint., Control Room Auxiliary Emergency Service downstream of RHR offline indication and alarm Building Water Loop B Heat Exchanger with sample pump 568' - West and East Dl7K607 Downstream of Gamma - scint., Control Room Control Complex Nuclear Closed nuclear closed offline indication and alaria 599' , Cooling System Cooling Heat with sample pump p3 Exchangers un ji D17K606 Radwaste line Gamma - scint., Control Room and Auxiliary H Radwaste Effluent downstreaia of offline Radwaste PNL Building to ESW - Discharge discharge valves with sample pump indication and 620' - East Pipe PCV-F153 and PCV-155 alarm. Close discharge valve on high trip. D17K608 Radwaste line Gamma - scint., Control Room and Control Complex Radwaste Effluent downstream of offline Radwaste PNL 599' to Sanitary Waste discharge valve with sample pump indicator and PCV-F158 alarm. Close discharge valve on high trip. D17K820 A&B Gravity Drain System Gamma - scint., Control Room Gravity Drain Underdrain System discharge lines inline indication and System Manhole alarm. Stop No. 20 & 23, underdrain pumps on 608' high trip. NO"E: Tag numbers with IDl7K---associated with Unit 1, 2D17K---associated with Unit 2, and D17K---are common to Unit 1 and Unit 2.
O O O TABLE 3.5-12 PROCESS AND EFFLUENT RADIATION MONITORING SYSTEM CHARACTERISTICS No. of Trips High (Trip) Prealara Monitoring Number
~~Detector Instrument Upscale - Setpoint Setpoint Systems of Units Sensitivity Range (Scale) Downscale (a) (a)~~
Main Steam Lines 4-lc 3.7 x 10-10 amp /R/hr (b) I to 106 ar/br 2-1 Technical Variable Specification Off-Gas Pretreatment 1-GM - 1 to 106 mr/hr 2-1 (c) variable Off-Gas Post- 2-CM 10-6 pCi/ml 10 to 106 2-1 (c) Variable Treatment counts / min. Carbon Bed Vault 2-GM - 1 to 106 mr/hr 1-1 (c) -- Containment ventl. 4-GM --
.01 to 100 mr/hr 2-1 Technical V...able Exhaust (each channel) Specification Annulus Exhaust 1-GSP 106 pci/ml (Er-85) 10 to 106 2-1 Technical Variable counts /nin. Specification Unit Vent Exhaust 1-GSP 10-6 pCi/ml (Kr-85) 10 to 106 2-1 Technical Variable y 1-PSP 2.7 x 10-11 (Cs-137) counts / min. Specification (d) e 1-HSP 1.6 x 10-11 pC1/ml (each channel)
Ln (I-131) 8 [ Turbine Bldg. - 1-GSP 10-6 pCi/ml (Kr-85) 10 to 106 2-1 Technical Variable Heater Bay 1-PSP 2.7 x 10-11 pCi/ml counts / min. Specification (d) (Cs-137) (each channel) 1-HSP 1.6 x 10-11 pCi/ml (I-131) Off-Gas Vent 1-GSP 10-6 pC1/ml (Kr-85) 10 to 106 2-1 Technical Variable 1-PSP 2.7 x 10-11 pCi/nl counts / min. Specification (d) (Cs-137) (each channel) 1-HSP 1.6 x 10-11 pCl/ml (I-131) Steam Packing 1-GSP 2 x 10-6 pC1/ml 10 to 106 2-1 Technical variable Exhauster (Xe-133) counts / min. Specification Emergency Service 1-ISP 1 x 10-6 pCi/ml 10 to 106 1-1 7 x 103 cpn(*) -- Water loop A (Cs-137) counts / min. Emergency Service 1-LSP 1 x 10-6 pC1/ml 10 to 106 1-1 7 x 103 epm (*) -- Water toop B (Cs-137) counts / min. Nuclear Closed 1-LSP 1 x 10-6 pCi/ml 10 to 106 1-1 104 cpe (e) __ Cooling Water (Cs-137) counts / min. Plant Radwaste 1-ISP 1 x 10-6 pC1/ml 10 to 106 1-1 Technical -- Discharge - ESW (Cs-137) counts / min. SpecificationId) Discharge
o o o TABLE 3.5-12 (Continued) PROCESS AND EETLUENT RADIATION MONI'!ORING SYSTEM CliARACTERISTICS No. of Trips High (Tript Prealara Monitoring Number
~~Detector Instrument Upscale - Setpoint Setpoint Systems of Units Sensitivity Range (Scale) Downscale (a) (a)~~
Plant Radwaste 1-MP 1 x 10-6 pCi/ml 10 to 106 1-1 Technical -- Discharge - Sanitary (Cs-137) counts / min. Specification (d) Waste Underdrain 1-MP 1 x 10-6 pC1/ml 10 to 106 2-1 Technical Variable (d) (I-131) counts / min. Specification
~~KEY:~~
GM Geiger-Muller detector IC Ion chamber detector GSP Gas chanber scintillator-photomultiplier detector PSP Particulate filter scintillator-photomultiplier detector w HSP Halogen cartridge scintillator-photanultiplier detector
~~LSP Liquid scintillator-photomultiplier detector tn h~~
w (a)Setpoints to be revised as required to be campatible with limits established and current calibrated sensitivity of the applicable channel. i (b) Physical orientation and installation shall determine relative sensitivity end set point. (c) Set point determination will depend on source geometry, radiation background, and shielding. (d) Basis for set point calculations:
a. Calculation based on perimeter limits for unrestricted areas as per Table II of 10 CFR 20

b. Average long-term release limits based on mixing and diffusion factors in FSAR

c. Set points for high set point to include total error

d. As low as practicable quantities to be detersined by laboratory analysis for reporting quantities, i.e.,
laboratory analysis of filters and samples I') Initial setpoint at twice background. .f I i
p b ( V TABLE 3.5-13 RADIOLOGICAL ANALYSIS SUW4ARY OF LIQUID PROCESS SAMPLES Grab suple Sensitivity Sample Description Frequency Analysis ( pCi/ml) Purpose Reactor Coolant Filtrate Daily (a) Gross Gammaa 10-6 Evaluate reactor water activity Crud Daily (a) Gross Gamuna 10-6 Evaluate crud activity Filtrate Weekly (b) I_131, g.133 5 x 10-7 Evaluate fuel cladding integrity Crud and Filtrate Weekly Gamma Spectrum 5 x 10*7 Determine radionuclides present in system Reactor Water Cleanup Biweekly Gross Gamuna 10-6 Evaluate cleanup efficiency System condenser Demineralizer Influent Monthly Gross Gamuna 10-6 Evaluate carryover Effluent Monthly Gross Gaassa 10-6 Evaluate demineralizer performance bJ Condensate Storage Tank A Weekly Gross Gamma 10-6 Tank inventory f Condensate Storage Tank B Weekly Cross Gausea 10-6 Tank inventory Ln A Fuel Pool Filter - Demineralizer Inlet and Outlet Periodically Gross Ganuna 10-6 Evaluate system performance Waste Collector Tank Periodically Gross Gauuna 10-6 Evaluate system performance Floor Drain Collector Periodically Gross Gammaa 10-6 Evaluate system performance Tank Chemical Waste Tank Periodically Cross Ganuma 10-6 Evaluate system performance l Evaporator Bottoms Periodically Gross Gauuna 10-6 Comparison of activity with that determined by drum readings l Evaporator Distillate Periodically Gross Ganuna 10-6 raluate evaporator performance Tanks (b) Nuclear Closed Cooling Periodically Gross Ganuna 10-6 Evaluate system integrity (a) Daily means five times per week. (b) Performed more frequently if increase noted on daily gross ganuma count.
o O O TABLE 3.5-14 f RADIOLOGICAL ANALYSIS SUMARY OF GASEOUS PROCESS SAMPLES Sample Sensitivity , Sample Description Frequency Analysis (pCi/ml) Purpose Off-gas Monitor (SJAE) Monthly Gamma Spectrum 10-4 Determine off-gas activity Sample Post-Treatment Sample Monthly Gamma Spectrum 10-4 Determine off-gas system cleanup performance l ) W ' e l U1 4 i 4 L 9 9 l ^ i e
o o o TABLE 3.5-15 RADIOIDGICAL ANALYSIS SUINARY OF LIQUID EFFLUENT SAMPLES Sample Sensitivity Sample Description Frequency Analysis (PCi/ml) Purpose Floor Drain Sample Tank Batch (a) Gamma Spectrum 5 x 10-7 Effluent discharge record Waste Sample Tanks (b) Batch (a) Gamma Spectrum 5 x 10-7 Effluent discharge record Detergent Drain Tanks (b) Batch (a) Gamma Spectrum 5 x 10-7 Effluent discharge record Liquid Radwaste Effluents Batch (a) Gamma Spectrum 5 x 10-7 Effluent discharge record and Ba/La-140 and I-131 78 Composite of all Monthly Gamma Spectrum 5 x 10-7 us tanks discharged Tritium 5 x 10-5 di Gross Alpha 10-7
Dissolved Gas (b) 10-5 Quarterly Sr-89/90 5 x 10-8 Circulating Water Weekly grab Gross Gamma 5 x 10-7 Effluent discharge record Decant Line of contin- Tritium 5 x 10-5 (backup sample) uously col-lected pro-portional sample Underdrain sump Weekly Gross Ganna 5 x 10-7 Effluent discharge record (a)If tank is to be discharged, analyses will be performed on each batch. If tank is not to be discharged, analyses will be performed periodically to evaluate equipment performance.
(b)If no discharge event occurs during the week, frequency shall be so adjusted.
o o o TABLE 3.5-16 PADIOIOGICAL ANALYSIS SUMARY OF GASEOUS EFFLUENT SAMPLES Sample Sensitivity Sample Description Frequency Analysis (pCi/ml) Purpose Plant vents, heater bay / Weekly Principal pamma 10-11 Effluent Record turbine building vents, emitters (as for off-gas vent pipe at least I-131 and Ba-La-140 I-131 (b) 10-12 . Monthly Principal panuna 10-4 emitters (ci 1 Gross Alpha (a,b) 10-11 I-133 and 135 10-10 y (a)On particulate filter m (b)On charcoal cartridge (c) Gas samples ]
TABLE 3.5-17 PROCESS SAMPLING SYSTEM Description Location Purpose Reactor Steam Supply System Reactor Water Recirculation Pump Reactor Water Quality Discharge Main Steam Main Steam Line Carryover / Moisture Reactor Water Cleanup System Filter /Demineralizer Inlet Line Reactor Water Quality Influent Filter /Demineralizer Outlet Line Filter Efficiency Effluent Fuel Pool Cooling snd Cleanup System Filter Influent Inlet Line Fuel Pool Water Quality O
'~
Filter Effluent Outlet Line Filter Efficiency Demineralizer Outlet Line Demineralizer Efficiency Effluent Containment Vessel and Turbine Building Closed Loop Cooling Water System Cooling Water Sample Outlet of Each Major Monitor Heat Exchanger Heat Exchanger Leaks
, Condensate System Condensate Condensate Pump Condensate Quality Discharge and Tube Leaks Condensate Demineralizer Treated Condensate Demineralizer Outlet Pipe Quality Effluent l
Condensate Hotwell Tube Leaks l l 3.5-58
TABLE 3.5-17 (Continued) PROCESS SAMPLING SYSTEM Description Location Purpose Emergency Service Water System RHR Cooling, Loop A - Outlet of RHR Heat Exchanger Tube Leaks / Activity RHR Cooling, Loop B - Outlet of RHR Heat Exchanger Tube Leaks / Activity < Main Condenser Circulating Water System Influent Discharge of Circu- Determine Background lating Water Pump Effluent Discharge Canal Monitor added activity of discharge Radwaste System Regenerant Evaporator Recycle Line Process Data Feed Tank Regenerant Evaporator Recycle Line Process Data V Bottoms Tank 4 Waste Collector Tank Recycle Line Process Data Floor Drain Collector Recycle Line Process Data Tank Radwaste Filter Outlet Line Filter Efficiency Effluent Radwaste Demineralizer Outlet Line Demineralizer Effluent Efficiency Floor Drain Filter Outlet Line Filter Efficiency Effluent Waste Evaporator Recycle Line Process Data Bottoms Waste Evaporator Recycle Line Process Data Sample Tank Discharge Sample Recycle Line Water Quality Tank O 3.5-59
TABLE 3.5-17 (Continued) A U PROCESS SAMPLING SYSTEM Description Location Purpose Recovery Sample Recycle Line Water Quality Tank Discharge Control Discharge Line Water Quality and Monitor Station Liquid Activity Roleases SJAE Off-gas System Off-gas Sample Upstream of Final Evaluate Gas Composition SJAE and Isotopic Composition of Off-gas Off-gas Sample Downstream of Off- Evaluate Recombiner gas Condenser Performance and Subsystem DF, Isotopic Composition Off-gas Sample Upstream of Charcoal Evaluate Gas Dryer Adsorber Performance and DF e Off-gas Sample Downstream of 1st Evaluate Charcoal Noble Charcoal Adsorber Gas Delay Off-gas Sample Downstream of Final Evaluate Charcoal Noble Charcoal Adsorber Gas Delay, Isotopic Composition l l l 3.5-60 i l 1
RHR FLUSN CONDENSATE
~~@-- l ERAlllER ;~~
lfilT"' -G l r--q) i h nA5TE 150 GPM i { + mASTE COLLECTGR 4 1 COLLECTOR : TANKS @Q FILTER UC 35.000 GAL (2) I I A l CASR PIT ORA @0WN b 'To SOLID l RA3nASTE 7 l DECANT FROM SOLl0 RADwASTE TREATMENT SfSTEM V g . (* I TREATMENTI SYSTEM g
~~@, @ I I I~~
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TAN S F LTER 0tg 35.000 GAL. (2) CONDENSATE E NT rT DEMINERAlllER REGENERATION g SOLUTIONS l ir
}
~~CHEMICAL~~
*8E, - EVAPORATOR / _
TA K " ONENSR 'A" g 20.000 GAL. 30 GPM I LA80RATORf f -- DRAINS
' h h l CNEMICAL l 00 1 WASTE t E v&POR ATOR / ; O 30 G CONDENSER *B. }
20 0 GA . 20 l' CONI PERSONNEL ' WAS DECONTAMINATION 5000 STAfl0NS 9 DE1ERGENT l DETERGENT DRAINS A 1 OIAINI i TO SANITARY TANFS 1600 GAL. (2) U34 T:LTERS(2) D r TREATMENT $s 50 100 GPM CONDENSATE C SM CONDENSATE FILTER l CONDENSATE FILTER 450 GPM BACKmASH l A l gggggggg RECElVING TANuS @ - SETTLING TANRS : DE 10.000 GAL.(2) 450 GPM 21.000 GAL. (2) 0-50 GPM
' TO SOLIO RA0w&STE RWCU F/D TREATMENT SYSTEM BACRnASH #wCU FILTER / 350 GPM RWCU FILTER / /
~~( DEMINERAlllER - DEMINERALIZER O 8ACNWASM RECElVING TANKS~~
@A BACFWASM U Tyu gg u ng3 @ C DEC 50 GPM 3300 GAL. (2) 4500 GAL (2)
I TO SQL10 RADWAs TREATMENT SYSTE 0-50 GPM
l LEGEND: PRIMARY FLOW PATH l 200 GPM $ SECONDARY FLOW PATH WASTE D. WASTE SAMPLE 9 NERALIZER D I TANKS 35.000 GAL.(2) r TO CONDENSATE STOPAGE TANN UNIT I - - - ALTERNATE FLOW PATH STREAM NUMBER I 0-200 GPM TO DISCMARGE (SEE TABLE 3.5-5) _ CANAL l l h LOCATION MARMER I I I l r-4 l 200 GPM >R DRAINS G28 f FLOOR ORAIN g g _ TO CONDENSATE NERAlllER U SAMPLE TANAS g29 35.000 GAL. (2) STORAGE TANE UNIT I 0-200 GPM TO OlSCHARGE
-' CAhAL CAL TASTE SPENT kESINS SPENT RESINS TILLATE FROM CONDENSATE FROM SUPPRES$10N ng =ga 19 -
~~D DEMINERALIZER POOL DEMINERALIZER GAL. SPENT RESINS~~
~~TO DISCHARGE FROM WASTE 14 CANAL DEMINER ALIZER~~
- TO CONDENSATE SPENT RESINS STORAGE TANK FROM FLOOR ORAINS UNIT I DEMINERALIIER ,r .r ir i, CAL TASTE SIENT RESIN TILLATE TANKS O40 - TO SOLID RADwASTE WE "B" 10.000 GAL.(2) U TREATMENT SYSTEM f00 GAL.
EXTRATED o TO SOLID RADWASTE AL ) 0-50 GPM r-O I PASTE 8ACrwASN FROM FUEL P00L l 18 (EM FILTER /DEMINERALIZERS { FUEL POOL F/D 450 GPM DRANT SET L T NxS 21.000 GAL.(2) ANT 39 0 C GPM TO SOLID RADwASTE TiEATMENT SYSTEM , LIQUID RADWASTE TREATMENT T SYSTEM FLOW DIAGRAM o PERRY NUCLEAH POWER PI ANT 1 & 2 THE CLEVELAND ELECTRIC ILLUMINATING COMPANY FIGURE 3.5-1 1 3.5-61 l
I c i 40/100/0 (SEE NOTE 1)
~~REUSE l~~
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~~FILTER & ; REUSE 1 DEMlHERALIZE 1~~
~~N 100/100/50~~
~~REUSE BODY FEED + EVAPORATE DEMINERALIZE 10/100/20 & FILTER & CONDENSE L - - - - .J 0/100 l* DISCHARGE~~
~~/50 l~~
s MEDIUM-TO-LOW 60/100/50 BODY FEED, PURITY WASTES : FILTER & ; REUSE D EMIN ER ALIZ E 100/100/50
~~REUSE BODY FEED EVAPORATE~~
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~~40/100/50 [ _ _ _ _ y */100 0 DISCHARGE~~
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~~CHEMICAL WASTES 3 l 0/100/10~~
~~f. :~~
L____ DISCH ARG E CONCENTRATE 1 r L TEMPORARY TO SOLID STORAGE : R ADIO ACTIVE I WASTE DISPOSAL l
l DETERGENT 100/100/100 TR ANSFER TO CASTES FILTER : SANITARY WASTE SYSTEM r FILTER + & CONDENSATE 9 DMINERAUZE + DISCH AR GE , l L _ _ _ _ .a ' SEE NOTE 2 (TYPICAL) DECANT TO HIGH PURITY OR
~~MEDIUM-TO-LOW PURITY WASTE TRE ATMENT SUBSYSTEMS l~~
~~FILTER _ SETTLE & BACKCASH - DECANT SLUDGE TO SOLID RADIOACTIVE WASTE DISPOSAL SYSTEM~~
~~- TEMPORARY TO SOLID RADIOACTIVE SPENT RESINS ' ;~~
~~STORAGE WASTE DISPOSAL SYSTEM NOTES:~~
1. THE THREE PERCENTAGES GIVEN FOR EACH FLOW PATH REPRESENT, IN ORDER, a) THE PERCENTAJE OF THE TOTAL FLOW NORMALLY EXPECTED TO USE THAT FLOW PATH, b) THE PERCENTAGE OF THE TOTAL FLOW USED TO DESIGN AND SIZE EQUIPMENT AND PWING FOR THAT FLOW PATH, AND c) THE PERCENTAGE OF THE TOTAL FLOW USED TO CALCULATE THE QUANTITY OF RADIOACTIVE ISOTOPES DISCHARGED BY WAY OF THAT FLOW P ATH.

2. EVAPORATOR DISTILLATE CAN BE DISCHARGED DIRECTLY (WITHOU r DEMINERALIZING) IF IT MEETS DISCH ARGE WATER QUALITY SPECIFICATIONS.
2
~~SUMMARY~~
OF PROCESS FLOW PATHS , FOR ESTIMATING ANNUAL RADWASTE LIQUID RELEASES PERRY NUCLEAR POWER PLANT 1 & 2 THE CLEVELAND ELECTRIC ILLUMINATING COMPANY FIGURE 3.5-2 3.5-62
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o o o NOTE 1: ALL FLOW RATES SHOWN ARE INTERMITTENT. NOTE 2: X REFERS TO STREAM NUMBER (TABLE 3.5-5) CAKE CAKE COMPACTED WASTE COMPRESSIBLE WASTE gggppggg (RAGS, PAPE R, ; CONTAINERS CLOTHING, ETC.) AS E g 1 r 1 r 0-50 GPM FROM CNWT 1 033 0--50 GPM w FROM RBST 5 m SOLIDIFIED ' g 0-50 GPM WASTE SOLIDIFICATION m FROM FBST ; 15-40 GPM WASTE m ; ; SYSTEM SHIPPING ; 6 TO oOT , 0-50 GPM CONTAINERS LICENSED TRUCK FROM SRT :
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s. e. _ - . . ........_...n. 6 .g LIOUlD PROCESS STREAMS 7 PERRY NUCLEAR POWER PLANT 1 & 2 THE CLEVELAND ELECTRIC ILLUMINATING COMPANY FIGURE 3.5-7 3.5-67
O : 1 APPENDIX A3.5 l l 4 DATA NEEDED FOR RADIOACTIVE
~~' SOURCE TERM CALCULATIONS l~~
' \ l l 4 ( i i j O l
I. GENERAL () Question 1: The maximum core thermal power (MWt) evaluated for safety considerations in the SAR. Answer: The maximum core thermal power is 3,758 MWt. , Question 2: Core properties:
a. The total mass (1b) of uranium and plutonium in an equilibrium core (metal weight).

b. The percent enrichment of uranium in reload fuel, and

c. The percent of fissile plutonium in reload fuel.
Answer: The approximate mass of uranium and plutonium in an equilibrium core is given as follows: Total Uranium - 292,000 lbs U - 3,915 lbs Fk$bilePlutonium - 1,538 lbs Information on reload fuel is not available for the PNPP. Question 3: If methods and parameters used in estimating the source terms in the primary coolant are different from those given in Regulatory Guide 1.112, " Calculation of Releases of Radioactive Materials in Gaseous and Liquid Effluents from Light-Water-Cooled Power Reactors," describe in detail the methods and parameters used. Include the following information:
a. Plant capacity factor,

b. Isotopic release rates of noble gases to the reactor coolant at 30-minute decay igCi/sec), and

c. Concentration of fission, corrosion, and activation products in the reactor i coolant (pCi/sec) . l The quantity of tritium released in liquid and gaseous effluents (Ci/yr per reactor).
Answer: The methods and parameters used are consistent with Regulatory Guide 1.112. A3.5-1
II. NUCLEAR STEAM SUPPLY SYSTEM 1 () Question 1: Total steam flow rate (lb/hr). 6 Answer: The total main steam flow rate is 15.4x10 lb/hr. Question 2: Mass of reactor coolant (lb) and steam (lb) in the reactor vessel at full power. Answer: The mass of reactgr coolant in the reactor vessel is 5.2sx10 lb. 4 The mass of steam is 1.93x10 lb. III. REACTOR COOLANT CLEANUP SYSTEM Question 1: Averagc flow rate (lb/hr). Answer: The average flow rate is 1.54x10 5 lb/hr. Question 2: Demineralizer type (deep bed or powdered resin). Answer: The RWC demineralizers are of the powdered resin type. () Question 3: Regeneration frequency. Answer: The RWCU filter /demineralizers are not designed to be regenerated. Question 4: Regenerant volume (gal / event) and activity. Answer: Not applicable to Perry. IV. CONDENSATE DEMINERALIZERS Question 1: Average flow rate (lb/hr). Answer: The average flow r&te is 10.5x10 6 lb/hr. i Question 2: Demineralizer type (deep bed or powdered l resin). Answer: The condensate demineralizers are the deep bed type. Question 3: Number and size (ft3 ) of demineralizers. Answer: There are six condensate demineralizers each {} containing 260 cubic feet of mixed resin. A3.5-2
Question 4: Regeneration frequency. () Answer: The regeneration frequency is assumed at 3.5 days per demineralizer for a total regenera-tion time of 21 days. Question 5: Indicate whether ultrasonic resin cleaning is used and the waste liquid volume associated with its use. Answer: Ultrasonic cleaning is not used. Question 6: Regenerant volume (gal / event) and activity. Answer: 12,000 gal / batch - The activity is calcu-lated internally by the BWR-GALE code. V. LIQUID WASTE PROC 2SSING SYSTEMS Question 1: For each liquid waste processing system, provide in tabular form the following infor-mation
~~a. Sources, flow rates (gpd), and expected activities (fraction of primary coolant activity, PCA) for all inputs to each~~
~~/' system, b) b. Holdup times associated with collection, processing, and discharge of all liquid streams,~~
c. Capacities of all tanks (gal) and proces-sing equipment (gpd) considered in calcu-lating holdup times,

d. Decontamination factors for each processing step,

e. Fraction of each processing stream expected to be discharged over the life of the station.
~~Answer:~~
~~l l~~
A3.5-3 l i
o o o Holdup Fraction of Times Flow III Primary Collection / Fraction Rates Coolant Discharge Assumed Name Sources (gpd) Activity (days) Discharge High Purity Equipment Drains Waste Drywell 4300 1 1.7/.65 0.1 Containment 2550 .01 1.7/.65 0.1 Radwaste Building 500 .01 1.7/.05 0.1 Turbine Building 5760 .01 1.7/.65 0.1 Auxiliary Building 60 .01 1.7/.65 0.1 Intermediate Building 25 .01 1.7/.65 0.1 Control Complex 50 Negligible 1.7/.65 0.1 Drywell and Containment Steam Valves 1685 .01 1.7/.65 0.1 Cond. Demin. Rinse 1230 .002 1.7/.65 0.1 RHR Flush / Text 340 Negligible 1.7/.65 0.1 [ Low Purity Floor Drains
. Waste Drywell 720 1 1.7/.65 0.25 T Containment 1000 .01 1.7/.65 0.25 Turbine Building 2000 .01 1.7/.65 0.25 Radwaste Building 500 .01 1.7/.65 0.25 Auxiliary Building 200 .01 1.7/.65 0.25 Intermediate Building 800 .01 1.7/.65 0.25 Decantate 2210 .002 1.7/.65 0.25 1
Chemical Chemical Drains 275 .02 6.1/.37(3) 0.1 Waste Regenerant Cond. Mixed Bed Demin. Waste Reg. Scl. 820 (2) 6.1/.37(3) 0.l* (1) Values based on one-half of the total flow for two units. II Value calculated internally in BWR-GALE code. I } Collection time is based on total flow for chemical waste and regenerant waste since they utilize a common tank.
g , (~)) e g Q Decontaminatian Factors Halogens /Csr Rb/Other Name Component Capacity Nuclidya High Purity Waste Collector Tank 35,000 gallons N/A II Waste Waste Sample Tank 35,000 gallons N/A Waste Waste Collector Filter Evaporator 144,000 43,200 gpd gpd 10 31/lfl 10 /1g 4 Waste Demineralizer 288,000 gpd 10 /10/10 Low Purity Floor Drains Collector 35,000 gallons N/A Waste Tank Floor Drains Sample 35,000 gallons N/A Tank Floor Drains Filter Waste Evaporator 144,000 gpd 43,200 gpa 31/lfl 10fl0/lg 4 Floor Drains Demineralizer 288,000 gpd 10 /2/10 Chemical Chemical Waste Tank 20,000 gallons N/A [ Waste Chemical Waste 20,000 gallons N/A Dist.'.llate Tank 3 4 4 T Waste Evaporator 43,200 gpd 10fl0/lg Waste or Floor Drains 288,000 gpd 10 /2/10 Demineralizer Regenerant (2) (2) (2) Waste I1I N/A - Not Applicable (2)Part of chemical waste system
Question V.1 () f. For waste demineralizer regeneration, time between regenerations, regenerant volumes and activities, treatment of regenerants, and fractions of regenerant discharged (include parameters used in making these determinations), and
~~g. Liquid source term by radionuclide in Ci/yr for normal operation, including anticipated operational occurrences.~~
Answer: The waste demineralizers are mixed bed, nonre-generative demineralizers. The liquid source term is calculated by the BWR-GALE code and the resultant discharges are given in Table 3.5-3. Question 2: Piping and instrumentation diagrams (P& ids) and process flow diagrams for the liquid radwaste systems along with all other systems influencing the source term calculations. Answer: The P& ids and flow diagrams for the liquid radwaste system are shown in Figure 13.2-1 [("D _) of the PNPP-FSAR. VI. MAIN CONDENSER AND TURBINE GLAND SEAL AIR REMOVAL SYSTEMS Question 1: The holdup time (hr) for offgases from the main condenser air ejector prior to processing by the offgas treatment system. Answer: The holdup time for offgases is 0.167 hr (10 min.). Question 2: Description and expected performance of the gaseous waste treatment systems for the off-gases from the condenser air ejector and mechanical vacuum pump. The expected air inleakage per condenser shell, the number of condenser shells, and the iodine source term from the condenser. Answer: Release from the Lo Temp Rechar Off-Gas System is strongly a function of condenser air inleak-4g0. Delay rates as a function of air inleak-age are as follows: (~') v A3.5-6
~~- - - _ _ . - . _ _ _ ~ -_~~
Air Inleakage Holdup Time (SCFM) Krypton Xenon O 20 70 hours 65 days
30 46 hours 42 days 40 35 hours 32 days 50 28 hours 26 days 60 23 hours 21 days The actual values used in calculating the
. gaseous releases for the PNPP in the GALE code are 1.86 days and 42.6 days for krypton and xenon, respectively. Mechanical vacuum pumps are used to evacuste 1 to the condenser prior to turbine startup. They discharge to the atmospheric vent. At no time are the mechanical vacuum pumps in operation while steam from the main turbine ! generator is being condensed in the main condenser. The expected air inleakage per condenser shell is 10 cfm. The PNPP utilizes a three shell condenser. The radiciodine input rate to the main conden-Os ser offgas system is 5 Ci/yr per reactor downstream of the main condenser air ejectors. .t Question 3: The mass of charcoal (tons) in the charcoal delay system used to treat the offgases from the main condenser air ejector, the operating and dew point temperatures of the delay system, and the dynamic adsorption coefficients for Xe and Kr. Answer: The mass of charcoal in the offgas system is approximately 24 tons. The ogerating agd dew point temperatures are 0 F and -20 F, respectively. The and dynamic Kr are 2410 adsorpg/g cm and 105 cm /g, ionrespec- coefficiegt for Xe tively. Quetion 4: Description of cryogenic distillation syr, tem, fraction of gases partitioned during distilla-tion, holdup in system, storage following distillation, and expected system leakage rate. This type of system is not used on the PNPP.
~
Answer: A3.5-7
Question 5: The steam flow (lb/hr) to the turbine gland seal and the source of the steam (primary or auxiliary). (]) Answer: The steam flow to the turbine gland seal is normally 25,000 lb/hr. Clean steam generated by a reboiler is used in the gland seal system. Question 6: The design holdup time (br) for gas vented from the gland seal condenser, the iodine partition factor for the condenser, and the fraction of radioiodine released through the system vent. Description of the treatment system used to reduce radioiodine and particu-late releases from the gland seal system. Answer: Not applicable to the PNPP. Question 7: Piping and instrumentation diagrams (P& ids) and process flow diagrams for the gaseous waste treatment system along with all other systems influencing the source term calcula-tions. Answer: The P& ids and process flow diagrams are shown in Figure 11.3-1 or the FSAR. VII. VENTILATION AND EXHAUST SYSTEMT, For each station building hcusing system that contains radioactive materials, prceide the following:
1. Provisions incorporated to reduce radioactivity releases through the ventilation or exhaust systems.

2. Decontamination factors assumed and the bases (include charcoal adsorbers, HEPA filters, mechanical' devices').

3. Release rates for radioiodines, noble gases, and radio-active particulates (Ci/hr) and the bases.
~~l 4. Release point to the environment including height, effluent temperature and exit velocity. l~~
~~5. For the containment building, indicate the expected purge and venting frequencies and duration, and contin-uous purge rate (if used).~~
I A V A3.5-3
Purge Rate and Decontamination DF Frequency (Reactor O Building _ Factors (DF) Bases Building only) i Reactor Building 100 HEPA 5,000 cfm, continuous 10 Charcoal 30,000 cfm, refueling Auxiliary Building 100 HEPA 10 Charcoal Radwaste Building 100 HEPA 10 Charcoal Turbine Building 1 - 1 - Off-Gas Building 100 HEPA 10 Charcoal The reactor building, auxiliary building, and radwaste building releases are via the plant vent. The turbine building is via the turbine building / heater bay vent. The off-gas building is via the off-gas vent. See Figures 3.1-2 and 3.5-5. The maximum effluent tempera-ture of the gases and the effluent velocity from these
~~,s) systems are given as follows:~~
Effluent Effluent Gas Velocity Temperature Release Points (ft/ min) (max) Unit 1 Plant Vent (cont.) 4100 1050F Turbine Building 4000 115 F (Heater Bay Vent) Off-Gas Building 1900 105 F Unit 2 Plant Vent (cont.) 3500 105 F Turbine Building 4000 115 F (Heater Bay Vent) Off-Gas Building 1900 105 F The release rates were calculated using the BWR-GALE code and are given in Tables 3.5-4 and 3.5-5. l l A3.5-9 1 l j
l VIII. SOLID WASTE PROCESSING SYSTEMS I) Question 1: In tabular form, provide the following informa-d waste tion concerning processing system:allsou.ce, inoutsvolume to the (ft solj/yr per reactor), and activity (Ci/yr per reactor) of principal radionuclides along with bases for values. Answer: The inputs to the solid waste processing system.are presented in Table 3.5-5. Quantities of solid radioactive wastes generated at PNPP are given in Table 3.5-6. Question 2: Onsite storage provisions (location and capacity) and expected onsite storage times for all solid wastes prior to shipment. Answer: The solid radwaste storage area is located on the 616'-0" elevation of the Radwaste Building. Normally only one months' production or less is kept in the storage area, however, l capability has been provided to store up to 1% months' production at the plant. The onsite storage time is expected to be one month or less prior to shipment. (3
\ ,/ Question 3

Piping and instrumentation diagrams (P& ids) and process flow diagrams for the solid rad-waste system.
~~Answer: The flow diagram for the solid radwaste system is given in Figure 11.5-1 of the TSAR. l l l l i /" V) A3.5-10~~
~~'s 3.6 CHEMICAL AND BIOCIDE WASTE SYSTEMS This section is essentially unchanged from that in the ER/CP.~~
~~3.6.1 CHEMILsL WASTE SYSTEMS Chemical nonradioactive wastes will be discharged from two major systems, as shown in Figure 3.6-1:~~
a. Cycle makeup

b. Chemical cleaning wastes (startup)
The chemical cleaning will be done only several ti;nes during the life of the plant; therefore, these wastes will be minimal. The chemicals used in the plant are required for the regenera-tion of ion-exchange resins. The regeneration wastes produced by these chemical processes will be collected in neutralization {
~~'- basins. The regenerative wastes will be neutralized to a pH of 6 to 9 to meet discharge limits. The neutralized wastes will be blended into the plant cooling-water discharge.~~
3.6.1.1 Cycle-Makeup Demineralizer The purpose of the cycle-makeup demineralizer is to purify the makeup water for the plant steam cycle. The demineralizer system consists of two parallel cation-anion tanks and one mixed-bed tank, each with a capacity of 360 gallons per minute. The demineralizer resins will be regenerated with 2 and 4 percent sulfuric acid and 4 percent sodium hydroxide. The quantities used for each regeneration will be approximately 260 pounds of 66 Be sulfuric acid for the cation unit, approxi-mately 283 pounds of 100 percent sodium hydroxide for the anion unit, and approximately 153 pounds of 66 Be sulfuric gg acid and approximately 111 pounds of 100 percent sodium hydrox-
%/
3.6-1
ide for the mixed unit. The resulting solutions will be clear; they will be collected in a neutralizing pit and further diluted with backwash and rinse water to less than 1.43 percent by weight, containing mostly sodium and sulfate. The pH of the waste solution will then be adjusted within the discharge limits. The waste solution will be drained at a controlled rate into the cooling water; the mixture will be within accept-able discharge limits. The waste from the demineralizer units will contain no radioactive material. A summary description of the cycle-makeup demineralizer waste flow is presented in Table 3.6-1. The effect of the cycle-makeup demineralizer-regeneration waste on the plant effluent is summarized in Table 3.6-2, which also shows the lake-water composition and State require-ments, where applicable. 3.6.1.2 Chemical Cleaning Wastes (Preoperational Cleaning) (G~} A very high degree of internal surface cleanliness must be maintained in the reactor vessel and all piping and equipment that convey water or steam to or f rom the reactor. These systems will be flushed with approximately 500,000 gallons of demineralized water. The initial flush will be discharged to liquid-waste basins, where metal chips, turnings, or similar foreign materials will be settled. Clear wastewater will be discharged to the condenser circulating water. Water quality is not expected to change significantly (see Table 3.6-3). The system vill then be cleaned with the following approximate amounts of alkaline chemicals:
a. trisodium phosphate, anhydrous (2000 pounds)

b. disodium phosphate, anhydrous (100 pounds)

c. blodegradable detergent (60 gallons) k_)s l i l 3.6-2 l
These chemicals will be mixed with 120,000 gallons of demineral-ized water, circulated, and heated to about 180 P. The heated solution will be discharged to the chemical cleaning lagoon when cleaning is complete. Subsequent rinses will amount to about 1 million gallons of demineralized water, containing trace quantities of the cleaning chemicals. The rinse waters will also be discharged to the waste basins after treatment and discharge of the cleaning solution. It is estimated that the following approximate quantities of chemicals will be used to treat the waste solutions:
a. 3500 pounds of lime

b. 500 gallons of 66 Be sulfuric acid The chemical treatment will precipitate virtually all of the phosphate in the waste solutions. The remaining clear solution, containing mostly sodium sulfate, will be blended with cooling
~'
water and discharged at a controlled rate (approximately 500 gallons per minute for about 17 hours) . The calcium phosphate sludge will be hau.'.ed away by a contractor licensed to accept these wastes. The wastes will be proauced once for Unit 1 and once for Unit 2. Table 3.6-3 shows the composition of the chemical cleaning waste solutions, their eff ect on plant-ef fluent and lake-water quality, and the applicable State requirements. 3.6.2 BIOCIDE WASTE SYSTEM , Approximately 69,400 gallons per minute of water from Lake Erie will be required during normal operation for cooling-tower circulating water make-up and for once-through service water for cooling auxiliary plant equipment. In addition, the emergency service-water system may require approximately O 3.6-3 I (
1000 to 44,000 gallons per minute of Lake Erie water during hot standby, post accident, or scheduled pump test conditions. Sodium hypochlorite (0.8 percent) will be injected into the cooling-tower circulating water, the service water, and the emergency service water to control algae and plant growth. The chlorination system will be set up to dose the cooling-tower circulating water, the service water, and the emergency service water separately and on a programmed timed-dosage basis. Sodium sulfite will be injected into the cooling-tower blowdown and service-water discharge line to remove any residual chlorine. The dechlorination system will be set up on an individual programmed timed-dosage basis coordinated with the cooling-tower circulating-water hypochlorite injection and with the service-water hypochlorite injection controls. Similarly, each of the two emergency service-water system discharge lines "T has an individual sodium sulfite injection system with a program-med timad-dosage system coordinated with hypochlorite injection. The emergency service-water system will be chlorinated only intermittently, when the emergency service-water pumps are running. This would normally be during regularly scheduled tests of the emergency service-water pumps. During chlorination and dechlorination, the mixed plant dis-charge water will be continuously sampled at the entrance to the plant discharge tunnel and monitored and recorded for chlorine residual. Conductivity and pH will also be monitored. It is estimated that a daily dosage of approximately 96,000 pounds of 0.8 percent sodium hypochlorite solution will be required for each of the two cooling-tower circulating-water systtms. Each circulating-water system will be sampled, moni-tored, and recorded for chlorine residual. The service-water system will require a daily dosage of approximately 3870 pounds v
-)
i 3.6-4 i L_
of 0.8 percent sodium hypochlorite solution. The emergency service-water system will be dosed on an intermittent basis. 0- Each dose will be approximately 1200 pounds of 0.8 percent sodium hypochlorite solution. Sulfuric acid will be added to the cooling-tower circulating-water system to prevent scale formation. A total daily dosage of approximately 18,200 pounds of 93 percent sulfuric acid will be required for the two cooling-tower circulating-water systems. The sulfuric acid will be added on an automatic pH-control basis to maintain circulating water pH within desired limits. The circulating water will be sampled, monitored, and recorded for pH and conductivity. The cooling-tower blow-down will be discharged to the plant discharge tunnel, where the mixed plant effluent will be sampled, monitored, and recorded for pH and conductivity. A summary description of the chemical addition to the cooling-tower circulating-water, service-water, and emergency service-Os water flows is presented in Table 3.6-4; a summary of the eff ect of sodium hypochlorite addition and sulfuric acid addition on the plant effluent is given in Table 3.6-5, which also shows the lake-water composition and State requirements, where applicable. Figure 3.6-1 shows the overall nonradioactive chemical waste discharge systems. A closed-loop system is provided for makeup-water coagulators and filter backwashes so that no effluent f rom this system is released to the environment. In addition, ! turbine lubricating-oil areas, diesel-generator areas, and auxiliary boiler blowdown are routed to this closed-loop system. The outdoor basin drains of the main transformer, auxiliary transformer, interbus transformer, and startup transformer are all routed through oil interceptor tanks capable of con-f- taining the full volume of oil of any transformer in the event ( 3.6-5
of a transformer leak. Normal precipitation runoff from these transformer basins flows first through the oil interceptor tanks before discharge through the yard drainage system. O O 3.6-6
~~.~. . _ _ - . _ - _ , _ _ , . . _ _ . . _ _ . - _ , _ . _ ._ __~~
TABLE 3.6-1 () EXPECTED CHEMICAL USE AND WASTE FLOW IN CYCLE-MAKEUP DEMINERALIZER Sulfuric acid (100% H 2SO 4), lb Cation unit, per regeneration 244 Mixed-bed unit, per regeneration 142 Daily use 989 Annual average 357,000 Maximum use 714,000 Caustic soda (100% NaOH), lb Anion unit, per regeneration 723 Mixed-bed unit, per regeneration 111 Daily use 1,062 Annual average 383,000 Maximum use 766,000 Waste flow per regeneration, gal Cation unit 2,175 Anion unit 1,983 Mixed-bed unit 6,735 Rate of regeneration-waste production, gpd Maximum (a) 34,364 f~') Average (b) 17,182 v Regeneration-waste discharge schedule Average 85 gpm for 4 hr Maximum 85 gpm for 8 hr (a) Based on 300-gpm flow, eight regenerations per day on cation and anion beds, one regeneration every 5.4 days on mixed bed. (b) Based on 150-gpm flow, four regenerations per day on cation and anion beds, one regeneration every 10.8 days on mixed bed. 4 V 4 3.6-7
v - TABLE 3.6-2 WATER-QUALITY EFFECT OF CYCLE-MAKEUP REGENERATION WASTE Regeneration Cooling-Water (a) Lake-Water Discharge Waste Nominal Lake- Containing Composition LimitID) Constituent Composition Water Composition Regeneration Waste Range Requirements pH 5-9 7.9 6-9 7.7-8,5 6-9 Na, ppm 5,250 16 45.9 13-26 none Ca, ppm 1,330 40 69.2 33-45 none Mg, ppm 340 8 14.6 7-8.9 none HCO 3 , ppm 106 62.6 80-124 none C1, ppm 800 38 63.9 30-57 none SO 4 , ppm 7,150 24 144.8 14-60 none Suspended solids, ppm 5 12 19.2 1-200 30 (30 day avg.) g 100 (1 day max.)
+ Dissolved solids, i ppm 14,870 244 401 130-325 none 08 Oil or grease, ppa 0 0 0 0 15 (30 day avg.)
20 (1 day max.) (a) Cooling water is ccanposite cooling water discharge to Lake Erie with cooling towers operating at 2.5 concentrations and maximum monthly average cooling tower evaporation. Emergency service water flow is assumed to be zero. (b) 40 CFR Part 423.
~~.- .__. __ . _ _ _- _ .= . --~~
o o o TABLE 3.6-3 WATER-QUALITY EFFECT OF CHEMICAL CLEANING WASTE Chemical-Cleaning Nominal Cooling-Water (a) Lake-Water Discharge Waste Solutions Lake-Water Containing Chemical- Composition Limiti) Constituent Range Composition Cleaning Solution Range Requirements pH 6-9 7.9 6-9 7.7-8.5 6-9 Phosphate as P, ppm 0.5-2.0 0.14 0.22 0.005-0.15 none Iron as Fe, ppm 0.5-5.0 0.25 0.40 0.07-0.48 1.0 Copper as Cu, ppm 0 0,3 0 0.0-0.6 1.0 Dissolved solids, ppm 4000 max. 244 401.6 130-325 500 w
~~. Suspended solids, ppm 50-100 12 21.5 1-200 30 (30-day avg.)~~
~~i 100 (1-day max.) ,~~
~~Oil or grease, ppm 0 0 0 0 15 (30-day avg.)~~
20 (1-day max.) (a) Cooling water is composite cooling-water discharge to Lake Erie with cooling towers operating at 2.5 concentrations and maximum monthly average cooling-tower evaporation. Emergency service-water flow is assumed to be zero. (b)40 CFR Part 423 4 4
O O i, TABLE 3.6-4 ESTIMATED BIOCIDE AND CHEMICAL USE IN COOLING %ATER AND COOLING-WATER DISCHARGE Daily Use (lb) Emergency Biocide or Cooling-Tower Service Service Total Annual Use (lb) Chemical Circ. Water Water Water per Day Average Maximum Sulfuric acid, 100% H 2SO4 18,200 -- -- 18,200 6,560,000 8,220,000 Sodium hypochlorite, 4 100% NaOCl 788 31 9.6 818.6 221,000 295,000 Sodium sulfite, , 100% Na2SO3 y (cooling-water ] discharge) 3.5 17.3 4.5 25.3 6,840 9,120 H O 1 l 4 1 i 1 Y
TABLE 3.6-5 WATER-QUALITY EFFECT OF BIOCIDE AND CHEMICAL USE IN COOLING-WATERS AND COOLING-WATER DISCHARGE Discharge Nominal Lake-Water Cooling-Water (a) Lake-Water Limit (b) Cons tituent Composition Discharge to Lake Composition Range Requirements pH 7.9 6-9 7.7-8.5 6-9 Na, ppm 16 25.6 13-26 none Ca, ppm 40 69.2 33-45 none t' Mg, ppm 8 14.6 7-8.9 none HCO3 , Ppm 106 62.6 8-124 none ta ag C1, ppm 38 63.8 30-37 none i I$ SO4, ppm 24 106.4 14-60 none C1 (as chlorine 0.2 (30 day avg.) 4 residual) , ppm 0 <0.2 0 0.5 (1 day max.) 4 Suspended solids, ppm 12 19.2 1-200 none Dissolved solids, ppm 244 341.8 130-325 none i j (a) Cooling water is composite cooling water discharge to Lake Erie with cooling towers operating at , 2.5 concentrations and maximum cooling tower evaporation. Emergency service water flow is assumed 3 to be zero. (b)40 CFR Part 423
~~;. i~~
J
~~,f ~~~
f 5J TUP 94NELusE OIL. YARD T R AN5 FORME R DaESEL GENE RATOR DR AINS B ASIN OR AIN5 AND AUM. BOILER ACID & I AREA FLOOR DRAIN 5 ACID C AUSTIC C AUSTIC OIL INT ERCE PTOR T A NK 5 (4)
~~ 'I 1' ACID LikE D E MIN. ADDITION ADD 4 TION INTERCEPTOR * * * " "'
FILT E R E D r TANK 4 1 o MATER TEMPORARY CLE ANING
]
MATER 3 3 m PUMP ,r l' w ASTE5 SE R VICE j$ g6 of 1r T T a 5 v m g e 2 y c" < ='c ^' c'e ^"'"o
~~.AgyEtAGOON FILT E RS (3) ACID CAUSTIC~~
~~_+ MAKEUP WATER d4 26 COAGULATORS FROM~~
/ r . , BACK CLEARwELL 7 9 U U w ASH - gig SLUDGE ,
R E G ENE R A TION LAGOON ' NEUTRALIZ ATION B ASIN LJ DECANT SUL FIT c 1r
~~INJ E C TION C 0)~~
I : H h N ir 5LUDGE L AGOONS %
)
~~
~~ ~~
~~TO COAGULATORS C00 LING T0w e (2)~~
~~->+~~
ir 26 J , PLANT 7 'T l - I-- SODIUM HYPOCHLORIT E Ds 5CH ARGE SODIUM HYPOCHLORITE TUNNEL i SUL FURIC - EMERGENCY
~~+ SE RVICE ACID 'f~~
~~SERVICE C WATER CONDE N5E R WATER~~
" (2) 4 - s i H Y POCHLORIT E
~~' ^~~
~ h _- %w ir i PLANT WATER PL ANT WATER LAKE ERlE NONRADIOACTIVE CHEMICAL WASTE DISCHARGE SYSTEMS PERRY NUCLEAR POWER PLANT 1 & 2 THE CLEVELAND ELECTRfC FIGURE 3.6-1 ILLUMIN ATING COMP ANY
(~) v 3.7 SANITARY AND OTHER, WASTE SYSTEMS This section is essentially unchanged from the corresponding section in the ER/CP. 3.7.1 SANITARY WASTE SYSTEM Sanitary wastes are conveyed to one of two sewage-treatment units each with a capacity of 15,000 gallons per day and all equipment necessary for efficient operation. The units use the extended-aeration process, which reduces suspended solids by 90 percent and the 5-day biochemical oxygen demand by 90 percent. Three half-capacity blowers are provided. The secon-dary treated sewage discharge is treated with tertiary rapid sand filtration. The sewage-treatment plant effluent is chlori-nated before discharge using a Sanilec tablet chlorination system. O Because the sanitary-waste-treatment system was designed to service 3000 construction workers at 10 gallons per day per person (total 30,000 gallons per day), it will be able to service approximately 130 operating personnel at 60 gallons per day per person (total 7800 gallons per day). Effluent from the sewage treatment plant will be discharged to Lake Erie. The estimated concentrations in the effluent are listed in Table 3.7-1. Waste sludge accumulated and thick-ened in the sludge-holding tank will be pumped out and hauled
~~.off the site for disposal in an approved manner.~~
~~i N~~
]
l 3.7-1
3.7.2 OTHER WASTE SYSTEMS 3.7.2.1 Diesel-Generator Exhaust Diesel generators will be provided for emergency use in the event of loss of offsite power, and a separate diesel generator will provide power for the high-pressure core spray system (HPCS). In addition, a diesel-driven fire pump will be used in the standby service-water pumphouse. These diesel generators will be operated only periodically for testing purposes for approximately 1 hour. The gaseous effluent production rate will be approximately as follows: Equipment Effluent Production Rate (lb/hr) Standby diesel generators 118,300 each (two per unit) HPCS diesel generators 30,000 per unit i
./
Diesel driven fire pump 3600 both units The above effluents will result in the following approximate annual emissions of specific combustion products: Combustion Product Emission Rate (lb/yr) Sulfur dioxide 2,690 Nitrogen oxides 25,364 Carbon monoxide 5,066 Hydrocarbons 583 Particulates 254 The duty cycles assumed for the diesels are 1 hour every other week for the standby diesel generators and the HPCS diesel O l 1 3.7-2
generator and 30 minutes every week for the diesel-driven fire pump. Except for sound attenuation, the exhaust gases will not be treated. 3.7.2.2 Auxiliary Boiler Flue Gases Two auxiliary boilers are provided for use during plant startup and shutdown operations whenever steam from the nuclear steam supply system is not available and for operating the radwaste evaporators. It is estimated that both boilers will be operated for two 1-week periods per year for plant startup and shutdown. In addition, one boiler will be required for operating the radwaste evaporators for 11 hours every 6 days. The total boiler opera-tion is estimated to be 1158 hours per year. 1 The boilers will be fired with oil and produce a maximum of 112,000 pounds of flue gases per hour. The flue gases will not be treated. This effluent will result in the following approximate annual emission of combustion products: , Combustion Product Emission Rate (lb/yr) Sulfur dioxide 150,000 Nitrogen oxides 1,700 Particulates 3,300 3.7.2.3 Miscellaneous Waste paper, packing cartons, boxes, etc., accumulated during daily plant operation and maintenance will be disposed of by removal to a licensed offsite landfill. () 3.7-3 .
o o o TABLE 3.7-1 ESTIMATED CONCENTRATION OF RAW AND TREATED SANITARY WASTE Parameter Condition (a) Influent Effluent pH 1 8.3 8.3 , 2 8.3 8.3 Alkalinity as CACO3 , Ppm 1 100 30 2 100 30 Suspended solids, lb/ person-day 1 0.05 0.005 2 0.15 0.015 Dissolved solids, ppm 1 300 300 2 300 300 ta
-a Five-day biochemical oxygen demand 1 0.040 0.0040 1 (200 C), Ib/ person-day 2 0.085 0.0085 Ammonia nitrogen, ppm 1 20 7 2 20 7 Nitrate nitrogen, ppm 1 0 10 2 0 10 Phosphate (as P) 1 20 15 (total soluble), ppm 2 20 15 Chlorine residual, ppm , 1 0 0.5 2 0 0.5 (a) Condition 1 = construction personnel (no showers); condition 2 = operating personnel 4
(showers and laundry). i 5 e
() 3.8 REPORTING OF RADIOACTIVE MATERIAL MOVEMENT The transportation of cold fuel to the reactor, of irradiated fuel from the reactor and of solid radioactive wastes from the reactor is within the scope of 10 CFR Part 51.20 as follows: (i) The reactor is a light-water-cooled nuclear power reactor with a core thermal power level not exceeding 3800 megawatts; (ii) The reactor fuel is in the form of sintered uranium dioxide pellets encapsulated in zircaloy rods with a uranium-235 enrichment not exceeding 4% by weight; (iii) The average level of irradiation of the irradiated fuel from the reactor does not exceed 33,000 megawatt days per metric ton and no irradiated fuel assembly is shipped until at least 90 days have elapsed after the fuel assembly was discharged from the reactor; (iv) Waste (other than irradiated fuel) shipped from the reactor is in the form of packaged solid wastes; and ' f' (v) Unirradiated fuel is shipped to the reactor N- by truck; irradiated fuel is shipped from the reactor by truck, rail, or barge; and waste other than irradiated fuel is shipped from the reactor by truck or rail. See Section 7.2 for the impacts of transportation as set forth in Table S-4 of 10 CFR 51. l
~_
i 3.8-1
O 39 ma^"s" ss on '1"8 e^c t1r 88 This section differs from that in the ER/CP with regard to a portion of the transmission-line routing. The routing change is in accordance with the requirements of the Ohio Power Siting Commission as described below. Two high-voltage transmission lines originate at the PNPP. One, the Perry-Macedonia-Inland line (project 1), is a 345-kilovolt double-circuit line from the PNPP through Lake, Geauga, cuyahoga, and Summit Counties to a tie-in point near Macer *onia to the Inland substation. The second transmission line, Perry-Hanna (project 2), is a 345-kilovolt line initially strung for single-circuit operation. This line also originates at the PNPP and extends south through Lake, Geauga, and Portage Counties to the Hanna substation near Ravenna. Figure 3.9-1 shows the approximate locations of these two lines. The Perry-Macedonia-Inland line (project 1) was presented II to the Ohio Power Siting Commission, which granted a Certificate of Environmental Compatibility and Public Need,I I with conditions. One condition is that the route be modified for the crossing of the Grand River in Lake County; the modified part of the route is shown in Figure 3.9-2. The Perry-Hanna line (project
~~2) has also been presented to the Ohio Power Siting Commission.I )~~
The change in the Grand River crossing was required by the Ohio Power Siting Commission to avoid crossing the Grand River in an area where the river is designated a wild river. (2) O 3.9-1
() REFERENCES FOR SECTION 3.9
1. Site Report, Perry-Macedonia-Inland 345 KV Transmission Line, Volumes I and II, the Cleveland Electric Illuminating Company, 1975.

2. Ohio Power Siting Commission, Opinion and Final Order Granting Certificate of Environmental Compatibility and Public Need With Conditions, Case No. 02-00001 - Applica-tion of the Cleveland Electric Illuminating Company for a Certificate of Environmental Compatibility and Public Need authorizing the construction, operation, and mainte-nance of a 345,000 volt transmission line, known as the Perry-Macedonia-Inland transmission line, filed March 29, 1976.

3. Site Report, Perry-Hanna 345 KV Transmission Line, the
~~() Cleveland Electric Illuminating Company and the Ohio Edison Company, 1978. 1 iO 3.9-2~~
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CHAPTER 4 ENVIRONMENTAL EFFECTS OF SITE PREPARATION, PLANT CONSTRUCTION, AND TRANSMISSION FACILITIES CONSTRUCTION This chapter dealing with construction is not applicable for the operating-license stage. Construction effects were discussed in the ER/CP with the exception of the impacts af some radio-activity from Unit 1 on the Unit 2 construction workers, which will be discussed in Section 12.4 of the FSAR.
~~V i l l O 4.1-1~~
~~. _ _ _ , ._, __ _ _ . - . , , _ . .-_._ .._. ._ _ _ _ _ _ . _ . . . . . - _ ~ ~ . - _~~
~~} i (} CHAPTER 5 ENVIRONMENTAL EFFECTS OF STATION OPERATION l This chapter presents a description of the interaction of~~
~~the station and transmission facilities (discussed in Chapter~~
~~-3) and the environment (discussed in Chapter 2). The effect 4~~
i of a single opercting unit would be less than that for two units. 5.1 EFFECTS OF OPERATION OF HEAT-DISSIPATION SYSTEM J i This section has been revised to reflect changes in the PNPP cooling system, which is now based on cooling towers rather than the once-through discharge system described in the ER/CP. l The cooling-tower system, discussed in Section 3.4, consists
~~of two hyperbolic natural draft towers, one for each unit.~~
() The cooling air flow is obtained from the natural draft of air heated and moistened by contact with the condensed cooling I [ water. For the 2410-MWe plant generating capacity, two natural ! draft towers are required to dissipate the total plant heat load of 1.67 x 10 10 Btu per hour; thus, each tower will have to dissipate 8.35 x 10 9 Btu per hour. For the design wet-f' i bulb temperature of 76 F, circulating cold-water temperature of'94.0 F, and cooling range of 30.6 0F, the exit air temperature is 114 F. Each tower is therefore designed to evaporate 14,500 i gallons of water per minute at design conditions, with 55 gallons per minute of liquid water droplets (drif t) entrained i in the exit air flow. l
~ Reference design parameters for the PNPP natural dratt cooling towers are presented in Table 5.1-1. The expected exit air flow rate and effluent air temperature are plotted as functions of ambient wet-bulb temperature and relative humidity in Figures )
5.1-1
5.1-1 and 5.1-2, respectively. Figure 5.1-3 shows the location of the natural draft cooling towers at the PNPP site. (~/} u. 5.1.1 EFFLUENT LIMITATIONS AND WATER QUALITY STANDARDS All surface waters of the State of Ohio are covered by water quality standards promulgated in December 1973 (amended December 30, 1977) by the Ohio Environmental Protection Agency (OEPA) . The standards are designed to protect the quality of water for various uses, including agricultural, industrial, and public water supplies; recreational uses; navigation; and the propagation of fish, other aquatic life, and wildlife. Where multiple uses are designated for a particular portion of a given water body, the most restrictive water-quality standards for the designated uses apply. The following are standards extracted from the Ohio Water Quality Standards as amended in 1977 and are generally applicable to the receiving waters of Lake Erie. O]
~~\- 5.1.1.1 Water Quality Limits Table 5.1-2 gives the water quality limits for Lake Erie. l 1~~
1 5.1.1.2 Temperature Limits There shall be no water temperature changes resulting from human activity that cause mortality, long-term avoidance, exclusion from habitat, or adversely affect the reproductive success of representative aquatic species, unless caused by natural conditions. At no time shall water temperature outside the thermal mixing zone exceed a monthly or biweekly average, or at any time - exceed the daily temperature due to plant activity. Table 5.1-3 gives temperature requirements for Lake Erie. l l (~)'
~~
5.1-2
5.1.1.3. Discharge Limits IO
~~\~# Discharge limits are shown in Tables 3.6-2, 3.6-3, and 3.6-5.~~
Discharge limits are adopted from 40 CFR Part 423 Stram Electric Power Generating Point Source Category. 5.1.1.4 Radioactive Materials The control and regulation of radioactive substances discharged to any waters shall be in accordance with and subject to the criteria, standards, or requirements described by the United States Nuclear Regulatory Commission as set forth in 10 CFR Part 20 and the guidance set forth in Regulatory Guide 1.109. 5.1.2 PHYSICAL EFFECTS For the natural draft cooling towers at the PNPP, the major consumptive water loss will be through evaporation. The entrain-ment of droplets as drift in the effluent plume will cause (}
\' additional water losses. Table 5.1-4 summarizes the calculated average consumptive water losses by month. The values in this table are based on a 100 percent load factor and were calculated from monthly averages of hourly meteorological data collected at the site during 3 years: May 1, 1972, through April 30, 1973; May 1, 1973, through April 30, 1974; and September 1, 1977, through August 31, 1978.
5.1.2.1 Sources and Volume of Heat Influx The seasonal average operational characteristics of the PNPP thermal discharge are shown in Table 5.1-5. These values were determined using information from Table 3.4-1. As shown, the average annual heat influx to the lake from the cooling-tower blowdown and service water discharge will be 6.85 x 10 6 Btu per minute, which is less than 2.5 percent of the (r , (_) l i 4 5.1-3 I _ _
i j heat influx projected for.the originally designed once-through
~~' cooling system described in the ER/CP.~~
5.1.2.2 Thermal Plume Analysis 5 .1. 2. 2.1. Plume'Modeling i. The plume analysis was conducted using the computer code HOTSUB2, , which is a revision of the HOTSUB program described in the ! ER/CP. HOTSUB2 incorporates new computation methods to account for bounding effects imposed by the lake bottom and surface,
+
and as such represents a state-of-the-art improvement over the original code. 1 A complete description of the HOTSUB2 code appears in Appendix A5.1. Briefly, the program simulates two types of transport and diffusion processes: subsurface jet diffusion and passive drift diffusion. Subsurface jet diffusion occurs due to the entrainment of lake water in the high-velocity discharge flow. O This process is simulated in HOTSUB2 using the numet. cal solu- ) tion method of Koh and Fan,II) which tracks the plume in differ-ential slices from the point of discharge up to the lake surface. Passive drift diffusion is assumed to be the dominant mechanism l of surface transport. Passive drift diffusion occurs due to the movement and mixing of the effluent stream when it is driven by lake currents. This process is simulated using the Fickian diffusion equations developed for the Great Lakes in NRC Regulatory' Guide 1.113. Surface heat transfer effects have not been included in the j HOTSUB2 code because the effects of surface transfer are insig-nificant in comparison to the effects of dilution and entrain- , j ment processes in the region being modeled. With this exclusion of surface heat losses, the dilution of heat as calculated l by the model is. equivalent to the dilution of radionuclides and trace chemicals, assuming equal diffusion coefficients. 5.1-4 p .- . -, . . , , . - . , . - - . - , ,-. ,.,..-,,,.,,,nnn . - . . , . . . . . . . , - . - . . ..an, , - - , , . , , ,, , , -,.- - , , s
5.1.2.2.2 Model Input O# The HOTSUB2 model requires the following information: discharge diameter, discharge flow rate, discharge centerline depth, ambient temperature, ambient depth, ambient surface current, and horizontal vertical turbulent diffusion coefficients. The diameter of the discharge port is 3 feet. Seasonal flow rates and temperatures are shown in Table 5.1-5. Discharge centerline depth was taken to be 16.2 feet, based on a 1.3-foot clearance between the bottom of the discharge port and the lake bed. Lake depth at the point of discharge is 19 feet. Seasonal lake temperatures, which were treated as depth-independent, are shown in Table 5.1-5. The average surface current in Lake Erie is reported to be 0.33 foot per second. (2) Horizontal and vertical turbulent diffusion coef-ficients were taken to be 0.5 and 0.001 square foot per second, respectively, which are the most conservative values discussed in NRC Regulatory Guide 1.113. 5.1.2.3 Thermal Plume Characteristics The thermal plume temperature and velocity characteristics are shown in Figures 5.1-3 through 5.1-14. It should be noted that the plume is essentially symmetrical about the centerline. Although the symmetry is complicated by the necessary truncation of the horizontal scale and by the curvature of the centerline itself, the depiction in the figures is distorted by the different distance scales. 5.1.2.4 Far-Field Transport The HOTSUB2 algorithm was used to project dilution values to trace chemicals and radionuclides for drinking-water intakes within 50 miles of the PNPP. Most of the dilution was projected to occur during the passive transport process, simulated using i 5.1-5 l l
Equation 13 from NRC Regulatory Guide 1.113. All inputs to the model were the same as those discussed in Section 5.1.2.2.2,
~~-)' with the exception of ambient depth. Ambient depth was taken to be 16 feet, which was the most shallow depth indicated for any drinking-water intake within 20 miles of the PNPP.~~
The computation was carried out in the following manner: all intakes on the southwest shoreline were assumed to intercept the PNPP discharge whenever the current was moving in the west-southwest, southwest, south-southwest, or south directions. All intakes on the northeasterly shore were assumed to intercept the PNPP discharge whenever the current was moving in the east-northeast, east, east-southeast, and southeast directions, and also one-half the time that it moved in the northeast direction. The transport resulting from currents in the south-southeast direction was assumed to divide evenly between the southwesterly and northeasterly intakes. The resulting frequency factors were 0.3 and 0.4 for the southwesterly and northeasterly /T intakes, respectively. U Dilution factors for the drinking-water intakes within 50 miles of the PNPP are presented in Tables 5.1-6 through 5.1-10. Dilution factors are also presented for points 0.5, 1.0, 5.0, and 10.0 miles from the plant in either shoreline direction. In each table, two sets of dilution factors are shown: (1) the unadjusted dilution factors determined with the HOTSUB2 model, and (2) the annually or seasonally adjusted dilution calculated as the product of the unadjusted dilution multiplied by the current frequency factor for a given location. The unadjusted dilution factors are considered to be conserva-tive and reasonable for the case where the lake surface drift carries the effluent directly from the discharge point to a given intake. The annually and seasonally adjusted dilution factors, however, must be regarded as conservative since the
~~) !~~
5.1-6
frequency factors are a conservative rather than a realistic estimate of how often such point-to-point transport occurs. O 5.1.3 BIOLOGICAL EFFECTS Operation of the PNPP is expected to have a negligible impact on the aquatic ecology of the site and the Central Basin of Lake Erie. During plant operation, aquatic organisms will be exposed to thermal, mechanical, and chemical damage as a result of being entrained in the cooling system. It is assumed that 100 percent mortality will occur in the organisms that are entrained. Since the plant cooling system has been redesigned to use cooling towers, the volume of water being drawn from the lake is small compared to the once-through system addressed in the ER/CP. Hence, the number of organisms lost during plant operation would be correspondingly less. The principal potential impacts are completely discussed in the ER/CP and are as follows: x 1. Impingement of adult fish
2. Entrainment of fish eggs and larvae

3. Thermal shock of fishes in the discharge region due to plant shutdown The flow of cooling water through the plant cooling system represents a negligible impact from the entrainment of phytoplankton, zooplankton, and benthos. The standing crop of these organisms will be reduced slightly in the immediate vicinity of the intake but this reduction should have no discernible effect on the site or the Central Basin of Lake Erie.
5.1.3.1 Impact of Intake on Fish and Ichthyoplankton The low velocity of water at the intake will substantially reduce the potential of loss of fish due to impingement. (-) V Table 5.1-11 presents swim speeds for some fish species found 5.1-7
at the plant that can be compared with the expected velocity range at the intake structure presented in Section 5.1.2. In consideration of the small volume of intake water and the relatively low intake velocity, it is unlikely that the small number of fish lost from impingement will be discernible enough to relate to the fish population of the Central Basin. It is expected that there will be no adverse environmental effects due to impingement of adult fish. During plant operation, fish eggs and larvae will be passively drawn into the cooling system along with the water. The numbers entrained are directly proportional to the volume of cooling water taken in. It is unlikely that entrainment will have a detectable effect on the adult fish population of the Central Basin, since the number of eggs and larvae in the area are low and the volume of water entrained is small. As discussed in the ER/CP, the site was not considereJ an important spawning area of the lake because the number of eggs and larvae at (- the site is small. In addition, spawning by most fish species
\~ occurs in predominantly shallow water outside the influence of the intake structure. Furthermore, the eggs of the important fish species existing at the PNPP site (e.g., walleye, yellow perch) are demersal; they tend to settle to the bottom and remain there until hatched.
5.1.3.2 Impact of Discharge on Fish and Ichthyoplankton The impact of the discharge on fish and ichthyoplankton in the immediate vicinity of the dischargi or the Central Basin of_ Lake Erie will be negligible. The amount of heat discharged into the lake and the dimensions of the thermal plume are very small. As discussed in the ER/CP, fish will tend to avoid the limited warmer areas of the plume because of the l induced turbulence created by the discharge currents. However, during the colder months, some fish will be attracted to the warmer water of the plume. As shown in Section 5.1.2, the 5.1-8
induced current from the discharge exceeds the swim speeds of fish found at the PNPP site, thus making it highly unlikely (* that fish will be able to reside in the warmer areas of the plume. In addition, the discharge velocity does not allow sufficient time for fishes to become acclimatized to tempera-tures that would be high enough to cause thermal shock in the event of a winter shutdown. Fish eggs and larvae that drift past the discharge structure may be entrained by the thermal plume. Some potential damage associated with higher temperatures and currents may occur. These impacts are anticipated to be of a minor consequence to the fish population within the vicinity of the plant and in the lake as a whole. 5.1.4 EFFECTS OF HEAT-DISSIPATION FACILITIES The potential environmental impacts resulting from the operation i r- of the cooling towers include the formation of ground-level fog, horizontal and vertical icing, elevated visible plumes, ground deposition and airborne concentrations of dissolved solids contained in drift droplets released from the towers, noise, and aesthetic effects. The FOG computer program (3) was used to analyze the potential environmental impacts of cooling-tower operation. Inputs for the FOG program are design and performance data describing the type of cooling system, overall dimensions and orientation of the cooling system, cooling-water flow rate, cooling range, drift loss, and the concentration of dissolved solids in the cooling water (see Table 5.1-1 and Figures 5.1-1 and 5.1-2). In order to provide a detailed analysis of the cooling-tower vapor plumes, the rise and growth of the plumes were calculated by the Lagrangian Vapor Plume Model (LVPM) computer program.(4) The LVPM program is a one-dimensional numerical model capable ( 5.1-9
of predicting the detailed behavior of either wet or dry plumes
~~'N for a given meteorological condition.~~
(d The computer analyses using the FOG model were based on hourly onsite meteorological data collected at the site in 3 years: May 1, 1972, through April 30, 1973; May 1, 1973, through April 30, 1974; and September 1, 1977, through August 31, 1978. Section 2.3 describes the meteorological data base. 5.1.4.1 Fogging and Icing The effect of an evaporative heat-dissipation system on the formation of fogging and icing conditions is determined by the quantity and location of added moisture and on the existing ambient air conditions. The calculations of fogging effects were based on the assumption that a liquid-water content of 1.2 x 10 -5 pound of liquid (T per pound of dry air (0.015 gram of water per cubic meter of dry air) would result in a visibility of 1000 meters (3280 feet, or 5/8 mile) or less.(5) The calculations showed that this condition would not occur at the PNPP; that is, any fogging induced by the natural draft cooling towers would not reduce visibility to 1000 meters (3280 feet) or less. The calculations also showed that the operation of the natural draft cooling towers would not produce any significant horizon-tal icing (more than 1 millimeter thick). The maximum predicted ice buildup on vertical surfaces (using a typical height of 60 feet) is 7 millimeters; it is expected to occur at a frequency of 26 hours during the average winter season and at a distance of approximately 3 miles east-northeast from the cooling towers. (a~) 5.1-10 i l
5.1.4.1.1 Effects on Ground Transportation -- Generally, driving conditions can be affected by visibility reductions caused by fogging over roads and by icing; both of these conditions can be potentially induced by the emssion of moisture from the heat-dissipation system of a nuclear power plant. The roads in the vicinity of the PNPP are U.S. Route 20, Ohio Route 84, Interstate 90, and Ohio Route 528; their locations and orientations in relation to the site are listed in Table 5.1-12. None of these roads is expected to have impaired driving conditions as a result of the operation of the PNPP natural draft cooling towers--that is, no reductions in visi-bility to 1000 meters (5/8 mile) or less and no horizontal icing. 5.1.4.1.2 Effects on Air Transportation O l m- There are four airports in the vicinity of the PNPP: Concord, Casement, Eckerd, and Woodworth. Their loctions and orienta-tions in relation to the PNPP site are listed in Table 5.1-13. None of these airports is expected to be adversely affected by the operation of the PNPP natural draft cooling towers: the calculations show that there will be no reductions in visibility to 1000 meters (5/8 mile) or less and no significant horizontal icing. 5.1.4.1.3 Effects on Water Transportation Commercial shipping ports, rivers, and lakes in the vicinity of the PNPP site include Fairport, Ashtabula, Grand River, and Lake Erie. Their locations and orientations in relation to the PNPP site are presented in Table 5.1-12. None of these ports or waterways is expected to be adversely affected by the operation of the PNPP natural draft cooling towers: the 5.1-11
calculations show that there will be no reductions in visibility to 1000 meters (5/8 mile) or less and no significant horizontal icing. 5.1.4.2 Elevated Visible Plumes This section discusses the predicted maximum annual and monthly frequencies of elevated visible plumes produced by the PNPP natural draft cooling towers. It also describes their impact on surrounding airports and population centers. 5.1.4.2.1 Maximum Frequency of Elevated Visible Plumes Isopleths of the predicted annual frequency of elevated visible plumes are presented in Figure 5.1-15. The maximum predicted frequency of elevated visible plumes is approximately 220 hours per year and is expected to occur in the immediate vicinity of the cooling towers, to the east-northeast. O 5.1.4.2.2 Occurrence of Elevated Visible Plumes at Airports The predicted mean annual frequencies of elevated visible plumes at these airports are as follows: Mean Annual ! Frequency of Visible Plumes Airport (hr/yr) l Concord 4 l Casement 14 Eckerd 5 Woodworth 24 5.1.4.2.3 Occurrence of Elevated Visible Plumes at Surrounding Population Centers The population centers within 6 miles of the PNPP site are j Painesville-on-the-Lake, Lane, Perry, North Perry, Madison,
~~Genung Corners, North Madison, Redbird, and Madison-on-the-l l~~
5.1-12
Lake. Their locations in relation to the PNPP site are shown ( in Figure 2.1-6 and listed in Table 5.1-13. The predicted k mean annual visibility of elevated plumes at these communities is as follows: Mean Annual Frequency of Visible Plumes Town (hr/yr) Genung Corners 18 Lane 12 Madison 17 Madison-on-the-Lake 24 North Madison 26 North Parry 42 Painesville-on-the-Lake 23 Perry 21 Redbird 41 5.1.4.2.4 Occurrence of Elevated Visible Plumes by Month Table 5.1-14 presents the maximum frequencies of elevated visible plumes longer than 0.25 mile for each month of the ("'} \- The results show year and for each of 16 compass directions. a maximum frequency of approximately 78 hours per month during January in an east-northeast direction from the PNPP natural draft cooling towers. Generally, the calculations showed that the visible plumes would be longer during the winter months than during the summer months. The ma::imum visible plume was predicted to be more than 10 miles long, occurring during December at a frequency of 4.4 hours per month. 5.1.4.3 Solids Discharged from the Cooling System The FOG computer program was used to calculate the ground-deposition rate for dissolved solids contained in the entrained drift droplets released from the coolir.g towers. The calcula-tions of ground-deposition rates for dissolved solids and (~} m 5.1-13
I airborne concentrations of dry drift particles were based on a drift rate of 0.01 percent of the circulating-water flow rate and a total-dissolved-solids concentration of 535 parts per million. 5.1.4.3.1 Dissolved-Solids Deposition Isopleths of the total-dissolved solids deposition from the natural draf t cooling towers are presented in Figure 5.1-16. The maximum calculated value is 0.08 pound per acre-year at a distance of 2.25 miles to the east-northeast of the cooling towers. Total-dissolved-solids deposition is defined as the net ground deposition of drift droplets that fall out of the vapor plumes plus the ground deposition of solids as dry drift particles. Dry drift particles form when the water completely evaporates from the entrained drift droplets contained in the plume. 5.1.4.3.2 Airborne Concentration of Dry Drift Particles As discussed in Section 5.1.4.3.1, a portion of the dry drift particles are deposited on the ground, and the remaining dry
~~-drift particles stay airborne. Insignificant levels of airborne concentrations of dry drift particles were predicted from the natural draft towers.~~
5.1.4.4 Increased Ground-Level Temperature The PNPP natural draft cooling towers are predicted to have a negligible effect on ground-level temperatures. The maximum predicted increase in ground-level temperature is less than 0.1 F. O i 5.1-14
5.1.1.5 Increased Ground-Level Relative Humidity O The mean annual increases of ground-level relative humidity beneath the plume from the natural draft cooling towers were calculated by the FOG computer program on a polar grid centered on the cooling system. The calculated values represent the mean of the predicted increases of ground-level relative humidity above ambient values. These predicted increaJes are less than 0.1 percent. 5.1.4.6 Cooling-Tower Plume Behavior In investigating the general behavior of the PNPP cooling-tower plumes (see Section 6.1. 3) , upper air soundings taken at the Greater Buffalo International Airport in Buffalo, New York, were used as input to the NUS LVPM computer program as representative baseline meteorological data. The Greater Buffalo International Airport is the nearest National Weather Soundings () \> Service station where upper air soundings are taken. were averaged by month and hour of observation over the period January 1969 through December 1973. The behavior of the cooling-tower plume predicted by the model represents the mean for a given month. Average January and July soundings were used to represent winter and summer morning conditions. For an average winter morning sounding (0700 EST), the surface temperature, relative humidity, and wind speed were 21.1 F, 78 percent, and 13.4 mph,'respectively. For the average summer morning sounding (0700 EST), the surface temperature, relative humidity, and wind speed were 64.2 F, 82 percent, and 7.8 mph, respectively. The initial momentum and buoyancy of the effluent from the cooling towers are expected to raise the vapor-plume to a height of approximately 670 meters during the average winter {} morning. No major difference in plume rise was predicted u 1 5.1-15
between winter morning and evening conditions. The neutral r~ buoyancy height is about 650 meters. (>$ During the average summer morning, a plume can penetrate through a maximum height of approximately 790 meters. Plume buoyancy becomes neutral at a height of approximately 730 meters. Figures 5.1-17 and 5.1-18 show some of the plume parameters as a function of height for winter and summer mornings, respec-tively. The height of the maximum penetration is determined by taking the height where the vertical velocity of the plume first becomes zero. Neutral buoyancy height (equilibrium level of buoyancy) is defined as the level where the plume and ambient air densities are identical. Cloud water is defined as condensed water droplets that have negligible terminal velocity and are carrried by the updraft of the plume. The visible plume will be observed up to an ('N extent where the cloud water content becomes zero; beyond N--) that point the plume will no longer be visible. The average length of the visible plume is estimated to be 750 meters during the average winter morning and 450 meters during the average winter evening. The average visible plume length is estimated to be 50 and 25 meters during the average summer morning and evening, respectively. Figures 5.1-19 and 5.1-20 show the excess relative humidity profile at the plume centerline at various distances downwind from the cooling towers under average winter and summer morning conditions. The operation of the PNPP cooling-tower system is not expected to induce any significant weather modification. 5.1-16
5.1.4.7 Parametric Study of Plume Rise To examine expected plume rise in the PNPP site area, a para-metric analysis was performed for the average winter morning and summer morning conditions; the analysis was made with the NUS LVPM computer program (see to Section 6.1.3). The two major parameters influencing plume rise are the ambient temperature lapse rate and the ambient wind speed, and the i following analyses were performed:
a. Examination of plume rise as a function of the vertical temperature gradient, assuming the gradient is constant with height (see Figure 5.1-21).

b. Examination of plume rise as a function of ambient wind speed at the top of the cooling tower (see Figure 5.1-22).
~~In the second analysis, the wind profile was assumed to vary ['N~~
~~\l 3~~
with the empirical wind power law: ug = u l0 0 (5.1-1) where ug = wind speed at height Z, in meters per second u = wind speed at 10-meter height, in meters per second l0 P = wind power law exponent, an empirical constant calculated from the Buffalo upper air soundings to be 0.1788 for winter morning and 0.1697 for summer morning conditions. The average January and July morning soundings (0700 EST) were used as representative winter and summer morning reference states. Under the average wind speed, the plume height from the natural draft cooling towers can be expected to exceed _ {~} l l 5.1-17
400 meters for both seasons, as shown in Figure 5.1-21. The 4 lowest plume rise is found under strong ground-based inversions [} on summer mornings. The effect of wind speed on plume rise is pronounced. Very strong wind speeds (on the order of 12 to 15 meters per second) i could limit the plume rise to less than 360 meters above the ground, as shown in Figure 5.1-22. i 5.1.4.8 Noise ? The noise sources associated with the PNPP natural draft cooling towers are described in Section 5.6. An assessment of operational . noise impacts is also presented in Section 5.6, including operations impacts of the cooling towers, circulating pumps, } and service-water pumps. I i j 5.1.4.9 Aesthetics A i V The two hyperbolic natural draft cooling towers are about
! 500 feet high; they have a base diameter for 395 feet and i a stack diameter at discharge height of approximately 257 feet. The large scale of the towers and the lack of natural screening features in the surrounding terrain will affect
! the visual character of the predominantly rural landscape. l Section 5.1.4.2.3 discusses the visibility of cooling-tower plumes at surrounding population centers. The maximum predicted annual mean frequency of elevated visible plumes is approximately 41 hours per year and occurs at Redbird, Ohio. One of the crucial elements in assessing the visual impact of the natural draft cooling towers is to determine the degree to which shadowing will take place as a result of overhead l .i plumes. Shadowing is caused by the direct light of the sun l (]) being blocked over an area underneath of the plume. The degree 5.1-18
to which shadowing occurs varies with atmospheric conditions. On a warm, low-humidity day, a visible plume may not form; [} if one does form, it will dissipate quickly, thereby eliminating any potential for shadowing. On a cold, humid day, the plume will billow out and up like a cloud and, depending on its degree of opacity, may effectively block out the light of the sun. As seen from Figure 5.1-18, the maximum possible frequency of shadowing from the vapor plume is predicted to be no more than approximately 200 hours per year. However, it should be noted that the isopleths in Figure 5.1-18 represent both day and night hours, and both sunny and cloudy hours. I ( l l l O 5.1-19
REFERENCES FOR SECTION 5.1
~~1. R. C. Koh and L. N. Fan, Mathematical Models for the Prediction of Tempertaure Distributions Resulting from the Discharge of Heated Water into Large Bodies of Water.~~
~~Water Pollution Research Series, Program 16130 DWO, Water Quality Office, Environment ) Protection Agency, 1970.~~
2. R. Gedney and W. Lick, " Numerical Calculations of the Wind-Driven Currents in Lake Erie and Comparison with Measurements," Proceedings of the 14th Conference on Great Lakes Research, pp. 454-466, International Association of Great Lakes Research, 1971.
~~1 1~~
~~3. G. E. Fisher, FOG Model Description, NUS-TM-S-185, NUS Corporation, Rockville, Md., July 1974.~~
~~O 4. J. Lee, The Lagrangian Vapor Plume Model - Version 3, 2 NUS-TM-S-184, NUS Corporation, Rockville, Md., July 1974.~~
~~5. S. Petterssen, Weather Analysis and Forecasting, Vol.~~
~~II, McGraw-Hill Book Company, New York, 1956.~~
6. Ohio EPA Regulation EPl, Amended 1977.

7. R. G. Otto, J. O'Hara Rice, and M. Kitchel, " Temperature Effects on Fish," In R. G. Otto (Ed), Evaluation of Thermal Effects in Southwestern Lake Michigan Special Studies 1972-1973, Report to Commonwealth Edison Company, Chicago, Illinois, Prepared by Industrial Bio-Test Laboratories, Inc., pp. 129-206, 1975.
~~O 1 5.1-20~~
8. R. Bainbridge, "The Speed of Swimming Fish as Related to Size and to the Frequency and Amplitude of the Tail Beat," Experimental Biology 35 (1) , pp. 109-133, 1957.

9. D. R. Jones, J. W. Kiceniuk, and O. S. Bamford, " Evaluation of the Swimming Performance of Several Fish Species from the Mackenzie River," Journal Fisheries Research Board Canada 31(10); pp. 1641-1647, 1974.

10. L. R. King, " Swimming Speed of the Channel Catfish, White Crappie and Other Warm Water Fishes from Conowingo Reservoir, Susquehanna River, Pa.," Ichthyological Associates Bulletin, Vol. 4, 1969.
iO 9 l l l O 5.1-21
TABLE 5.1-1 DESIGN PARAMETERS FOR THE PNPP NATURAL () DRAFT COOLING-TOWERS ANALYSES Parameter Value(a) Generating capacity, MWe 1,205 Heat-rejection rate, Btu /hr 8.35 x 109 Circulating-water flow rate, gal / min 545,400 Air flow rate, ft /3 min 1.5175 x 108 Exit air temperature, OF 114 Ambient wet-bulb temperature, OF 76 Relative humidity, percent 50 Approach, OF 18 Hot-water temperature , OF 124.6 Cold-water temperature, OF 94.0 1 Cooling range, OF 30.62 Cycles of concentration of circulating water 2.5 Total dissolved solids, ppm 535 Makeup water rate, gal / min 24,167 Evaporation rate, gal / min 14,500 Blowdown rate, gal / min 9,612 Drift rate, gal / min 55 Maximum drift loss, percent of circulating-water flow rate 0.01 Base diameter of towers, ft 395 Tower discharge height, ft 480.5 Tower exit diameter, ft 256.7 (a) Values given are for one unit (and one tower) only. 5.1-22
~~- - - . - - -m-~~
1 TABLE 5.1-2 WATER QUALITY LIMITS FOR LAKE ERIE (6) ( N Constituent Limit Comment Ammonia -- Varies as a function of temperature and pH ac-cording to Table 2 of the reference document Arsenic 0.050 mg/l Barium 1.0 mg/l Beryllium 1.100 mg/l Cadmium 0.0012 mg/l Chlorine 0.002 mg/l Total residual Chromium 0.050 mg/l Copper 0.005 mg/l Cyanide 0.025 mg/l Cyanide 0.005 mg/l Amenable to chlorination ( ) Dissolved oxygen 6 mg/l To maintain as a minimum Fecal coliform 4200 counts /100 ml Based on a minimum of five (avg.) samples within a 30 day 4400 counts /100 ml period. Based on geometri-(in 10% of the cal mean fecal coliform samples) (either MPN or MF) Fluoride 1.8 mg/l Iron 1.000 mg/l Total a# , Iron 0.300 mg/l Soluble Lead 0.030 mg/l Manganese 0.050 mg/l MBAS 0.500 mg/l Foaming agents Mercury 0.0002 mg/l Instantaneous limit Mercury 0.00005 mg/l Monthly limit O 5.1-23
TABLE 5.1-2 (Continued) () WATER QUALITY LIMITS FOR LAKE ERIE (6) Constituent Limit Comment Mercury 0.0005 mg/l In any whole sample or (wet weight) representative aquatic organism. Nickel 0.025 mg/l Nitrate-N 10.0 mg/l Nitrate + nitrite 100.0 mg/l Oil and grease 5 mg/l Chlorofluorocarbon extract-ables. Surface water shall be free from floating oil, visible sheen or color film. No oil on the banks which will cause deleterious effects on the biota will be permitted. Pesticide -- Not to exceed Table 4 of O the' reference document or the Safe Drinking Water Act, whichever is more stringent. pH 6.5-9.0 No change attributable to man-induced concentrations. Phenolic compounds 0.001 mg/l Phosphorua <l.0 mg/l Total phosphorus as P. Applies only to areas where nuisance growths of algae, slimes and weeds that result in a violation of the water standards set forth in Chapter 3745-1 of the Ohio Administrative Code. Particulate ' esters 0.003 mg/l Polychlorinated Absent from public water biphenyls supplies () l l 5.1-24 l t
3, TABLE 5.1-2 (Continued) () WATER QUALITY LIMITS FOR LAKE ERIE (6) Constituent Limit Comment Selenium 0.010 mg/l Silver 0.050 mg/l Zinc 0.030 mg/l Toxic substances -- All pollutants or combina-tions of pollutants shall not exceed, at anytime, one tenth of the 96 hour median tolerance limit (TLN) of LCS o for any representative aquatic species. Persis-tent toxicants in the aqua-tic environment shall not exceed, at anytime, an application factor of one-hundredth applied to the 96 hour TLN or LC50-O 5.1-25 l
~~.,,J _ e- , , . - - - . L. M + aea ,b,,a . -, e a u a nMa as >u-e_a i~~
TABLE 5.1-3 () TEMPERATURE LIMITS FOR LAKE ERIE (6) Temperature I Average Daily Maximum (OF) (OC) (OF) (OC)
~~January 1-31 -- --~~
35 1.7 February 1-29 -- -- 38 3.3 March 1-15 -- -- 39 3.9 March 16-31 -- -- 45 7.2 April 1-15 43 6.1 48 8.9 April 16-30 53 11.7 56 13.3 May 1-15 59 15.0 63 17.2 May 16-31 63 17.2 72 22.2 June 1-15 75 23.9 78 25.6 j June 16-30 80 26.7 83 28.3
; July 1-31 83 28.3 85 29.4 l l August 1-31 83 28.3 85 29.4 24.4 September 1-15 76 81 27.2 September 16-30 71 21.7 76 24.4 October 1-15 66 18.9 71 21.7 i
October 16-31 58 14.4 63 17.2 l November 1-30 48 8.9 53 11.7 December 1-31 -- -- 46 7.8 Note: Indicates no " average" standard to be met. 1 0 5.1-26 l l
~~. - - . ,. . . - . . . - . . - - . - . , , . ,,-.-.--.,_..,.,,.,....,_...n,__-, , .,.. , , , , . . - ,,, , , - . . _ - , '~~
TABLE 5.1-4 () MONTHLY AVERAGE WATER LOSS, BLOWDOWN, AND MAKEUP FOR EACH OF THE TWO PNPP NATURAL DRAFT COOLING TOWERS (a) Evaporatio and Drift ( ) Blowdown Makeup (b) Month (gal / min) (gal / min) (gal / min) January 9,686 6403 16,144 February 9,062 5987 15,104 March 10,151 6713 16,919 April 11,167 7399 18,612 May 11,734 776E 19,557 June 12,270 8125 20,450 July 12,513 8288 20,856 August 12,406 8216 20,677 September 12,181 8066 20,302 October 11,511 7619 19,185 November 10,695 7075 17,825 December 9,848 6511 16,414 (a) Values are based on a 100 percent load factor and were calculated from monthly averages of hourly meteorological data collected at the site during 3 years: May 1, 1972, through April 30, 1973; May 1, 1973, through April 30, 1974; and Septem-
~~) ber 1, 1977, through August 31, 1978. ,,/ (b) Includes a monthly loss of 55 gal / min through the entrainment of droplets as drift.~~
I O 5.1-27
_ _ _ _ _ _ _ _ _ _ ._ _ -_____ ____ _ __ - ~ _ - _ . - o o o TABLE 5.1-5 ; LAKE TEMPERATURES, PLANT BLONDOWN WATER FIDWS AND TEMPERATURES EUR UNITS 1 AND 2 (Normal Operation, Seasonal Averages) (a) Discharge Inlet Lake Discharge Water Discharge Water Heat Flow Season Water Temp. (OF) Flow (GPM) Temp. Rise (OF) (M BTU / min) Winter (Dec.--Feb.) 36 49,700 20.0 8.27 Spring (Ma r. --May) 44 46,500 20.4 7.90 Summe r m (June-- Aug . ) 71 43,300 14.7 5.30 P h Fall (Sept.--Nov. ) 59 45,300 i3.9 5.99 Annual 52 46,200 17.8 6.85 (a) Based ora monthly averages
TABLE 5.1-6 SPRING AVERAGE DILUTION FACTORS FOR LAKE WATER INTAKES (V') WITHIN 50 MILES OF PNPP Distance Current Seasonally From Frequency Adjusted Plant Dilution Factor Dilution Location of Intake (Miles) Factor (Input) Factor IRC Fibers Co. 3.50 31.9 0.3 106.3 East System, OWC 4.20 35.3 0.4 88.3 Fairport Harbor 7.00 45.8 0.3 152.8 Painesv.ille 7.50 47.3 0.3 157.8 West System, OWC 10.00 54.0 0.3 180.2 Ashtabula 20.00 74.4 0.4 186.0 Union Carbide Metals 22.00 77.8 0.4 194.5 Conneaut 33.00 94.4 0.4 236.0 Cleveland 35.00 97.1 0.3 323.8 Avon Lake 50.00 115.5 0.3 385.0 Elyria 50.00 115.5 0.3 385.0 Lorain 50.00 115.5 0.3 385.0 ENE, 0.5 Miles 0.50 12.7 0.4 31.7 ENE, 1.0 Miles 1.00 16.2 0.4 40.5 ENE, 5.0 Miles 5.00 38.8 0.4 96.9 ENE, 10.0 Miles 10.00 54.0 0.4 135.1 WSW, 0.5 Miles 0.50 12.7 0.3 42.2 g- g WSW, 1.0 Miles 1.00 16.2 0.3 54.0 g ~'j WSW, 5.0 Miles 5.00 38.8 0.3 129.2 1 WSW, 10.0 Miles 10.00 54.0 0.3 180.2 I s u.) 5.1-29
1 TABLE 5.1-7 i () SUMMER AVERAGE DILUTION FACTORS FOR LAKE WATER INTAKES WITHIN 50 MILES OF PNPP Distance Current Seasonally From Frequency Adjusted Plant Dilution Factor Dilution Location of Intake (Miles) Factor (Input) Factor IRC Fibers Co. 3.50 34.2 0.3 114.1 East System, OWC 4.20 37.9 0.4 94.8 Fairport Harbor 7.00 49.2 0.3 164.0 Painesville 7.50 50.8 0.3 169.4 West System, ONC 10.00 58.0 0.3 193.4 Ashtabula 20.00 79.8 0.4 199.6
! Union Carbide Metals 22.00 83.5 0.4 208.8 Conneaut 33.00 101.4 0.4 253.4 Cleveland 35.00 104.3 0.3 347.6 Avon Lake 50.00 124.0 0.3 413.2 Elyria 50.00 124.0 0.3 413.2 j Lorain 50.00 124.0 0.3 413.2
ENE, 0.5 Miles 0.50 13.6 0.4 34.0 1 ENE, 1.0 Miles 1.00 17.4 0.4 43.5 ENE, 5.0 Miles 5.00 41.6 0.4 104.1 EUE, 10.0 Miles 10.00 58.0 0.4 145.0 WSW, n.5 Miles 0.50 13.6 0.3 45.3 s WSW, 1.0 Miles 1.00 17.4 0.3 58.0 i
~~Os WSW, 5.0 Miles WSW, 10.0 Miles 5.00 10.G0 41.6 58.0 0.3 0.3 138.7 193.4 i i J 4 k O 8 5.1-30 t~~
~~. ,-.__.,m, , , , _ - - - - _ - - - _ - - , - - .~~
~~TABLE 5.1-8~~
) FALL AVERAGE DILUTION FACTORS FOR LAKE WATER INTAKES WITHIN 50 MILES OF PNPP Diskance Current Seasonally From Frequency Adjusted Plant Dilution Factor Dilution Location of Intake (Miles) Factor (Input) Factor IRC Fibers Co. 3.50 32.2 0.3 107.2 East System, OWC 4.20 35.8 0.4 89.4 Fairport Harbor 7.00 46.7 0.3 155.7 Painesville 7.50 48.3 0.3 161.0 West System, OWC 10.00 55.2 0.3 184.1 Ashtabula 20.00 76.2 0.4 190.5 Union Carbide Metals 22.00 79.7 0.4 199.3 Conneaut 33.00 96.8 0.4 242.0 Cleveland 35.00 99.6 0.3 331.9 Avon Lake 50.00 118.4 0.3 394.8 Elyria 50.00 118.4 0.3 394.8 Lorain 50.00 118.4 0.3 394.8 ENE, 0.5 Miles 0.50 12.2 0.4 30.6 ENE, 1.0 Miles 1.00 15.9 0.4 39.7 ENE, 5.0 Miles 5.00 39.4 0.4 98.4 ENE, 10.0 Miles 10.00 55.2 0.4 138.1 WSW, 0.5 Miles 0.50 12.2 0.3 40.8 gx WSW, 1.0 Miles 1.00 15.9 0.3 52,9 t WSW, 5.0 Miles 5.00 39.4 0.3 131.2 \~') WSW, 10.0 Miles 10.00 55.2 0.3 184.1
['T 5.1-31
TABLE 5.1-0 WINTER AVERAGE DILUTION FACTORS FOR LAKE WATER INTAKES WITHIN 50 MILES OF PNPP Current Seasonally Distance Frequency Adjusted From Plant Dilution Factor Dilution Location of Intake (Miles) Factor (Input) Factor IRC Fibers Co. 3.50 30.6 0.3 102.0 East System, OWC 4.20 33.7 0.4 84.4 Fairport Harbor 7.00 43.4 0.3 144.5 Painesvi9 7.50 44.8 0.3 149.2 West Syc, ., OWC 10.00 51.0 0.3 169.9 Ashtabula 20.00 69.0 0.4 174.7 Union Carbide Metals 22.00 73.1 0.4 182.7 Conneaut 33.00 88.6 0.4 221.5 Cleveland 35.00 91.1 0.3 303.7 Avon Lake 50.00 108.3 0.3 360.9 Elyria 50.00 108.3 0.3 360.9 Lorain 50.00 108.3 0.3 360.9 ENE, 0.5 Miles 0.50 12.9 0.4 32.3 ENE, 1.0 Miles 1.00 16.2 0.4 40.6 7-sg ENE, 5.0 Miles 5.00 36.9 0.4 92.2 () ENE, WSW, 10.0 Miles 0.5 Miles 10.00 0.50 51.0 12.9 0.4 0.3 127.4 43.1 WSW,1.0 Miles 1.00 16.2 0.3 54.1 WSW, 5.0 Miles 5.00 36.9 0.3 123.0 WSW, 10.0 Miles 10.00 51.0 0.3 169.9 O 5.1-32
TABLE 5.1-10 ANNUAL AVERAGE DILUTION FAC'IORS FOR LAKE WATER INTAKES WITHIN 50 MILES OF PNPP Current Annually Distance Frequency Adjusted From Plant Dilution Factor Dilution Location of Intake (Miles) Factor (Input) Factor IRC Fibers Co. 3.50 32.2 0.3 107.4 East System, OWC 4.20 35.7 0.4 39.2 Fairport Harbor 7.00 16.3 0.3 154.2 Painesville 7.50 47.8 0.3 159.3 West System, OWC 10.00 54.5 0.3 181.9 Ashtabula 20.00 75.1 0.4 187.7 Union Carbide Metals 22.00 78.5 0.4 196.3 Conneaut 33.00 95.3 0.4 238.2 Cleveland 35.00 98.0 0.3 326.7 Avon Lake 50.00 116.5 0.3 388.5 Elyria 50.00 116.5 0.3 388.5 Lorain 50.00 116.5 0.3 388.5 ENE, 0.5 Miles 0.50 12.8 0.4 32.1 ENE, 1.0 Miles 1.00 16.4 0.4 41.1 ENE, 5.0 Miles 5.00 39.2 0.4 97.9 [ ENE, 10.0 Miles 10.00 54.5 0.4 136.4 WSW, 0.5 Miles 0.50 12.8 0.3 42.8 , WSW, 1.0 Miles 1.00 16.4 0.3 54.7 ' WSW, 5.0 Miles 5.00 39.2 0.3 130.5 WSW, 10.0 Miles 10.00 54.5 0.3 181.9 i O 5.1-33
O O O . TABLE 5.1-11 SWIM SPEEDS OF SOME LAKE ERIE CENTRAL BASIN FISH SPECIES Species Size (nun) Speed (fps) Duration Temperature (OC) Reference Rainbow smelt 134 1.15 Maximum sustained 6 Otto et al. (Reference 7) Carp 36-66 0.72-1.15 Brainbridge (Reference 8) 135 5.6 Darting Emerald shiner 65 TL 1.94 10 min. 7-20 Jones et al. (Reference 9) Quillback 24 0.7 Sustained 23.9 King (Reference 10) White sucker 33 TL 0.72 10 min. 7-20 Jones et al. (Reference 9) 67 1.05 10 min. 7-20 g 100 1.21 10 min. 7-20 Os
~~Trout-perch 72 TL 1.80 10 min. 7-20 Jones et al. (Reference 9)~~
White crappie 60-88 TL 0.54 Maximum sustained 21.1-28.9 King (Reference 10) 66-95 0.61 Maximum sustained 21.1-26.6 Yellow perch 102 0.33 Maximum sustained 2 Otto et al. (Reference 7) 0.49 Maximum sustained 7 0.66 Maximum sustained 13 O.82 Maximum sustained 26 1 1
TABLE 5.1-12 t MAJOR ROADWAYS, COMMERCIAL SHIPPING PORTS, LAKES, AND RIVERS IN THE VICINITY OF THE PNPP SITE Distance (a) (miles) and Major Roads (b) Direction from the PNPP U.S. Route 20 1.3, SSE Ohio Route 2 3.0, WSW Ohio Route 84 3.5, SSE Interstate 90(c) 5.0, SSE Ohio Route 528 4.9, E Commercial Shipping Ports, Lakes, and Rivers Fairport 7.5, WSW Ashtabula 22.0, ENE
~~) Grand River 4.6, SSE~~
} Lake Erie W through NE (a) Rounded off to the nearest one-tenth of a mile; 16-point compass used. l (b)Unless otherwise indicated, all roads listed here are classified as asphalt, medium duty. (c) Classified as asphalt, heavy duty. J l 5.1-35 l 1 l
TABLE 5.1-13 () AIRPORTS AND POPULATION CENTERS IN THE VICINITY OF THE PNPP SITE Distance (a) (miles) and Direction from Airport the PNPP Concord 10.0, SSW Casement 6.3, SW Eckerd 9.8, SE Woodworth 4.5, ESE Population Center Painesville-on-the-Lake 5.0, WSW Lane 4.0, SSW Perry 3.0, S North Perry 1.2, S,SE () Madison Genung Corners 5.3, ESE 5.0, ESE North Madison 5.0, E Redbird 3.5, ENE Madison-on-the-Lake 5.0, ENE (a) Rounded off to the nearest one-tenth of a mile; 16-point compass used.
\
O 5.1-36
O O O / TABLE 5.1-14 MAXIMUM MONTHLY FREQUENCIES OF VISIBLE PLUMES LONGER THAN 0.25 MILE Maximum Frequency (hr/ month) at Indicated Direction from the Cooling Towers Month NNE NE ENE E ESE SE SSE S SSW SW WSW W WNW NW NNW N j January 14.3 44.7 77.8 42.7 21.6 8.0 4.8 8.8 8.0 24.3 34.7 19.2 4.8 12.8 10.0 10.0 February 8.6 33.0 50.8 39.6 19.3 22.4 5.6 17.8 9.2 21.3 26.9 15.8 10.7 4.6 2.0 8.1 March 3.1 6.3 34.5 ~33.5 8.9 11.5 4.7 7.8 2.6 11.5 16.7 12.0 7.8 3.7 8.9 9.4 April 2.7 4.7 14.9 7.5 11.4 5.9 3.9 3.9 5.9 8.6 0.4 0.4 0.4 0.8 0.8 1.2 May 0.0 2.6 2.1 3.1 3.1 1.5 0.5 2.1 0.5 2.6 1.0 0.5 0.0 1.5 0.0 1.0 June 0.6 2.3 0.6 0.6 0.0 1.7 3.4 0.0 0.0 0.6 0.0 0.0 0.6 1.1 1.1 0.6 July 0.0 2.2 1.3 2.6 0.4 0.0 0.0 0.0 1.3 0.9 0.9 1.3 0.9 1.7 0.0 0.0 gn August 3.5 1.7 6.2 3.5 2.1 0.7 1.7 0.0 0.3 1.0 0.7 0.4 1.0 1.0 1.7 1.0 h[ September 1.8 1.8 0.6 0.6 0.0 1.8 2.4 2.4 0.0 1.8 0.6 2.4 1.8 1.8 1.2 1.8 w October 4.1 4.5 3.0 0.8 0.8 4.5 4.5 0.4 0.4 1.9 2.3 1.1 2.6 4.9 2.6 1.5 November 12.1 8.3 6.4 6.0 6.8 4.9 2.3 3.4 3.4 7.2 4.2 8.7 7.2 12.1 4.9 4.2 December 30.8 60.9 22.7 20.2 14.3 8.1 9.5 6.6 7.0 26.8 15.0 20.2 9.9 14.7 16.1 18.7 r
i O t 58 ; i e i e i i i 1 55 - - I j .s 4 50 - -
h Relative Humidity t M $ 100% $ 45 - -
E c { 75% 1 i $ ! j 40 -- - w
~~$ 50%~~
i 35 - 30% ! 30 l 10 20 30 40 50 60 70 80 Ambient Wet-Bulb Temperature,8F J 1 i PERFORMANCE CURVES FOR EXIT AIR FLOW . R ATE vs WET BULB TEMPER ATURE I AND RELATIVE HUMIDITY PERRY NUCLEAR POWER PLANT 1 & 2
-O THE CLEVELAND ELECTRIC ILLUMINATING COMPANY FIGURE 5.1-1 5.1-38
~~i O 6 i 6 i i i i 125 - Relative Humidity i 30%~~
~~! 50%~~
115 ~ 75% p 100% II i E 105 A i 4 5 kw 95 - - O 85 - -- 75 10 20 30 40 50 60 70 80 Ambient Wet-Bulb Temperature, OF 1 PERFORMANCE CURVES FOR EFFLUENT AIR TEMPERATURES vs WET-BULB TEMPER ATURE
;' AND RELATIVE HUMIDITY PERRY NUCLEAR POWER PLANT 1 & 2 THE CLEVELAND ELECTRIC i l ILLUMINATING COMPANY FIGURE 5.1-2 5.1-39 ,-)
1000 1000 0 ! 900 - - 900 800 - 800 l I 700 - - 700 I i I I [ 600 - - 600 g il a - I
~~! I j 500' -~~
l - 500 i I 5 a i I s f 1 400 - I I
~~- 400 \ l 1~~
300 - 300 2 i ATmax = 2.3 1 200 - 200 l 1 1 clotes: (1) The Confining Boundary is at 4 the Lake Surface G - (2) Temperatures are in Degrees Fahrenheit 0 l I I I I i 1 0 200 100 0 100 200 Lateral Distance From Discharge Centerline,(Feet)
- - - -- Indicates HOR!ZONTAL TEMPERATURE PROFILE AT THE Centerline o s CONFINING BOUNDARY, Plume Travel SPRING CONDITIONS PERRY HUCLEAR POWER PLANT 1 & 2 THE CLEVELAND ELECTRIC FIGUHE 5.1-3 ILLUMIN ATING COMPANY 5.1-40
g 1000 , 1000 I I 900 - I - 900 l I I 800 - - 800 l I I 700 - l - 700 o I
- 1 600 - - 600 j l a l E I
~~} 500 - -~~
500 g a s I i I j 400 -- l - 400 I fd 3 l j 300 - ! - 300 l AT max = 1.8 I I 200 - 200 10 g Notes: (1) The Confining Boundary is at 100 -
- 100 the Lake Surface (2) Temperatures are in Degrees Fahrenheit 0 l I I I I I I O 200 100 0 100 200 Lateral Distance From Discharge Centerline,(Feet) 4 - - - -Indicates HORIZONTAL TEMPERATURE PROFILE AT THE Centerline of CONFINING BOUNDARY, Plume Travel SUMMER CONDITIONS PERRY NUCLEAR POWER PLANT 1 & 2 THE CLEVELAND ELECTRIC FIGURE 5.1-4 ILLUMIN ATING COMP ANY O
5.1-41
1000 1000 O 1 I 900 -
~~- 900 I~~
~~l I 800 -~~
~~- 800 l~~
~~l I 700 - l - 700~~
, I i I 600 - ! -
~~600 j i~~
=
E 1 3 I g 500 - - 500 l 3 i I j 400 - l - 400 p V I l 300 - 300 I AT max *19 i 1 200 - 200 l 10 l 1 100 - Notes: (1) The Confining Boundary is at - 100 the Lake Surface (2) Temperatures are in Degrees Fahrenheit O l l l l l l l 0 200 100 0 100 200 Lateral Distance From Discharge Centerline,(Feet)
- - - - Indicates HORIZONTAL TEMPERATURE PROFILE AT THE Centerline of CONFINING BOUNDARY, Plume Travel FALL CONDITIONS PERRY HUCLEAR POWER PLANT 1 & 2 THE CLEVELAND ELECTA:C FIGURE 5.1-5 ILLUMIN ATING COMPANY l l 5.1-42 i l
1000 1000 l I 900 - - 900 l I I 800 - ! - 800 l I I 700 - - 700 g
~~? I i-4 I~~
~~( 600 - l~~
~~- 600 1~~
o I g E I P s I 500 - I - 500 s I
.E a Q l 1 1 j 400 - - 400 Point of Contact g
~~f. g g~~
( 3 Plume Centerline l With Lake l 300 - l - 300 (T 9") 1 I 200 - - 200 2' Notes: (1) The Confining Boundary is at max " # 100 - - 100 the Lake Bottom (2) Temperatures are in Degrees 5 Fahrenheit 0 I I I l l l 0 200 100 0 100 200 Lateral Distance From Discharge Centerline,(Feet)
- - - - Indicates HORIZONTAL TEMPERATURE PROFILE AT THE Centerline of CONFINING BOUNDARY, Plume Travel WINTER CONDITIONS PERRY HUCLEAR POWER PLANT 112 THE CLEVELAND ELECTRIC FIGURE 5.1-6 ILLUMIN ATING COMPANY
, J 5.1-43
o o o Low Water Datum - USGS Elev. = 570.5 Feet 0 l I 2 1 3 - l 8 2-5 - I I
~~? I 2 7 -~~
~~_ jo _ 5- 3 I , 4 e I a I~~
~~$n i~~
~~{ 5 13 - l l 14 i5~~
~~-} - /~~
a / Discharge 16.2 P # Point - NOTE: Temperature Differentials are in Degrees Fahrsnheit 17 I I I I I I I I 19 (Bottom) 0 100 200 300 400 500 600 700 800 900 1000 Longitudinal Distance from Discharge Point,(Feet)
= = --- Indicates Centerline "*"' PREDICTED TEMPERATURE PROFILES, VER'ilCAL CROSS-SECTION, SPRING CONDT!ONS
~~PERRY NUCLEAR POWER PLANT 1 & 2 THE CLEVELAND ELECTRIC FIGURE 5,1-7 ILLUMIN ATING CGMP ANY~~
o o o Low Water Datum - USGS Elev. = 570.5 Feet 0 F--------~~~~---~~~~~---------~~---" 1
~~- I l~~
~~3 - '* I I 5 - I~~
~~,I 7 - 2 j "~~
~~if 3 e - I I z~~
~~= 11 ,I jo 1 I u, s is - /~~
~~'T 14 < Oi 15 -~~
~~/ 20 Discharge 16.2 -{-~~
Point -'- NDTE: Temperature Differentials are in Degrees Fahrenheit 7 3o I 19 (Bonom) 0 100 200 300 400 500 600 700 800 990 1000 Longitudinal Distance from Discharge Point,(Feet)
~~-- - - - Indicates Centerline of Plume Travel PREDICTED TEMPERATURE PROFILES, VE RTICAL CROSS-SECTION.~~
SUMMER CONDITIONS l PERRY NUCLEAR POWER PLANT 1 & 2 THE CLE VELAND E LECTelC FIGURE 5.1-8 ILLuulN ATING Comp ANY
o o o O 3 - lllr_______________________ go 5 o 20
~~} l -~~
~~l 9 [ i ,-~~
~~] 11 l~~
~~t I 5 13 /~~
~~'y 14 a g 15 - /~~
Discharge 16.2 -t-Point NOTE: Temperature Differentials are in Degrees Fahrenheit 3e 17 - [ 19 (Bottom) 0 100 200 300 400 500 600 700 800 900 1000 Longitudinal Distance from Discharge Point,(Feet)
----- Indicates Centerline of Plume Travel PREDICTED TEMPERATURE PROFILES, VERTICAL CROSS-SECTION, FALL CONDITIONS PERRY HUCLEAR t OWER PL ANT 1 & 2 THE CLEVELAND ELECTRIC FIGURE 5.1-9 ILLUMIN ATING COMP ANY
o o o .I 4 Low Water Datum - USGS Elev. = 570.5 Feet i 0 1 3 - 5 - o j 7- 1*
~.
~~3 9 E f 11 2 il 5 13 3* 14 T~~
~~$ 15 '-~~
Discharge Point 16.2 P = ~ % ' % ~ NOTE: Temperature Differentials are in Degrees Fahrenheit l 19 L--- '--- I--- L-- b-- b-- b-- 1---- (Bottom) 0 100 200 300 400 500 600 700 800 900 1000 i Longitudinal Distance from Discharge Point,(Feet)
~~----- Indicates Centerline PREDICTED TEMPERATURE PROFILES,~~
VERTICAL CROSS-SECTION, WINTER CONDITIONS

PERRY NUCLEAR POWER PLANT 1 & 2 1
~~THE CLEVELAND ELECTRnC~~
! FIGURE 5.1-10 IL LUMIN ATING COMP ANY
1 Low Water Datum . USGS Elev. 570.5 Feet ! 1 0 SPRING Note: Temperatures are in Degrees Fahrenheit ISDTHERMS l 2 5-
~~.2 - ~~~
~~5 l~~
~~.' /~~
~~2 ~ 3 / 3 p~~
~~)5 10 - -~~
~~p p 1 I~~
-E - ,/ l f~ - -15 o ' to 5 /
Discharge 16.2--h AT = 20.4 -- - - """ ~ ~ 1 Point o 2 (Bottom) 19 i i i ; , , ; i , ; 3 0 10 20 30 40 50 60 70 80 90 100 110 120 Low Water Datum USGS Elev. 570.5 Feet 0
~~- SPRING j[~~
~~_ ISDVELS 1 fps 5-~~
~
~~N ~ t m 10 -~~
~~~- h 2 fps y,'~~
~~a - /~~
~~'s # s~~
~~l - S - j _~~
~~. 3 fps , - "' = 10 f ps '8' "" ~~~
Dc ' - " " " ~ pn 16.2--+ '!, = 14.7 f ps - - (Bottom) 19 i i g g , , , ; , y 3 0 10 20 30 40 50 60 70 80 90 100 110 120 Longitudinal Distance from Discharge,(Feet) PREDICTED TEMPERATURE AND VELOCITY PROFILES
--- Indicates WITHIN 120 FEET OF DISCHARGE POINT, Centerline of VERTICAL CROSS-SECTION, Plume Travel SPRING CONDITIONS PERRY NUCLEAR POWER PLANT 1 & 2 l THE CLEVELAND ELECTRIC FIGURE 5.1-11 I ILLUMINATING COMPANY 5.1-48 t
Low Watrr Datum - USGS Elev. 570.5 Feet SUMMER Note: Temperatures are in Degrees Fahrenheit ISOTHERMS /
~~/ ')~~
~~2* /~~
~~, 5- /~~
~~3 - #~~
~~/ \~~
~~i -~~
/
4 . / 10 - l l
~~.9 - %o /~~
~~5 - 3 / I $ T, f~~
~~/ . 10' 5 s'l D c arge 16.2 "~~
p A r, = 14.7 - -- (Bottom) 19 i T- i i i i i i i i i 0 10 20 30 40 50 60 70 80 90 100 110 120 Low Water Datum USGS Elev. 570.5 Feet 0
- SUMMER j ISOVELS j,, / / /
~~D 5- / I - 2 fps /~~
~~/ =~~
~~E -~~
~~/ " /~~
~~10 - /~~
$ ~ / ~a ~ 3 fps /
~~y o~~
/
~~A 10 fps 5 fps f 0 erge 16.2 - p V, = 13.7 fps -~~
/
~~Ifps (Bottom) 19 i i i i i i i i i i~~
~~/ i 0 10 20 30 40 50 60 70 80 90 100 110 120 Longitudinal Di.tance from Dischary. (Feet)~~
PREDICTED TEMPERATURE AND VELOCITY PROFILES Indicates WITHIN 120 FEET OF DISCHARGE POINT, Centerline of VERTICAL CROSS-SECTION, Plume Travel , SUMMER CONDITIONS , PERRY NUCLEAR POWER PLAmi 1 & 2 l THE CLEVELAND ELECTRIC FIGURE 5.1-12 ILLUMINATING COMPANY 5.1--49
Low Water Datum - USGS Elev. 570.5 Feet FALL Note: Temperatures are in Degrees Fahrenheit ISOTHERMS
~~- _g o o 5- ~~~
~~N p~~
$ / ~. - /
~~8 - /~~
$= - / / " 10 - /
~~kca - ha 3~~
/
~~s' 5 /~~
$ _ 5 / *1C \ '
D
~~""~~~~
pn 16.2 ] A To = 15.9 (Bonom) 19 , , , , , , , , , , , 0 10 20 30 40 50 60 70 80 90 100 110 12G Low Water Datum USGS Elev. 570.5 Feet 0 _ FALL 1 fps [ _ ISOVELS O ? 5-
' 2 f ps / / /
~~y y -~~
\/
~~3 -~~
/1 f / ". 10 -. -
~~5 s~~
~~- A 3 fps Nl/p/~~
~~10 fps S fps~~
~
D arge 16.2--4 " " p V, = 14.3 fps - - - - - (Bottom) 19 , , , , , , , , , 0 10 20 30 40 50 60 70 80 90 100 110 120 l 1 Longitudinal Distance from Discharge,(Feet) REDICTED TEWERAWRE AND VELOCIM PROMES
- --- Indicates WITHIN 120 FEET OF DISCHARGE POINT, Centerline of VERTICAL CROSS-SECTION, Plum Travel FALL CONDITIONS PERRY NUCLEAR POWER PLANT 1 & 2 THE CLEVELAND ELECTRIC FIGURE 5.1-13 ILLUMtNATING COMPANY 5.1-50
i Low Water Datum - USGS Elev. 570.5 Feet ! 0 l
~~- WINTER Note: Temperatures are in Degrees Fahrenheit ISOTHERMS O -~~
~~5-j -~~
~~- 2o b - $ ~~~
~~t - fg 10-3 co - y _ 5 o - 10 D charge 16.2~~
~
~~AT, = 20.0 . --~~
\ -H--___ _ _ _ _ _ _ _ _ ,,,,, -15 j ,,,,,, _ _ _ _ _
~~(Bonom) 19 x i i i i i~~
] i e i i } i 0 10 20 30 40 50 60 70 80 90 100 110 120 Low Water Datum USGS Elev. 570.5 Feet 0
~~_ WINTER ISOVELS Ifps O i 5- )~~
~~? -~~
~~4 10 a _ 2 fps~~
~~~ ,E ] 3 fps 10 fps 5 fps \~~
~~0C ] p~~
9' 16.2 -i Vo = 15.7 fps- - ----.- .. _ _ _ _ _ ,___ ~
(Bottom) 19 Y i i i i i i i i i 0 10 20 30 40 50 60 70 80 90 100 110 120 Longitudinal Distance from Discharge,(Feet) PREDICTED TEMPERATURE AND VELOCITY PROFILES
'5 WITHIN 120 FLET OF DISCHARGE POINT, Centerline of VERTICAL CROSS-SECTION, Plume Trawl WINTER CONDITIONS O PERRY NUCLEAR POWER PLANT 1 & 2 THE CLEVELAND ELECTRIC FIGURE 5.1-14 ILL8JMINATING COMPANY 5.1-51
' 10 ' ,p . , , ,.,,
0 , 4 6
? / ' .-j . ,/
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ANNUAL FREQUENCY OF OCCURRENCE OF 1 0.5 0 1 2 3 4 Miles ELEVATED VISIBLE PLUMES, (hours per year) PERRY NUCLEAR POWER PLANT 1 & 2 THE CLEVELAND ELECTRIC l ( ILLUMINATING COMPANY FIGURE 5.1-15 l l 5.1-52
1 I 1 1 01 s a a a e e a a i 1
~~.nz - !~~
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# ..,( . '.h ..3......., ; . . . . . . . . , , . . ..] .005.as- -- ~h n?.-.,g-]D. .< . < ,,,.1 + .3 g/ ., ., . .
g. (" * = , [gh, . = .k, M ' ' ' '
%. _. / .-- ' M. b' 1
ANNUAL GROUND DEPOSITION OF DISSOLVED ' SOLIDS IN CIRCULATING COOLING WATER 1 0.5 0 1 2 3 4 Miles (pounds per acre per year) PERRY NUCLEAR POWER PLANT 1 & 2 THE CLEVELAND ELECTRIC , ILLUMINATING COMPANY FIGURE 5.1-16 5.1-53 1 _ . . _ _ , . . . . , . . _ , _ _ _ . . . _ _
1000 , i i i i i i i i i i i i
~
~~050 - O get - 050 - 1 000 - 750 - 1 700 -~~
- Maximum penetration height 650 - Neutral buoyancy height -
~~600 - 550 - E. - 3500 -~~
"+
~~E -~~
450 - yCloud water Vertical velocity _ 400 - r 350 - 300 - 250 - Ambient temperature _ Plume temperature # 200 150 - 100 - 50 0 -6 4 2 0 2 4 6 0 10 12 14 16 C Temperature 0 2 1 0 1 2 3 4 5 6 7 8 9 10 m/sec Vertical Velocity
~~.4 .2 0.0 .2 .4 .G .0 1.0 1.2 1.4 1.6 1.0 2.0 g/kg Cloud Water~~
) PLUME PARAMETER VARIATIONS, AVERAGE WINTER MORNING CONDITIONS l PERRY NUCLEAR POWER PLANT 1 & 2 1 THE CLEVELAND ELECTRIC ILLUMINATING COMPANY FIGURE 5.1-17 5.1-54 i
~~.- -- , . , . - , . . ~ - _ , , _ , - . , _~~
1000 i i i i i i i i i i i 6 060 - - O - - - 850 - -
~~~ ~~~
~~Maximum penetration height ~ 750 - -~~
~~Neutral buoyancy height 650 - -~~
600 - - 550 - - c E 500 - Vertical velocity -
~~? . Ambient temperature -.~~
450 - - 400 - - 359 - p Cloud water - 300 - - Plume temperature 250 - f _ 200 - - 150 - 100 - - , H - - .l 12 14 16 18 20 22 24 26 28 30 32 *C Tempwature 0 O 1 2 3 4 5 6 7 8 9 10 m/sec Vertical Velocity 0 .2 .4 .6 .8 1.0 1.2 1.4 1.6 1.8 2.0 g/kg Cloud Water PLUME PARAMETER VARIATIONS, AVERAGE SUMMER MORNING CONDITIONS PERRY NUCLEAR POWER PLANT 1 & 2 THE CLEVELAND ELECTRIC ILLUMINATING COMPANY FIGURE 5.1-18 5.1-55 i
1000 i i i ! i i i i i i i i SM - 900 - - 850 - - 800 - - 750 - - 700 - - 650 - 10 km l5km 3km _ 600 - - e 550 - - 3 h {500 5 450 - - 400 - 350 - - 300 - 250 - ' - 200 - 150 - 100 - 50 - g I e i i I e i i e i i i t 70 75 80 85 O 1 2 3 4 5 6 7 8 9 10 Ambient Relative Humidity,% Excess Reletive Humidity at Plume Centerline,% EXCESS RELATIVE HUMIDITY, AVERAGE WINTER MORNING CONDITIONS PERRY NUCLEAR POWER PLANT 1 & 2 THE CLEVELAND ELECTRIC ILLUMINATING COMPANY FIGURE 5.1-19 5.1-56
1 1000 1 4 i i i i i i i e I e m - - O See - - SH - - 800 - - 7H - - 10 km Skm 3km
~~, 700 - -~~
l i SH - - See - - 550 - - 1.See
}
z I 450 - 400 - O 350 - 300 - 250 - 200 - 150 - 180 - 50 - 0 ' ' ' ' ; i I ' ' ' I I ' SO 65 70 75 00 0 1 2 3 4 5 6 7 3 g Ambient Relative Humidity, % Excess Relative Humidity at Plume Centerline, % EXCESS RELATIVE HUMIDITY, AVERAGE SUMMER MORNING CONDITIONS , PERRY NUCLEAR POWER PLANT 1 & 2 THE CLEVELAND ELECTRIC ILLUMINATING COMPANY FIGURE 5.1-20 j 5,1-57 l l l- _____...___ , _.. . --
~~-__ _ __ -.___--__-._-___.~. ,__._ ._.-____ ._,__.- -._ ,___...- ~-----_.-- - -~~
i i i i i i i i i 1300 - - 0 1200 - - 1100 - - 1000 - - Summer 900 - - 500 - - h700 - - i 2 j Winter 600 - - 500 - - 400 - - 300 - - 200 - - l 100 - - 0 ' ' ' ' ' ' ' ' ' 1.2 -0.0 0.4 0 0.4 0.0 1.2 1.0 2.0 Vertical Ternperature Gradient, C/100 meters VARI ATION OF COOLING-TOWER PLUME HEIGHT WITH AMBIENT VERTICAL TEMPERATURE GRADIENT (STABILITY) PERRY NUCLEAR POWER PLANT 1 & 2 THE CLEVELAND ELECTRIC ILLUMINATING COMPANY FIGURE 5.1-21 l 5.1-58
i i i i 6 i i i 6 1300 - 1200 - - i 1100 - - 1000 - - l 888 - Winter 300 - I 700 Summer 800 - - 500 - - 1 400 - - I 300 - - 200 - - 100 - - g i t i i e i i t i e 2.5 E 7.5 10. 12.5 15. 17.5 20. Ambient Wind Speed at Tower Top, m/sec I VARIATIONS OF COOLING-TOWER PLUME HEIGHT WITH TOWER TOP WIND SPEED PERRY NUCLEAR POWER PLANT 1 & 2 I i THE CLEVELAND ELECTRIC l ILLUMINATING COMPANY FIGURE 5.1-22 i ! 5.1-59 __ _ - . _ _ _ _ . _ _ _ . _ - . _ _ _ _ _ - . - - ~ _ . - . . _ . _ _ . . . . . _ _ -
)
i o ; l l i APPENDIX A5.1 MATHEMATICAL MODEL USED FOR PLUME ANALYSIS O O
i l l The HOTSUB2 plume analysis model is documented below as an indepen- l dent entity from the earlier version of HOTSUB described in the ER/CP. The following differences should be noted:
~~1. The present code includes boundary conditions for the subsurface jet dispersion model. The previous code did not.~~
~~j 2. The present code assumes that passive diffusion is~~
the dominant mechanism of surface transport. This assumption is based on the fact that most of the momentum in the subsurface jet will be dissipated in a bubble or other surface disturbance. The previous analysis assumed that the jet momentum was not dissipated at the surface, and surface transport was analyzed as a jet-driven turbulent entrainment phenomenon.

Program Description O The HOTSUB2 computer program was adopted from the work of Koh and Fan II) and NRC Regulatory Guide 1.113.(2) With an input of discharge design, discharge-flow parameters, and receiving-wate characteristics, the code generates excess temperature l profiles in the ambient receiving water. The format of the output is such that isotherms can be plotted for horizontal planes at selected depths. In addition, by using the data from j the isothermal contours, the program calculates isothermal surface areas and volumes. The code can also be used to produce similar
~~, information on the dilution of excess contaminant concentrations. The analytic formulation of the model is described in the following sections. 1 Subsurface Jet Dispersion Analysis~~
~~When hot cooling water is released through a discharge structure, the effluent induces a strong momentum transfer resembling a~~
{} AS.1-1
jet. Since the heat effluent is usually warmer than the receiving water, there is a tendency for the effluent to float upward
~~-)'~~
as it propagates in the direction of the release of the discharge. As an effluent travels in the direction of the release, it begins to dissipate its forward thrust (due to momentum transfer) and buoyant thrust (due to mixing with colder ambient water). When the effluent dissipates most of its momentum, it ceases to behave as a jet and continues to disperse as a passive layer of water where mixing is dominated by the ambient currents and turbulence of the receiving body of water. For the purposes of model develop-ment, the discharge flow field is divided into two regions:
1. Near field. Dispersion primarily influenced by the flow characteristics of the jet and the design of the discharge structure.

2. Far field. Passive diffusion dependent on ambient flow characteristics and local climatology.
O l :his section concerns the near-field analysis. The far-field analysis will be described in the next section. The approach used in the near-field-dispersion analysis makes use of the equations of conservation of mass, momentum, density deficiency (the difference between jet-water density and ambient water density), and temperature deficiency (the difference between jet-water temperature and ambient water temperature). These equations can be written as follows:* Conservation of mass hh=E (1) {)
~~Symbols are defined in the List of Symbols on page AS.1-9.~~
AS.1-2
Conservation of momentum d (M cosG) =0 (2) d (M' sing) =f ds (3) Conservation of density deficiency flux dF d Pa y= es 0 (4) i Conservation of temperature deficiency flux dG dT a > g= ds 0 (5) Equations (1) through (5) make up a set of 5 equations with 7 unknowns (0, E, M,6, f, F, G). To complete the solution set, assumptions are made which allow E (the entrainment function and f(the buoyancy force) to be expressed in terms of the other variables. These are
~~1. The cross-sectional variation for jet velocity, density, and temperature distribution is assumed to be Gaussian.~~
~~The profiles are given by u* (s,r) = u (s) exp (-r 2/b 2) (6)~~
~
~~2 2 9a P * (s,r) = 9a P (s) exp (-r /A r b) (7) 1 2 T a = T*(s,r) = T a~~
~~-T (s) exp -r 7A 2b2) (8) lO AS.1-3~~
~~2. The entrainment function is assumed to be proportional to the jet velocity and the jet boundary circumference.~~
The proportionality is expressed as E=d r (2nb) u (s) (9) By use of Gaussian profiles, the quantities Q, M, F,G, and f can be written in terms of u,P , T, and b. For example, f=9 f(Pa area 9 *) dA
= 2ng p, - p (s ) exp ( -r 2/Ar b) (rdr) 2 =n A b g 9 - p(s) r 3 After manipulation of these equations, the buoyancy force and the entrainment function can be written 1+A f= gQF (10)
(] U 2M a E=23n 2 r iN Ill) Equations (10) and (11), along with equations (1) through (5), form a complete solution set. The computer code has been developed to solve this set. Three other aspects of the model should be noted:
1. In any discharging jet there exists a zone of flow estab-lishment extending a few diameters from the exit plane where the cross-sectional velocity profile changes from a " top hat" profile (uniform velocity at the exit _ plane) to a Gaussian profile. Experimental investigations (3) have shown that this zone of flow-establishment extends 6.2 port diameters from the exit point. The model, AS.1-4
~~therefore, starts the calculations at 6.2 diameters~~
~~- away from the exit point.~~
2. The model developed by Koh and Fan III assumed that dis-charges were made into receiving waters of infinite extent. The present model has been modified for use in discharge situations where this neglect of finite boundaries is not realistic. The modification essentially involves the requirement that energy be conserved within the boundaries of the receiving water. Computationally this requirement means that no heat is allowed to be artifically lost across the surface or bottom boundaries.

3. The model equations use the distance (s) along the jet centerline as the independent variable. The centerline distance is related to the x and z coordinates by dx = ds cos6
~
dz = ds sin 6 The method of calculation used in the model is as follows. Starting with the exit-plane jet-discharge data, the conditions at the end of the zone of flow-establishment are computed. Using these values as initial conditions, the program solves the set of equations defined by (1) through (5) , (10), and (11) to give Q, M, F, and G. The results are then converted to the physical centerline variables u,p, and T and a variabic b, which describes the plume width. The conversions are carried out by inverse transformations. With the centerline values for T established, the excess temperature field is computed by invoking the Gaussian profile assumption. Passive Turbulent Diffusion Analysis When warm-water effluent loses its discharge and buoyant momenta and spreads as a passive turbulent layer, the dispersion of AS .1-5
the effluent is primarily governed by ambient flow characteristics , and local climatology. The basic equation governing the made of dispersion in this far-field region is the diffusion equation. F the case of constant release of heated effluent into a steady osiironment where longitudinal transport by dif fusion is small compared to advective transport, the diffusion equation is U N=1 K N + A K (12) 3x By y by Sz , z Bz)I e T is defined here as being the temperature er' ,3 above ambient. Equation (12) may be generalized to represent either an excess temperature field or an excess contaminant-concentration field. The generalized equation can be written U = K + K 1-Kcd (13) y z If the diffsuion coefficients, K and K z, are assumed constant, p the decay term in equation (13) can be removed through the trans-formation c(x,y,z) = X. ( x , y , z ) exp - K dx/U (14) result!ing in the following equation for the nondecaying concen-tration U 3x U= K y32 b + K z32z (15) It is assumed that the discharge is located at the point (0,ys'*s)' i.e., at the origin of the x axis and a distance y s fr m the shoreline and z s beneath the water surface. For a large lake of constant depth d and straight shoreline the solution is X= f I'z,z,zs,d) f (ay,y,y s) (16) 2rruoa yz O AS.1-6
where _ _ (~T N/ (2md + zs -z)2 f(az,z,zs,d) = )[ exp - m=-on l 20g 2 (2md - z s -*) l
~~+ exp -~~
~~2 I 2oZ 2 (Y s - Y)2 (Ys+YI f (ay,y,ys ) * **P - 2o 2~~
~~+ **P -~~
~~2o 2 Y - Y - 2Ky x 2K~~
~~Z ay *) u '~~
az \u In Equation (16), the condition that there be no flux of material through the bounding surfaces is ensured by placement of an image source of strength W at y = -y and an infinite series s of image sources along the z axis. For cases in which X represents excess temperature, the surface boundary condition given here rg requires that there be no exchange of heat with the atmosphere. O The use of equation (16) in the present model is as follows. Given an excess temperature (or concentration) at the discharge point, the near-field model computes plume centerline quantities to the intersection of the centerline with the water surface. The coordinates (i.e., y=0, z=0, with z =0 assumed) and the s excess temperature (concentration) at this point of intersection are substituted into (16) to solve for the " virtual source distance." The " virtual source distance" is defined as being that source distance from the intersection of the plume centerline with , the water surface that, through turbulent diffusion only, would result in the same excess temperature (concentration) as computed by the near-field model. This calculated " virtual source distance" is used to redefine the coordinate system such that the origin of the x axis is at the location of the virtual source. The far-field analysis is then carried out beyond the plume centerline-Cs) l l AS.1-7 l I h L. i
water-surface intersection by applying equation (16) in the rs new coordinate system. V Summary of Model Use The input parameters necessary to run the program are:
l. Discharge design

a. Slot jet

b. Single port round jet

c. Multiport system

2. Discharge structure
~~, a. Discharge depth~~
~~b. Discharge flow area~~
~~! c. Discharge angle l~~
~~3. Flow characteristics~~
~~(~h a. Flow rate 1~~
~~\- # b. Temperature excess (or concentration excess)~~
4. Receiving water characteristics

a. Ambient turbulence

b. Ambient currents With the aiven input, the program generates excess temperature (or excess concentration) profiles in the ambient receiving waters. The format of the output is such that isotherms (isopleths) may be plotted for horizontal planes at selected depths. In addition, by using the data from the isothermal (isopleth) contours, the program calcualtes isothermal (isopleth) surface areas and L volumes. A numerical record of the path of the plume centerline, along with the values of various centerline quantities, is also part of the program output.
~~f i f> u-AS.1-8 l~~
~~,. -- - , -w- - - , _ , ,~ . ..-- -n ..~~
s LIST OF SYMBOLS s E = entrainment function F = density deficiency G = temperature Gy = initial value of temperature deficiency flux K = kinematic surface heat exchange coefficient e K d
~~= decay coefficient K = lateral diffusion coefficient (horizontal) y K = vertical diffusion coefficient M = kinetic momentum M' = momentum M~~
~~y = initial value of kinematic momentum Q = volume flow Q1 = initial value of volume flow T = temperature or temperature excess T = ambient temperature a (~N) T* = local temperature~~
\/ U = ambient velocity W = strength of image source b = subsurface jet characteristic width c = concentration or field strength function d = depth of receiving water f = buoyancy force g = gravitational acceleration r = coordinate normal to subsurface jet path s = coordinate along the subsurface jet path t = time u* = local velocity in the jet i
u(s) = plume centerline velocity x = horizontal coordinate parallel to initial direction of discharge y = horizontal coordinate normal to initial direction of discharge y = distance of discharge point from shoreline s l AS.1-9
~~/~ z = vertical coordinate V) i zs = depth of discharge point below water surface ar = entrainment coefficient for round jet~~
6T = temperature difference 6T c = centerline temperature difference 6 = angle of jet trajectory in a subsurface jet with respect to horizont.al plane i go = initial angle of subsurface jet discharge with respect to horizontal plane
~~! hr~~
~~= spreading ratio for round jet j 9 = density pg = ambient reference density pa = ambient density P* = local density~~
< X = non-decaying cc,ncentration O . l l l A5.1-10
() REFERENCES FOR APPENDIX AS.1
1. R. C. Koh and L. N. Fan, Mathematical Models for the Predic-tion of Temperature Distributions Resulting from the Discharge of Heated Water into Large Bodies of Water, Water Pollution Research Series, Program #16130 DWO, Water Quality Office, Environmental Protection Agency, October 1970.

2. U.S. Nuclear Regulatory Commission, Estimating Aquatic Dispersion of Effluents from Accidental and Routine Reactor
~~! Releases for the Purpose of Implementing Appendix I, Regulatory Guide 1.113, Revision 1, April 1977.~~
~~3. E. L. Thackston and F. L. Parker, Effect of Geographical Location and Cooling Pond Requirements and Performance, Water Pollution Control Research Series, #16130, FDQ, 1971.~~
O c:) l AS.1-ll
() 5.2 RADIOLOGICAL IMPACT FROM ROUTINE OPERATION This section presents the results of the dose evaluation for PNPP Units 1 and 2. Compliance with Appendix I to 10 CFR Part 50 III and 40 CFR Part 190 (2) are also demonstrated in this section. 5.2.1 EXPOSURE PATHWAYS The exposure pathways considered in the evaluation of the dose to man and other biota due to operation of PNPP Units 1 and 2 include direct radiation from radioactivity contained within the station; shoreline fishing; immersion in airborne effluents; and radionuclides deposited on the ground surface and vegetation; as well as internal exposure due to inhalation of airborne effluents and from ingestion of milk, drinking water, fish, and vegetation. Figure 5.2-1 illustrates the ( ) various exposure pathways for biota other than man. Figure 5.2-2 illustrates the various exposure pathways for man. 5.2.2 RADIOACTIVITY IN THE ENVIRONMENT The analysis of impacts due to gaseous emissions and liquid effluents from the PNPP was performed using the models, assump-tions, and parameters described in NRC Regulatory Guide 1.109, Revision 1.I I The GASPAR and LADTAP computer codes were used to evaluate the doses from gaseous emissions and liquid effluents, respectively. Both of these computer codes are based on Regula-tory Guide 1.109, Revision 1. The sources of information used as input for these computer codes are as follows: o Nearest site boundary locations: Section 2.1.3, Table (-) 2.1-4. 1 5.2-1
o Location of nearest residence, milk cow, meat animal, {} and vegetable garden: Section 2.1.3, Table 2.1-3. i o Location of all milk cows within 5 miles of the PNPP: Section 2.1.3, Table 2.3-5. o Location of shoreline recreation areas: Section 2.1.3, Table 2.1-7. o Location of drinking water intakes: Section 2.1.3, Table 2.1-10. o Milk, meat, and vegetable production data for the area within 50 miles of the PNPP: Section 2.1.3, Table 2.1-6. o Population distribution within 50 miles of the PNPP: Section 2.1.2, Figure 2.1-15 (data and description of the c' -ion methods). o Total sports fish catch from all points along the lakeshore within 50 miles of the PNPP: Approximately 48,500 kg/yr; See paragraph 2.1.3.5.2 for details, o Total commercial fish catch from portion of Lake Erie which is within 50 miles of the PNPP: Approximately 8,720,000 kg/yr; See paragraph 2.1.3.5.1 for details, o Meteorological data ( X/Q and D/Q values): Section 2.3.3 and Tables 2.3-19 through 2.3-25. o Hydrologic dilution factors: Section 5.1 and Tables 5.1-6 through 5.1-10. o Source terms: Section 3.5, Table 3.5-4 for the estimated annual release of radionuclides in liquid effluents [-} l l l l 5.2-2 ) l
and Tables 3.5-2 and 3.5-3 for estimated gaseous emissions (') V from Units 1 and 2, respectively. (Section 3.5 also describes how these releases were estimated.) 4 o Maximum and per capita data on water, milk, meat, vegetable, and fish consumption; shoreline recreation use (including boating and swimming); breathing rates and dose-conversion factors for ingestion and inhalation: NRC Regulatory Guide 1.109, Revision 1.(3) 5.2.3 DOSE RATE ESTIMATES FOR BIOTA OTHER THAN MAN This section evaluates the impacts on biota other than man attributable to the estimated normal release of radioactivity from PNPP Units 1 and 2. Both terrestrial and aquatic biota are considered in the assessraent. 5.2.3.1 Radiation Exposure of Terrestrial Biota
%/
The analysis of radiological impact cehaidered the var:,ous pathways through which these organisms could be exposed to radiation. Radiation doses received by terrestrial biota from ext ernal exposure (cloud immersion and contaminated land surfaces) are expected to be similar to those received by man. While the doses within the site boundaries would be somewha;; higher than those received off the site, they would be withia the same order of magnitude and are considered to be quit e small. Similarly, based on experience at other nuclear power plants and calculations performed for the PNPP, internal doses received by man from gaseous and particulate releases are expected to be small. The same is expected to hold true for doses received by other terrestrial organisms. ! ( 5.2-3 l
There is a direct correlation between the biological complexity of an organism and its sensitivity to radiation.I4) Because [} the doses received by man, a very complex organism, are not expected to pose any hazard, the operation of the PNPP Units 3 1 and 2 will not result in any radiological hazard to the terrestrial fauna inhabiting the PNPP site and its vicinity. The amount of radiation that could be delivered to plants by efflue'nt releases from PNPP Units 1 and 2 is estimated to be significantly less than that requiring any concern. The effects of radiation on plants can range from a slight inhibition of growth to death, depending on the dose rate and the total dose received. A flora sensitivity range is given in Table 5.2-1; the information was obtained from Woodwell and Sparrow. (5) A number of the vegetation types listed in the table are found at the PNPP. The table shows that the amount of radiation required for even slight growth inhibition in plants is extremely high and well in excess of the radiation expected to be released from PNPP Units 1 and 2. [} 5.2.3.2 Radiation Exposure of the Aquatic Biosystem The radiological impact of PNPP liquid effluents on the various aquatic lifeforms inhabiting Lake Erie was evaluated by means of the Nuclear Regulatory Commission's (NRC) LADTAP computer program. The models and assumptions used in LADTAP are based on NRC Regulatory Guide 1.109, Revision 1.I I The annual internal and external radiation dose received by a fish living in Lake Erie in the vicinity of the PNPP is estimated to be 0.3 millirad. A duck living continuously in these waters might receive an annual dose of 1.6 millirads. These estimates
~~of the doses delivered by effluents from PNPP Units 1 and 2 are based on the Scarce terms presented in Section 3.5, Table 3.5-4 of this report, and the dilution factors presented~~
, in Section 5.1. ( I t 1 5.2-4 l
Any evaluation of radiological impacts must take into account the relative radiosensitivity of aquatic organisms. As already (3 mentionea, the radiosensitivity of a species is related to its biological complexity. Thus, invertebrates are more resis-tant to radiation than vertebrates, and among the vertebrates, mammals are more sensitive than birds, fish, amphibians, or reptiles.(4) Consequently, the radiological impact incurred by aquatic biota from exposure to radiation from the liquid effluents discharged by PNPP Units 1 and 2 will be less than those incurred by man for the same exposure. Eggs and larvae in their early developmental stages are the most radiosensitive and, therefore, constitute the most critical group in the aquatic population.(6) Many studies have been made to determine the effect on fish eggs and larvae chronically irradiated by immersion in low-level radionuclide solutions. An investigation by Polikarpov I) found that the death rate of freshwater fish eggs was not increased even when the eggs (~'} were immersed in a strontium-90 solution with a radioactivity
'- concentration of 10-6 microcurie per cubic centimeter, which is more than 100 times higher than the total estimated concen-tration in the nontritium annual average discharges from PNPP Units 1 and 2. Thus, it can be expected that any radiological effects on aquatic biosystems will be negligible.
5.2.4 DOSE RATE ESTIMATES FOR MAN The calculation of maximum individual and population doses were based on NRC regulatory guides current as of September 1979 and compared with the design objectives of Appendix I to 10 CFR 50 (1) and 40 CFR 190. (2) Figure 5.2-2 shows the pathways that were considered and analyzed. The calculated maximum individual dose was found to be well within the limits specified in 40 CFR 190. m J ! 5.2-5
t t 5.2.4.1 Liquid Pathways O The maximum dose received by an individual and the total dose
~~received by the general population were computed by using i~~
the data and methods described in the preceding section. i Since the PNPP will periodically discharge liquid radioactive wastes into Lake Erie, it is necessary to consider the dose contribution from water consumption, fish ingestion, shoreline recreational activities, swimming, and boating. Figure 5.2-2 j shows the various exposure pathways resulting from the dic-charge of liquid radioactive effluents. l The individual receiving the maximum dose from liquid radioac-j tive effluents is assumed to reside in one of the houses located l in the northeastern sector, approximately 0.5 mile from the l PNPP; the house is assumed to be located within 100 to 200 yards of the Lake Erie shore. This person is assumed to take l i all potable water directly from Lake Erie at this location. It is also assumed that this location is the site of all boating, l() swimming, fishing, and shoreline recreation activities in ! which this person participates. Annual average dilution factors are used to compute the dose contribution from drinking water j and fish consumption. A summer average dilution factor is f< used to compute the dose contribution from shoreline activities like swimming and boating. The estimated doses are given in Table 5.2-2, which shows that the radiation dose resulting from PNPP liquid radioactive effluents is much lower than the Appendix I design objectives. 7 l i The total integrated population dose from liquid radioactive effluents was also calculated. The results are presented in Table 5.2-3 and are based on the number of people projected to live within 50 miles of the_PNPP site in the year 2000. l 5.2-6
5.2.4.2- Airborne Pathways O To evaluate the impact of radioactive airborne emissions, estimates were made of both the maximum dose received by an individual and the integrated population dose received by people living within 50 miles of the PNPP site. The calculated doses included immersion in the plume, ground contamination, inhalation, and the consumption of vegetables, meat, and milk. The location of the person who would receive the maximum dose depends on how he is exposed to the airborne emissions. Tables 2.1-3 through 2.1-5 of Section 2.1 list the detailed location, by direction and distance from the site boundary, of the nearest residence, milk animal, meat animal, and vegetable garden. The maximum estimated dose from plume immersion occurs at the residence located in the northeastern sector, 0.6 mile 1 from the plant. The dose at this location is estimated at 3.55 millirem per year to the whole body and 6.87 millirem () per year to the skin. This is less than the 10 CFR Part 50, Appendix I design objectives of 5 millirem per year to the l whole body and 15 millirem per year to the skin from all reac-tors located at the site. The maximum dose received by an individual from lodine and particulate radionuclides occurs at the residence located in the southern sector, 0.79 mile from the PNPP. The estimated , doses are given in Table 5.2-4. It is assumed that there is a vegetable garden at this location, but no milk or meat animals. The estimated doses are substantially lower than j the 10 CFR Part 50, Appendix I design objectives. The maximum air dose at any site boundary location occurs in the northeast sector, approximately one-half mile from the PNPP. The gamma and beta air doses are estimated to be 8.21 and 5.68 millirads per year, respectively, for two-unit operation. These. values are lower than the 10 CFR Part 50, (]} 5.2-7
Appendix I design objectives of 10 and 20 millirads per year on a per site basis for the gamma and beta air doses, respec-
~~} tively.~~
The calculated population doses (see Table 5.2-5) are based on the number of people projected to live within 50 miles of the PNPP site in the year 2000. The sources of data used to compute these doses are listed in Section 5.2.2. Both grazing season and annual average X/Q and D/Q values are used in the analysis. The grazing and growing seasons are assumed
~~.to last f rom May 15 to November 1 (see Section 2.1.3.4.2) .~~
5.2.4.3 Direct Radiation From Facility The dose due to direct radiation emitted from PNPP Units 1 and 2 to an individual located at the site boundary location and residence closest to the plant buildings is considered in this section. The nearest site boundary and residence location are used since the dose rate increases as the distance (} between the location of interest and the plant buildings is decreased. Dose contributions from skyshine and direct dose from the turbines, direct dose from stored radwaste, and direct dose from the external surfaces of buildings are considered. The dose results in this section are based on an application of the data and results presented in Section 12.3 and 12.4
~
of the FSAR for PNPP Units 1 and 2. Refer to these sections for a detailed description of the computational methodology. The site boundary location which is closest to the plant build-ings is found in the northeast sector, at a distance of 678 meters (2224 feet) from Unit 1 and 800 meters (2624 feet) from Unit 2, as shown on Table 2.1-4. (Note that the north, north-northeast, west, west-northwest, northwest, and north-northwest site boundary locations are over water.) Based on Figure 12.3-13 of the FSAR, the dose at this location is estimated at 1.2 x 10 -3 mrem /hr or 10.5 mrem /yr from Unit (} 5.2 8
1 and 4.0 x 10-4 mrem /hr or 3.5 mrem /yr from Unit 2. The {} total dose from both units is estimated at 14.0 mrem /yr. The location of the residence closest to the plant buildings is found in the northeast sector at a distance of 1009 meters (3310 feet) from Unit 1 and 961 meters (3152 feet) from Unit 2, as shown on Table 2.1-3. Based on Figure 12.3-13 of the FSAR, the dose rate due to both units at this location is 2.0 x 10 -4 mrem /hr or 1.75 mrem /yr. No dose rates are computed for hospitals, schools, and other public facilities since none of these facilities are located within one mile of the PNPP units. Based on the information presented in paragraphs 12.4.4.2 and 12.4.4.3 of the FSAR, the dose contribution to the afore-mentioned locations due to stored radwaste and external building surfaces is negligible. (\ J 5.2.4.4 Annual Population Doses Annual population doses were estimated; they are presented in Tables 5.2-3 and 5.2-5 for liquid and gaseous pathways, respectively.
\
5.2.5 COMPLIANCE WITH 40 CFR 190 Compliance with 40 CFR 190 is demonstrated if the total dose due to liquid and gaseous effluents, as well as direct radia-tion, does not exceed 25 mrem to the whole body or any organ except the thyroid and 75 mrem to the thyroid. Two locations are considered for demonstrating compliance with 40 CFR 190. The maximum dose to the thyroid occurs in the south sector, 0.79 mile from the plant, while the maximimum dose to the whole body and the bone occurs in the northeast sector, 0.63 (~)
~~\_/~~
~~mile from the plant. 5.2-9 ; 1 l~~
\
(.~. i ! i ! l ! r i l The dose results are tabulated on Table 5.2-6. These results ! i g show that PNPP Units 1 and 2 comply with 40 CFR 190. . i i 4 4 I ! r 9 ! I i i i i 5 I l ; , i k i ! i i I I i i h 5.2-10
~~._...._--,,-,.-,.._n--._.,,._._.,. .,,-...,nn,,,,n,- ._,.n, ,.,_n_.,m,__,,e,,,,n.w,,n_,m,.~,~~
~~REFERENCES FOR SECTION 5.2 {~~~
1. " Numerical Guides for Design Objectives and Limiting Condi-tions for Operation to Meet the Criteria 'As Low as Practic-able' for Radioactive Material in Light Water Cooled Nuclear Power Reactor Effluents," Appendix I to 10 CFR 50, 1975.

2. " Environmental Radiation Protection Standards for Nuclear Power Operations," 40 CFR 190, 1977.

3. U.S. Nuclear Regulatory Commission, Calculation of Annual Doses to Man From Routine Releases of Reactor Effluents for the Purpose of Evaluating Compliance with 10 CFR 50, Appendix I, Regulatory Guide 1.109, Revision 1, October 1977.

4. The Effects on Population of Exposure to Low Levels of
~~( Ionizing Radiation, Report of the Advisory Committee on the Biological Effects of Ionizing Radiation, National Academy of Sciences-National Research Council, November 1972.~~
5. G. M. Woodwell and A. H. Sparrow, " Effects of Ionizing Radiation on Ecological Systems," in Ecological Effects of Nuclear War (G. M. Woodwell, ed.), USAEC Report BNL-917 (c-43), 1965, pp. 20-38; reprinted in Ecological Aspects of the Nuclear Age: Selected Readings in Radiation Ecology, USAEC report TID-25978, 1972, pp. 271-289.

6. L. R. Donaldton and R. F. Foster, " Effects of Radiation on Aquatic Organisms," in The Effects of Atomic Radiation on Oceanography and Fisheries, NRC Publication 551, National Academy of Sciences, 1957.
)
5.2-11
i , i i i l'
~~i i , )~~
i
~~7. G. G. Polikarpov, Radioecology of Aquatic Organisms, Reinhold, t g New York; 1966.~~
1 I b I ! I I l i i !
\
i i s i l 1 l i i i i i, . i l t i [ i l i 1 0 , I f 5.2-12 1
.--__,_.__-..,,~~n_,..,-,,,.,_ - _____,,.--,,_w., ._w.,,,
~~TABLE 5.2-1 ESTIMATED ACUTE EXPOSURES REQUIRED TO AFFECT DOMINANTS OF MAJOR NORTH AMERICAN VEGETATIONa,b~~
, Interphase Sensitivity Range (rads) i Chromosome Slight 100 vblume Inhibition of Percent Species (mean i S.E.) Growth Mortality FORESTS Boreal White spruce (Picea glauca) 39.7 i 1.6 220 590 Balsam fir (Abies balsamea) 33.4 1 2.2 270 700 Subalpine (Rocky Mountains)
Engelman spruce (Picea engelmannii) 26.8 i 1.6 330 880 Alpine fir (Abies lasciocarpa) 33.5 1 1.7 270 700 Montane (Rocky Mountains) Douglas fir (Pseudotsuga menziesii) 28.5 1 1.1 310 820 Ponderosa pine (Pinus ponderosa) 36.7 1 2.8 240 640 Montane (Sierra-Cascades) 1 White fir (Abies concolor) 23.3 1 0.9 380 1,010
Sugar pine (Pinus lambertiana) 57.8 1 3.1 150 410 Jeffrey pine (P. jeff reyi) 48.1 + 1.9 190 490 Ponderosa pine (P. ponderosa) 36.7 + 2.8 240 640 Douglas fir (Pseudotsuga menziesii) 28.5 1 1.1 310 a20 Pacific conifer Western hemlock (Tsuga heterophylla) 23.7 1 0.9 377 990 Giant cedar (Thuja plicata) 8.6 1 0.4 1040 2,730 Grand fir (Abies grandis) 33.2 i 1.1 270 710 Eastern deciduous 1
Mixed mesophytic , American beech (Pagus grandifolia) 2.3 1 0.1 3810 10,000 1 Cucumber tree (Magnolia acuminata) 4.8 1 0.2 1850 4,840 i Basswood (Tilia americana) 2.5 1 0.1 3520 9,230 Tuliptree (Liriodendron tulipifera) 6.4 1 0.5 1400 3,680 Sugar maple (Acer saccharum) 3.2 1 0.2 2800 7,360 White oak (Quercus alba) 6.6 1 0.3 1350 3,550 Eastern hemlock (Tsuga canadensis) 21.3 1 0.8 420 1,100 i Beech-maple and maple-basswood American beech (Pagus grandifolia) 2.3 1 0.1 3810 10,000 Sugar maple (Acer saccharum) 3.2 1 0.2 2800 7,360 Basswood (Tilia americana) 2.5 1 0.1 3520 9,230 O' 5.2-13
TABLE 5.2-1 (Continued) ESTIMATED ACUTE EXPOSURES REQUIRED '10 AFFECT DOMINANTS OF MAJOR NORTH AMERICAN VEGETATIONa,b Interphase Sensitivity Range (rads) Chromosome Slight 100 Volume Inhibition of Percent Species (mean j; S.E.) Growth Mortality Eastern deciduous (continued) Hemlock-hardwood Eastern hemlock (Tsuga canadensis) 21.3 j; 0.8 420 1,100 Yellow birch (Betula lutea) 2.2 j; 0.1 3860 10,120 White pine (Pinus strobus) 46.5 j; 2.8 190 500 Red pine (P. resinosa) 43.2 j; 3.5 210 540 Sugar maple (Acer saccharum) 3.2 j; 0.2 2800 7,360 Oak-chestnut American chestnut (Castanea dentata) 4.7 j; 0.3 1900 5,000 Scarlet oak (Quercus coccinea) 3.6 f; 0.3 2400 6,530 Chestnut oak (p. prinus) 6.1 f; 0.3 1470 3,870 Pitch pine (Pinus rigida) 48.3 j; 2.6 190 490 Oak-hickory _ White oak (Quercus alba) 6.6 j; 0.3 1350 3,550 Red oak (q. rubra) 5.5 j;0.3 1620 4,250 Black oak (q. velutina) 3.2 j; 0.2 2830 7,430 Post oak (Q. stellata) 4.4 j; 0.2 2040 5,350 Blackjack oak (Q. marilandica) 3.3 + 0.2 2690 7,060 Shagbark hickory (Carya ovata) 2.5 + 0.2 3560 9,340 Bitternut hickory (C. cordiformis) 1.8 + 0.1 5090 13,370 Mockernut hickory (c. tomentosa) 1.8 + 0.5 5080 13,350 Big shellbark (C. laciniosa) 2.6 + 0.1 3470 9,110 Loblolly pine (Pinus tuedo) 52.6 j; 4.1 170 450 GRASSLANDS Little blue stem (Andropogon scoparius) 6.4 j; 0.4 2330 9,200 AGRICULTURE t HV Golden bantam corn (Zea mays 14.0 j; 0.6 1060 4,200 tetraploid) 10.8 j; 0.6 1370 5,410
~~Wheut (Triticum aestivum) 14.6 j; 1.1 1020 4,020 (a) Prom Woodwell and Sparrow.(5)~~
(b) Estimates are based on correlations between radiosensitivity and interphase chromosome volume. Radiosensitivity is directly proportional to the inter-phase chromosome volume: a larger volume presents a larger target area. 5.2-14
_ . _ _ _ _ _ . . . _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ . _ _ _ _ _ __ __mm.,_. .. _ ._ ._____._m.._ . _ _ _ _ _ _ . _ . . - _ . . _
~~O O O 1~~
TABLE 5.2-2 MAXIMUM DOSE TO AN INDIVIDUAL DUC TO THE RELEASE OF LIQUID RADIOACTIVE EFFLUENTS FROM BOTH UNITS OF PNPP (MREM /YR) Adult Teen Child Infant Total Tota l Tota l Tota l Pathway Body Thyroid Bone Body Thyroid Bone Body Thyroid Bone Body Thyroid Bone Fish ingestion 1.18-2 4.08-2 4.56-2 7.55-3 3.81-2 4.94-2 4.46-3 3.93-2 6.32-2 0.00 0.00 0.00 Drinking 2.39-3 1.01-1 4.29-4 1.69-3 8.58-2 4.13-4 3.20-3 2.05-1 1.19-3 3.19-3 3.20-1 1.43-3 Shore line 1.52-5 1.52-5 1.52-5 8.47-5 8.47-5 8.47-5 1.77-5 1.77-5 1.77-5 0.0 0.0 0.0 Total 1.42-2 1.41-1 4.60-2 9.33-3 1.24-1 4.99-2 7.68-3 2.44-1 6.44-2 3.19-3 3.20-1 1.43-3 Notes: 1. This table presents the dose values for the total body and ror those organs which receive the highest dose.
2. The Appendix I design objectives are 5 mrem /yr to the total body or to any orgart from all reactors located at a site.

3. The number 1.18 - 2 = 1.18 x 10-2, Y
~
Ut I i 9 i I i I e 4 1
o o . o TABLE 5.2-3 FIFTY-MILE POPULATION DOSE DUE TO 'IHE RELEASE OF LIQUID RADIOACTIVE EFFLUENTS FROM BO'IH UNITS OF 'IHE PNPP (MANREM/YR) Adult Teen Child Total Total 'Ibtal Pathway Body Thyroid Bone Body Thyroid Bone Body Thyroid Bone Sportsfish ingestion 8.87-3 1.92-2 2.84-2 8.46-4 2.76-3 4.72-3 7.48-4 4.56-3 9.69-3 Comercial fish ingestion 3.59-1 6.12-1 1.05+0 3.40-2 8.76-2 1.74-1 2.90-2 1.45-1 3.56-1 Drinking water 2.52-1 6.42+0 3.64-2 2.76-2 8.52-1 5.42-3 8.48-2 3.32+0 2.54-2 Shoreline recreation 7.42-3 7.42-3 - 6.52-3 6.52-3 - 2.16-3 2.16-3 -- a Y H
~~Swiming 3.35-4 3.35-4 --~~
2.94-4 2.94-4 - 9.73-5 9.73-5 - u Boating 1.67-4 1.67-4 -- 1.47-4 1.47-4 - 4.86-5 4.86-5 -- Note: 1. The number 8.87-3 = 8.87 x 10-3 I l 2 4
o o o TABLE 5.2-4 MAXIMIM DOSE RECEIVED BY AN INDIVIDUAL FROM 'IHE RELEASE OF IODINE AND PARTICUIATES FROM BO'IH UNITS OF 'IHE PNPP Maximum Dosel (mrem /yr) Adult Teen Child Whole Whole Whole Pathway Body Thyroid Bone Body Thyroid Bone Body 'Itlyroid Bone Ground plane 7.86-2 7.86-2 7.86-2 7.86-2 7.86-2 7.86-2 7.86-2 7.86-2 7.86-2 Inhalation 1.20-2 8.35-1 3.12-3 1.26-2 1.06+0 4.29-3 1.16-2 1.27+0 5.68-3 ui-
'p Garden 3.79-1 6.98+0 1.79+0 5.87-1 6.07+0 2.87+0 1.37+0 9.73+0 6.89+0 v " 7.21+0 2.95+0 1.46+0 1.11+1 6.98+0 Total 4.70-1 7.90+0 1.87+0 6.78-1 Notes: 1. The Appendix I design objective for the pathways listed here is 15 mrem /yr to any organ for all reactors located at a site.
~~2. The number 7.86-2 = 7.86 x 10-2,~~
.I l i t i
TABLE 5.2-5 , INTEGRATED DOSE RECEIVED BY THE POPULATION WITHIN 50 MILES OF THE PNPP FROM GASEOUS EMISSIONS Population Dose (man-rem /yr for both units) Pathway Whole Body Thyroid Bone
Plume 1.09+1 1.09+1 1.09+1 Ground 1.34-1 1.34-1 1.34-1 Inhalation 6.49-2 4.44+0 1.68-2 Ingestion Vegetable 3.57-1 7.70+0 1.74+0 Milk 2.58-1 6.60+0 1.22+0 Meat 2.48-2 5.71-2 1.22-1 e Total 1.17+1 2.98+1 1.41+1 Note

1. The number 1.09+1 = 1.09 x 101 5.2-18
I i l TABLE 5.2-6 DOSE RESULTS SHOWING COMPLIANCE WITH 40 CFR 190 Dose (mrem /yr) Dose (mrem /yr) Tctal Dose Unit 1 Unit 2 for Both Total Including Category Plume Particulate Plume Particulate Units Direct Radiation mrem /yr mrem /yr FOR IOCATIONS IN 'IHE NE SEC'IOR, 0.63 MILES FROM PNPP UNITS 1 AND 2 l Whole body 1.70 0.77 1.85 0.82 5.14 6.89 Bone 1.70 3.59 1.85 3.91 11.05 12.80 Thyroid 1.70 4.44 1.85 4.62 12.61 14.36 skin 3.30 0.76 3.57 0.81 8.44 10.19 FOR LOCATIONS IN THE S SECTOR, 0.79 MILES FROM PNPP UNITS 1 AND 2 Whole body 1.35 0.73 1.40 0.74 4.22 5.10 Bone 1.35 3.44 1.40 3.54 9.73 10.61 Thyroid 1.35 5.46 1.40 5.62 13.83 14.71 Skin 2.62 0.71 2.70 0.72 6.75 7.63 Notes:
~~1. The direct radiation dose in the NE sector, 0.63 miles from the plant is 1.75 mrem /yr for both units. The direct radiation dose in the S j~~
~~'T sector, 0.79 miles from the plant is 0.88 mrem /yr for both units. ,,,/ See section 12.3 and Figure 12.3-13 for discussion on direct radia-tion calculations and results.~~
~~2. The contribution to the total dose due to the release of liquid radio-active effluents is negligible (see Table 5.2-2) .~~
i 5.2-19
O
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~~GASEOUS EFFl.UENT~~
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gngestion ' A e Immersion- - Sediments GENER ALIZED EXPOSURE PATHWAYS FOR ORG ANISMS OTHER THAN MAN PERRY HUCLEAR POWER PLANT 1 & 2 THE CLEVELAND ELECTRIC ILLUMIN ATING COMPANY FIGURE 5.2-1 5.2-20 t
O
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Ingestion GENERAllZED EXPOSURE PATHWAYS FOR MAN PERRY NUCLEAR POWER PLANT 1 & 2 THE CLEVELAND ELECTRIC lLLUMIN ATING COMPANY FIGURE 5.2-2 5.2-21
( (} 5.3 EFFECTS OF CHEMICAL AND BIOCIDAL DISCHARGES This section has been revised to reflect cooling-system design < > changes and changes in regulatory requirements. j i ! 5.3.1 SYSTEM DISCHARGES I 5.3.1.1 Direct System Discharges to Cooling Water i ] The wastewater produced in the regeneration of the cycle-makeup demineralizer and the biocidal chemicals used for plant auxiliary i cooling equipment will be treated and discharged directly r to the cooling-water discharge. These systems are described l in Sections 3.6.1 and 3.6.2, respectively. Tables 3.6-2 and 3.6-5 give the expected discharge concentrations of impurities, the nominal values and ranges of lake-water concentrations, ' and State regulatory limits, where applicable, for these systems.
~~o 5.3.1.2 Discharges to Cooling Water via Chemical Waste Lagoon l~~
Before initial startup, chemical cleaning waste water will l l be collected in a lagoon, treated to remove phosphates by 1 precipitation, and. allowed to settle to remove solids before it is discharged to the cooling water. This system is described I in Section 3.6.1.2. The expected discharge impurity concentra-tions of lagoen decant water and cooling water containing decant water, nominal values and ranges of lake-water concentra-
~
tions, and State regulatory requirements, where applicable, are given in Table-3.6-3. 5.3.1.3 Seasonal Effects There will be only very slight seasonal variations in water l quality in the discharge area. () 5.3-1
5.3.1.3.1 Dissolved Oxygen O The lake water at the intake of the plant is essentially satu-rated with dissolved oxygen. As the water passes through the turbine condenser, its temperature will increase by about 32 F. The water then passes through the cooling towers. After passing through the cooling tower, the major part of the cooling water is recirculated. The remainder is discharged as cooling tower blowdown with the surface water. Since oxygen is less soluble at higher temperatures, some decrease in the oxygen content of the cooling water will occur if equilibrium is attained. The following table shows typical values of how this change will occur in both summer (high temperatures) and winter (low temperatures): Inlet Cooling Lake Water Dissolved Oxygen (ppm) Water Temp. Discharge Temp. Lake Cooling O Season F F Water (equilibrium) (~S Winter 38 57.5 9.7 7.2 O Summer 74 87.6 6.7 5.7 Even though this decrease may occur as 6 -ncibed, it has been frequently noted that the oxygen content st the receiving water will not in fact decrease significantly. This is because the exiting water mixes quickly with the water in the receiving body, thereby rapidly decreasing in temperature and picking up oxygen from the diluting water and from the atmosphere. 5.3.1.3.2 Biochemical Oxygen Demand The biochemical oxygen demand (BOD) in th= lake water in the discharge area will be slightly increased by the two effluent sources: the discharge from the sewage treatment plant and the decaying biological organisms which are killed by biocidal chemicals and by passing through the cooling system. A () l 5.3-2
The BOD contributed by the sewage plant is given in Table 3.7-1. After plant operation begins, the volume of sewage (]} and BOD should be relatively constant, and the effect of seasonal changes will be minimal. The total BOD discharged will be only about 1.5 pounds per day. The BOD contributed by decomposing biological organisms is also insignificant. It has been calculated that the reduction of dissolved oxygen (or BOD before decomposition begins) resulting from the decomposition of organisms killed by biocidal chemicals and by passing through the condenser and heat exchangers will be on the order of 0.2 parts per million. This calculation was based on the following assumptions:
~~a. All of the organism is biodegradable. This assumption is very conservative since many of the organisms contain siliceous materials that do not decay.~~
()
b. None of the organisms are consumed by other life forms. This assumption is also conservative. It is expected that a large percentage of the organisms will be consumed rather than left to decay.

c. All of the organism decays. Actually, BOD measurements are based only on that material that decays in 5 days.
During the winter months, when the temperatures are lower, there will probably be some accumulation of BOD in the discharge area. However, the total oxygen decead is so low that this accumulation should not be significant. As the temperature increases, any slight buildup will disappear.
~~/~)~~
~~V 5.3-3~~
~~-w w e e r- ---e -e-~~
~~i i l 5.3.1.3.3 Dissolved Solids and Suspendtd Solids~~
!O The quantities of dissolved and suspended solids that will be discharged are given in Section 3.6. There should be no seasonal variation in these discharges since they are dependent 5 exclusively on plant operation.
i l l 5.3.2 BIOLOGICAL EFFECTS OF CHEMICAL AND BIOCIDAL DISCHARGE i l The chemical discharges from cycle-makeup demineralizer regenera- ' ] tion and the chemical waste system (see Tables 3.6-2, 3.6-3,
] and 3.6-5) are anticipated to have no effect on the aquatic ] life inhabiting Lake Erie in the area of the PNPP. After I ; dilution with cooling water, these wastewaters will be within i the same range of chemical composition as the ambient lake water. Since the aquatic organisms inhabiting Lake Erie at
, the site are well adapted to the existing ambient water condi- " i tions, discharges from these waste-treatment systems should ; j have no effect on them. The dechlorination system will remove f any residual chlorine before it reaches the mixing zone. The conversion of free and residual chlorine to chlorides l by the dechlorinzation process will prevent the formation
~~!. of chlorinated organics.~~
~~i There will be no buildup of chemicals in the bottom sediments~~
! of Lake Erie. Most of the chemicals discharged are soluble; i 'they will simply be diluted to a level within normal variations l of lake-water concentrations as they flow from the discharge line. Because the concentration'of chemicals coming from t
the plant is so small, the dilution will occur very quickly. The suspended matter is also very small in quantity and will l be undetectable in the outfall area. These discharges are
~~; discussed and quantified in Section 3.6.~~
i lO l 5.3-4 I
5.4 EFFECTS OF SANITARY WASTE DISCHARGES (]) i l The sanitary waste discharges are as originally estimated in the ER/CP. The sanitary-waste treatment system is described l in Section 3.7. The treated waste will be discharged directly to Lake Erie without dilution with cooling water. The quantities of dis-charge will depend on the number of people present at the site and will vary between 30,000 and 75,000 gallons per day. The composition of the discharge (see Table 3.7-1) will remain relatively constant. The effluent is typical of sewage plants employing secondary treatment; and even though contributing some nutrient to the water, it will, because of the small quantities involved, have a negligible effect on aquatic life, even in the immediate area of the discharge. O O 5.4-1 i
s C 5.5 EFFECTS OF OPERATION AND MAINTENANCE OF THE TRANSMISSION SYSTEM The operation and maintenance methods for the transmission system are unchanged from those described in the ER/CP. The estimated effects of operation and maintenance of the trans-mission system are also unchanged. O i l O 5.5-1
OTHER EFFECTS
~~. (]} 5.6 l This section describes the impacts of operation noise and other effects.~~
~~5.6.1 SOURCES OF NOISE DURING OPERATION ~~~
; The principal sources of operation noise at the PNPP will be the natural draft cooling towers, the steam turbines, and generators; the transformers; electrical equipment in the switchyard; the heating, ventilating, and air-conditioning (HVAC) system; and the circulating and service-water pumps.
I The sound-level spectrum for each type of equipment other than the cooling towers is based on reference design informa-tion and a detailed analysis of operation noise sources for the PNPP.(1,2) The sound-power-level spectrum for each cooling tower is based on information contained in the literature. () The characteristics of these noise sources are described below. 5.6.1.1 Natural Draft Cooling Towers The dominant sources of noise will be the natural draft cooling towers, which produce a noise resembling that of a waterfall. The noise is produced by water falling onto the tower packing and into the basin, and by the flow of air through the tower. The sound-power-level spectrum for each cooling tower was based on information available in the literature.(3) 5.6.1.2 Transformers and Switchyard 1 The noise generated by transformers is due primarily to the magnetostrictive effects in the core of the transformer. It consists of a harmonic series of component tones with a fundamental frequency equal to twice the main power frequency. Each PNPP unit will have main step-up transformers located (]) l 5.6-1 1 I
near the turbine building and shunt reactors, circuit breakers, {} and associated equipment in the switchyard. The noise from the circuit breakers and switchgear is an impact-type noise produced by the opening and closing of these devices and is highly intermittent. Transformer noise from the switchyard and main step-up trans-formers was considered in the operation noise analysis. The sound-power-level spectrum for each transformer and shunt reactor was based on that for a 750-MVA transformer, but the power-level spectrum of the transformers was scaled for the 345-MVA transformers at the PNPP.( } 5.6.1.3 Heating, Ventilating, and Air-Conditioning System The HVAC system throughout the PNPP will be a source of noise produced primarily by the supply and exhaust fans. Fan noise consists of a series of discrete tones superimposed on a broad band. The former, called the rotational component, can be (} attributed to the process of energy transfer that leads to the development of head pressure, with the dominant tone being that of the blade-passing frequency. The latter, called the vortex component, can be attributed to the formation of turbu-lent eddies that lead to losses in head pressure. Since the speed of sound is so much greater than the air speed in most fans, the noise is propagated upstream and downstream with equal facility. Half the total sound power of the fan is assumed to be radiated through both the inlet and the outlet since the transmission loss through the casing walls is small. The sound-power-level spectrum of each fan was determined (5) and was based on the type, capacity (in cubic feet per minute) , and the static pressure of each fan. In calculating the sound-power-level spectrum of the noise radiated from the intake
~~/~T V~~
~~i 5.6-2 L~~
~~. . . = _~~
4 and outlet louvers, the duct and end losses were assumed to be 15 dBA in each octave band. [} 5.6.1.4 Steam Turbines and Generator Most steam turbine-generator noise is created by friction, impact, turbulence, unbalanced rotating par,ts, pressure drops, mass flow, magnetic attraction, or other motions related to changes in the velocity of moving parts. Flow-related sources account for most of the middle- to high-frequency noise emitted by a turbine-generator. Low-frequency noise is created by rotor imbalance and fluctuating electromagnetic forces.(6) The sound power-level-spectrum of the steam turbines and gene-rator for each unit was determined I7) and was based on the steam flow rate. 5.6.1.5 Motors and Pumps A large number of motors and pumps are located throughout (} the plant, but, because of the attenuation of the concrete structure around them, their contribution to the overall station noise is small. They were, however, taken into account. Because of their large number, the motors and pumps in the main structure of each unit were considered collectively instead of individually. The motors and pumps in the service-water-pumphouse and circulating-water pumps associated with the natural draft cooling towers were considered individually. The noise generated by electric motors is caused by air turbu-lence induced by cooling fan blades, bearings, unbalanced shafts, and magnetostrictive effects. The sound-power-level spectrum of tl) electric motors was determined I7) and was based on the motor horsepower and speed (revolutions per minute). The noise generated by pumps is caused by mechanical forces and turbulence; it is radiated by the pump casing and associated [} 5.6-3 a . . , - - - , - .- ,. , -
piping. The sound-power-level spectrum of the pumps was based (- on the pump hydraulic horsepower and efficiency. This was
-]' taken as 86 percent, which is typical for most pumps.III 5.6.1.6 Overall Plant Noise In evaluating the contribution of each noise source, a conser-vative attenuation of 30 dB in each octave band was assumed for sources confined entirely to the interior of the main plant structures, including pumps, motors, and the steam turbine-generator.IO) The attenuation is attributed to the thick concrete walls of the structures.
No intermittent noise sources were considered in the analysis. These intermittent sources include the diesel generators, which will be operated only periodically to check their perfor-mance, and the circuit breakers in the switchyard. (~') 5.6.2 OPERATION NOISE IMPACT
~~\-s' .~~
The impact of operation noise has been evaluated by calculating the contribution of plant equipment noise to the background sound levels on a grid basis, using the methods described in Section 6.1. The sound-power-level spectrum for each source considered in the analysis, determined as described in Section 5.6.1, is presented in Table 5.6-1. Predicted sound levels for the operation of the PNPP are presented in Figure 5.6-1. The predicted sound levels represent approximately the L eq sound levels for both day and night (see Section 6.1. 3. 3.1) . Actual sound levels will vary with the operating load, the operation of auxiliary equipment, and the use of equipment producing intermittent noise. Predicted Ldn sound levels at the site boundary and the nearest residence are 56 and 55 dBA, respectively; the former er.ceeds /~% the EPA guideline of 55 dBA. However, the actual sound levels L.) 5.6-4
are expected to be slightly lower than the predicted levels rx since no attenuation of noise by vegetation or ground effects is considered in the model (see Section 6.1.3.3) . The grove of trees between the PNPP and the nearest residences to the northeast can be expected to attenuate some of the noise.I9'10) The actual sound levels at the northeastern site boundary are expected to be below the 55-dBA level. Since the background L 50 sound levels measured in the vicinity of the northeast boundary were approximately 45 dBA (see Section 2.7), the increase in the L sound levels is expected to be less than 50 5 dBA at the site boundary. For an operating power plant the background operational sound levels (Leg) are constant and approximate the expected L sound levels. 50 5.6.3 OPERATION NOISE MITIGATING MEASURES The noise generated by the turbines, geaerators, motors, and pumps will be attenuated to some extent by louvers at intakes Q V and exhausts. 5.6.4 OTHER-THAN-WOISE EFFECTS Other-than-noise effects are similar to those predicted in the ER/CP. l The other waste discharges, gaseous and solid, are described in Section 3.7. The small and infrequent discharges from the diesel generators and auxiliary boilers (which will use j No. 2 fuel oil) will be permitted for operation in accordance with the State requirements. l t 5.6-5
REFERENCES FOR SECTION 5.6
}
1. Cleveland Electric Illuminating Company, Perry Nuclear Power Plant Units 1 and 2 Preliminary Safety Analysis Report, Nuclear Regulatory Commission Docket 50-440, 50-441, July 18, 1975.

2. B. Bartram and R. Andes, Noise Analysis of the Perry Nuclear Power Plant, NUS-1276, NUS Corporation, Rockville, Md., September 1974.

3. G. A. Capano and W. E. Bradley, " Noise Prediction Techniques for Siting Large Natural-Draft and Mechanical-Draft Cooling Towers," Proceedings of the American Power Conference, Vol. 39, 1976.

4. B. Berger et al. , " Transformer Noise," Philosophical Transcript of the Royal Society (London), Series A, Vol.
~~(} 262 (1968-1969).~~
5. R. Jorgensen, Fan Engineering, Buffalo Forge Company, Buffalo, N.Y., 1970.

6. R. Bannister and P. M. Niskade, " Analysis and Control of Steam Turbine-Generator Noise," Noise Control Engineering (Winter, 1974).

7. I. Heitner, "How To Estimate Plant Noise," Hydrocarbon Processing (December 1968).

8. L. L. Beranek, Noise Reduction, McGraw-Hill Book Company, New York, 1960.

9. L. L. Beranek, Noise Vibration Control, McGraw-Hill Book

Company, New York, 1971.
l (_~-} 5.6-6 L
a i J f I 1
~~10. D. Aylor, " Noise Reduction by Vegetation and Ground,"~~
~~j Journal of the Acoustical Society of America, Vol. 51, No. 1, Part 2 (1972). J .I i i 1 i i, 4 i 4 i i l N i i 4 1 J l t O 5.6-7~~
~~. . _ . . _ . . _ _ _ _ _ . _ . - _ . - _ . _ . _ . _ . _ _ . . - , _ _ _ . _ . . . . . _ . _ . . . _ _ . , . _ . , _ , _ . . . . , - _ ~ . _ - , _ .~~
O o o TABLE 5.6-1 EQUIPMENT AND-SOUND-POWER-LEVEL SPECTRA MODELED IN OPERATION-NOISE IMPACT ANALYSIS Sound-Power-Level Spectrum (dB re 10-12 watt) at Indicated Frequency (Hz) Source 63 125 250 500 1000 2000 4000 8000 Turbine-generator (a) 86 90 92 95 98 101 98 95 HVAC system 100 101 103 101 98 95 88 79 Miscellaneous pumps and f ans (a) 85 91 97 97 97 91 85 79 Control complex ventilation 94 96 98 96 93 90 83 74 Stepup transformers (a) 105 120 121 117 102 90 81 81 Switchyard equipment 79 94 95 91 76 64 -- -- Circulating-water pumps (a) 80 86 92 92 92 86 80 74 Service-water pum 69 75 81 81 81 75 69 63 Cooling towers (a)ps 109 107 101 104 106 106 106 104 P (a)For each unit. 4 Y J i (
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//, FOR THE PNPP , .. 3 - . t ~/ _, _ - , ,
p r MtbW'%DJ < Y gfgd PERRY NUCLEAR POWER PLANT 1 & 2 6 I'. f l THE CLEVELAND ELECTRIC s ILLUMINATING COMPANY FIGURE 5.6-1 i ! 5.6-9 m- ,,- v. ,,.- ,r_- - - , - ,.v.- - - - - - - - . , - -
~~.,,,-,.y ,,~~
1 a 4 5.7 RESOURCES COMMITTED 5.7.1 ENVIRONMENTAL RESOURCES 1 1 l The water required for plant operation will be drawn from J l Lake Erie. i ^ 5.7.2 MATERIAL RESOURCES i Material resources consumed over a 40-year plant life are
~~; given in Table 5.7-1.~~
1 l i I i 1 1 ( i l O 5.7-1
TABLE 5.7-1 () MATERIAL EXPENDITURES OVER THE LIFE OF THE PNPP l l Material Amount Uranium (yellowcake) (tons) 20,000 Resins (ft 3) 100,200 Precoat (Solka-Floc) (ft 3) 1,583,880 Sulfuric Acid (tons) 139,980 l Sodium Hydroxide (tons) 1,250 i Sodium Hypochlorite (tons) 4,400 Sodium Sulfite tctos) 136 I Ammonia (tons) . Hydrazine (tons) 2 Lime (tons) 1,900 Ferrous Sulfate (tons) 700 0 5.7-2
5.8 DECOMMISSIONING AND DISMANTLING The Applicant has not yet formulated plans and policies for ] the decommissioning and dismantling of the PNPP at the end of its useful life. The NRC is currently developing new policy and regulations and guidance in this area, and this information will be considered in developing a plan. However, the alternatives available for decommissioning and dismantling include the following: o Mothballing - fuel and radioactive fluids and wastes removed; monitoring and surveillance required o Entombment - all highly radioactive components sealed in a structure providing integrity until decay to unrestricted levels O o Dismantlement - radioactive material removed until unrestricted levels are achieved o Conversion - convert plant to a new nuclear- or fossil-fueled system. The NRC is conducting a Decommissioning Program which has as its goals the development of technical information to support decommissioning and the development of NRC policy and regula-tions. As a part of this program, Battelle Pacific Northwest Laboratories has performed a study on the technology, safety, and costs of decommissioning boiling water reactors. The report of the study, NUREG/CR-0672, is expected to be published during 1980, and it should add to the body of information which the NRC will rely on to develop new regulatory require-ments, which are expected in 1982. 1 O 5.8-1
Costs for decommissioning on a per unit per site basis have (g been estimated for the alternatives by the Atomic Industrial Forum (AIF) and also in a presentation by the NRC. AIF NRC* (millions (millions Alternative 1975 dollars) (1) 1978 dollars) I I i Mothballing 2.5 Entombment 7.6 Dismantlement 31.2 56 Mothballing, 31.5 71 Delayed Dismantlement Entombment, 24.8 53 Delayed Dismantlement
*Theseestimatesinclude$12millionforbuildingdemolit{gp for each alternative and a 25 percent contingency factor. /)
V Actual costs will be influenced by the regulations currently under development, as well as the means of financing them. Only the alternatives of mothballing and entombment would result in a long-term commitment of the immediate land on which the power plant structures were built (as would, of course, conversion to a new nuclear or fossil system). Dis-mantlement, mothballing, or entombment with delayed dismantle-ment could permit the returning of much of the site to unre-stricted use at the time of dismantlement. For the purpose of the cost-benefit analysis in Chapter 8, the method of mothballing with delayed dismantlement was assumed. O 5.8-2
I REFERENCES FOR SECTION 5,8
)
1. AIF/NESP-009, "An Engineering Evaluation of Nuclear Power Reactor Decommissioning Alternatives," November 1976.

2. G. D. Calkins, " Status of NRC Decommissioning Program,"
~~l AIF Conference on Environmental Regulation of the Nuclear l Industry: A New Decade, May 18-21, 1980. ]~~
~~3. Personal communication between G. D. Calkins (NRC) and R. W. Englchart (NUS), June 4, 1980.~~
~~1 i 4 l 5.8-3~~
~~.. . _ . . . , . , , -._v.._.. - , . , ,,,,._,_y.,_ _ ,, - , , . , . . , - . . - . . . , _ , - , , ,_m ,,.c,,. , _ , - . ,~~
4 5.9 THE URANIUM FUEL CYCLE 1 O The environmental effects of the uranium fuel cycle, normalized to a model 1000-MWe light-water reactor, are given in Summary Table S-3 of 10 CFR Part 51, Section 51.20. These include the effects of uranium mining and milling (except for radon), l the production of uranium hexafluoride, isotopic enrichment, fuel fabrication, the reprocessing of irradiated fuel, the transportation of radioactive materials, and the management of low- and high-level wastes. The environmental effects of the PNPP can be determined by multiplying the values given in Table S-3 by the ratio of the total electrical power output of the PNPP units to the reference 1000-MWe output. (The i effect of transp'rtation to and from the PNPP is discussed in Section 3.8). On May 16 and 17, 1978, the NRC received new evidence ( } on ("N radon releases into the licensing record for the Perkins Nuclear Station. Only July 14, 1978, the Atomic Safety and Licensing Board (ASLB) issued a Partial Initial Decision relating to the radon portion of the environmental consequences of the
~~-uranium fuel cycle. The estimates of radon-222 release (by annual fuel requirement, AFR, for a reference 1,000-MWe light water reactor) which the board accepted were:~~
~~l Activity or Source Estimate~~
(1) Mining (underground or open pit) 4,000 Ci/AFR*
l (2) Unreclaimed open pits (assuming 10,000 Ci/AFR ! 100 years to reclamation) (3) Milling 30 Ci/AFR l (4) Tailings During the life of the mill 750 Ci/AFR l During tailings drying out 350 Ci/AFR After reclamation 1 Ci/yr AFR
~~Revised to 5,200 Ci/AFR in February 1980 I4) in NRC staff testimony.~~
5.9-1
Therefore, an estimate for radon-222 releases associated with the PNPP can be made with the assumption that half the uranium {} orginates from open-pit mines which are left unclaimed, that a typical mill life is 30 years, and that there is a 30-year period of commercial operation. For the combined effect of the two 1205-MWe units, the total radon release (over a period of 100 years) related to their operation would be approximately 819,159 Ci and the long-term continuing release would be approxi-mately 72 Ci/yr from reclaimed tailings. These releases can be compared to that for the natural emission of radon-222 from the soil of the United States, estimated at approximately 100,000,000 Ci/yr.(2) The Perkins ASLB concluded II that the increase in background radon from fueling the Perkins Nuclear Station "is so small compared with background and so small in comparison with the - fluctuations in background, as to be completely undetectable. Under such a circumstance, the impact cannot be significant." O B \ 5.9-2
' REFERENCES FOR SECTION 5.9
~~1. NRC, Docket No. 50-488, -489, -490, Perkins Nuclear Station.~~
i
~~2. C. C. Trairs, A. P. Watson, L. M. McDowell-Boyer, S.-J.~~
Cotter, M. L. Randolf, and D. E. Fields, "A Radiological Assessment of F+1on-222 Released from Uranium Mills and Other Natural r f achnologically Enhanced Source," NUREG/CR-0573, Februarf i 3. Federal Register, Vol. 43, No. 73, April 14, 1978.
~~4. R. M. Wilde, Atomic Safety and Licensing Appeals Board l~~
[ Dockets 50-277, -278; 50-320; 50-354, -355; STN 50-485, l February 27, 1980. 4 o I I 5.9-3 l
J l CHAPTER 6 {} EFFLUENT AND ENVIRONMENTAL MEASUREMENTS AND MONITORING PROGRAMS This chapter describes the means by which baseline data have been collected and used and the plans and programs for monitoring the environmental impacts of station operation. ! 6.1 PREOPERATIONAL ENVIRONMENTAL PROGRAMS This section describes the environmental measurement programs associated with surface waters, groundwater, air, land, and radiation. 6.1.1 SURFACE WATERS The initial baseline studies are described in the ER/CP. Since construction began, lake-water quality has been monitored monthly at three locations referred to as transects 1, 5, sud 3 (see [} Section 2.2). When lake and/or weather conditions permitted, composite water samples were taken 1 mile off the shore and from the shore at other times. Samples were analyzed for bio-chemical oxygen demand, nitrate, phosphorus, total dissolved solids, oil, turbidity, and pH. Field measurements of dissolved 4 oxygen, pH, and temperature were also made. Bacteriological analyses of the samples taken included standard plat counts and counts for coliform bacteria, fecal coliform bacteria, and fecal streptoccus. 6.1.2 GROUNDWATER Baseline studies are described in the ER/CP. Groundwater levels were monitored at test wells around the periphery of the site excavation on a biweekly basis during the first three years of construction and bimonthly thereafter. No unusual or unantici-pated fluctuations in groundwater levels were observed. Construc-(~)T x - i 6.1-1 i.
tion activities necessitated the removal of three of the five test wells in 1976. The locations of the test wells are shown in Figure 6.1-1. 6.1.3 AIR This section consists of three parts: (1) meteorology, (2) cooling-tower effects, and (3) noise. The meteorology dsLc collection system consists of measurements from an instrumented tower along with appropriate data reduction and assessments. This system has undergone improvements since the ER/CP; these improvements and the present system are described. The programs for estimating cooling-tower effects were not described in detail in the ER/CP; they are, therefore, presented here. Similarly, the noise measure-ments programs were not previously described and are presented here, , 6.1.3.1 Meteorology O O Both offsite and onsite data have been used to determine the meteorological characteristics of the PNPP site region and as input to various models (Section 6.1.3.1.3) used to predict the environmental effects of plant operation. 6.1.3.1.1 Offsite Data As described in Section 2.3, data on the meteorological character-istics of the PNPP region were obtained from National Weather Service (NWS) stations at the Cleveland Hopkins International ! Airport, approximately 50 miles southwest of the site, and tne Erie International Airport, approximately 50 miles northeast of the site. The Cleveland and Erie stations are at elevations of 777 and 731 feet above mean sea level (MSL) , respectively compared with the plant grade of 620 feet MSL. The data obtained for these NWS stations consisted of observations recorded at (~T 3-hour intervals and stored on magnetic tape; they covered a ' (J 6.1-2 t
i i i period of 10 years (long-term data) and the period concurrent t - with the site meteorological program. In addition, tapes con-taining hourly observations were obtained for the 5-year period l February 1959 to January 1964, for the purpose of analyzing offsite wind-direction persistence. Additional climatological l data were obained for Painesville, Ohio '(elevation 600 feet ! MSL, 7 miles southwest of the site), and Geneva, Ohio (680 feet MSL, 10 miles east of the site). i Information on the temperature, humidity, precipitation, and
wind instrumentation and measurement heights at each of the

offsite locations can be found in the Local Climatological Data Summaries for these stations. The instrumentation at the NWS i station at the Cleveland Hopkins Airport is the standard instru-j mentation used at most NWS stations throughout the United States.
6.1.3.1.2 Onsite Meteorological Measurement Program 6.1.3.1.2.1 System Description. The onsite meteorological program at the PNPP site began in April 1972. In August 1977, { the 60-meter (200-foot) tower was upgraded and moved 3500 feet + to a new location (see Section 2.3, Figure 2.3-14) in order j to minimize any potential ef fei-ts of the PNPP cooling towers, which were being constructed at the time. The old location of the tower was approximately 3700 feet south of the Lake Erie i shoreline. The new location is approximately 6000 feet inland and 4300 feet away from the hyperbolic cooling towers. The ! terrain in both locations is flat and covered with grasses, ! small shrubs, and small trees. The terrain in the site region is similar. Because of the similarity in terrain, the meteoro-i logical data collected at the tower should be reasonably repre- ! sentative of the site region. Wind, temperature, and dewpoint data are collected at the 10-l meter ( 35-f oot) and 60-meter (200-f oot) levels of the open-lattice 1 tower. Wind sensors are_ mounted on booms that extend to approxi-
}
~~!- 6.1-3 t l~~
~~.- - ~ ,- - --- - . ..-- . ,,,m,--, , , . _ , , . . . , , - , , , - , , - . - , - , , . -.m __.-.,-~,.c.,..___,~~
mately 9 feet to the west of the tower. Temperature and dewpoint sensors are mounted on booms that extend approximately 7 and [} 6 feet, respectively, to the west of the tower. Precipitation is measured at the surface from a rain gauge near the base of the tower. Analog data recording equipment is housed in an environmentally controlled shelter near the tower to the east. Also housed in the shelter is a minicomputer that provides a digitized record I of averaged meteorological data, both directly to a remote onsite i location and via telecommunication to a remote offsite location, where the record is examined daily for any anomalous meteorological conditions or obvious instrumentation problems. Instrumentation for the onsite program includes the following: Parameter Instrumentation Winds Set of Climet wind-speed and wind-direction sensors at 10-and 60-meter levels Temperature Rosemont resistance temperature i bulbs at 10- and 60-meter levels, i . housed in Geotech aspirated solar i radiation shields; Endevce signal conditioner , l Dewpoint Aspirated EG&G dewpoint-measuring units at 10- and 60-meter levels Precipitation Belfort heated tipping-bucket rain gauge and wind shield at ground-level
~~;()~~
~~6.1-4 l~~
~~._ .. , -. .. .. -,- . - . . . . . - _. ..-.- .......--.-...__....._--_...a~~
Atmospheric pressure Teledyne Geotech unit at 2-meter level Recorders Esterline-Angus multipoint recorders for all parameters except wind speed and direction, for which Esterline-Angus two-channel strip recorders are used Computer Digital Equipment Corporation model YSI II The specifications of the equipment for the meteorological system comply with the intent of NRC Regulatory Guide 1.23 (2) and are provided in Table 6.1-1. The sensor accuracies reflect all the equipment through the signal conditioners; the overall system accuracy for each meteorological parameter can be calculated from this information. O kJ Accuracies for instantaneous recorded values are calculated using the root sum squares of the accuracies of each component. Time-averaged accuracies are computed by dividing the instantan-eous accuracy by the square root of the number of samples taken per hour. The analog strip recorders (wind speed and wind direc-tion) are continuous, and hence the number of samples is essentially infinite. For an hourly average, a sampling rate of 10 times per second is assumed. The overall analog system instantaneous l accuracy for wind direction is 16.2 degrees. The overall analog system securacy is 10.01 mph for time-averaged wind speeds (all wind speeds),10.03 C for temperature,10.01 C for the vertical ! temperature difference 6T, and 10.05 C for dewpoint. The analog i multipoint recorder (temperature, 6T, dewpoint, and precipitation) samples each parameter approximately once per minute. The 9-foot-high shelter housing the signal-conditioning equipment {} and recorders is approximately 8 feet east of the base oi the 6.1-5 l
tower. Because of its location and design it is expected that {} the shelter will have negligible effect on the representativeness of data collected at the tower. The automated tipping-bucket rain gauge is located approximately 11 feet west of the tower and 30 feet west of the shelter. It is not expected that the tower, shelter, or surrounding security fence will affect precipitation measurements. The meteorological system at the PNPP is calibrated at least semi-annually. System surveillance has included daily checks by a duty observer; checks through dial-up of the computer have been made since April 1978. As soon as a malfunction is detected, either by daily system survaillance or by weekly analog-chart review, field service perrcAnel are dispatched to correct the problem. 6.1.3.1.2.2 Meteorological Data Reduction. Analog strip charts and multipoint charts were manually reduced for all onsite data (} cresented in this report. One-hour averages of all parameters except the wind and precipitation were read from the multipoint chart. Precipitation'was totaled for the hourly period. The reading for each hour was previously centered on the hour, but after the digital system was installed (March 1978) , the period was shifted to end on the hour, so as to be compatible with the real-time digital printout. The strip charts for wind records were read for a 15-minute period ending on the hour. All the manually reduced data were transcribed on punch cards, listed, reviewed, and subsequently used as input to data analysis computer programs. The classification of atmospheric stability was based on the vertical temperature difference between the 60- and 10-meter levels (6T(60-10m)). O 6.1-C
l 6.1.3.1.2.3 Meteorological Data Recovery. The monthly and gg annual meteorological data-recovery rates (by year and combined)
~~/ are presented in Table 6.1-2 for 3 years: May 1, 1972, through April 30, 1973; May 1, 1973, through April 30, 1974; September 1, 1977, through August 31, 1978.~~
All site data for this report period were derived frem analog chart records. Annual data-recovery rates generally exceeded 90 percent. The data-recovery rates for the 3 site years combined are 95 percent for joint-occurrence 10-meter wind and AT (60-10m) data and 87 percent for joint-occurrence 60-meter wind and 6T (60-10m) data. (These are considered the key parameters since they are used in the calculation of dispersion parameters presented in Section 2.3.) 6.1.3.1.3 Models 6.1.3.1.3.1 Realistic Accident Diffusion Estimates. Meteorologi-(g cal data collected at the PNPP site for 3 years were used to 5- / evaluate the accident meteorology for the PNPP area. The 3 site-data years are May 1, 1972, through Apri) 30, 1973; May 1, 1973, through April 30, 1974; and September 1, 1977, through August 31, 1978. Realistic atmospheric dispersion estimates were made for evaluations of the environmental effects of accidents (Chapter 7) . Among the basic inputs to the accident analysis were parameters that determine the dilution capacity of the atmosphere; these meteorological conditions were based on the 50th percentile probability level (3) for the standard population distances and the exclusion-area boundary. Direction-Dependent Calculations: Atmospheric dilution factors ()0/0 values) were calculated at the population distances for time periods of 8 hours, 16 hours, 3 days (72 hours), and 26 days (624 hours). The X/Q value for each sector was obtained by logarithmic interpolation between a 2-hour value and the annual average (8760-hour) value at the distance of interest (-) L.; 6.1-7
in the same sector. The annual average value was calculated
~~- for a ground-level release, in accordance with the methods des-cribed in NRC Regulatory Guide 1.111 I4) (see Section 6.1.3.1.3.2).~~
The X/Q values applicable for release durations of less than or equal to 2 hours were calculated at the population distances in each sector, using the joint-frequency distributions of wind speed and wind direction by atmospheric stability class. Winds were measured at the 10-meter level, and the stability class was based on the vertical temperature gradient between the 10 and 60-meter levels, AT(60-10m), in accordance with NRC Regulatory Guide 1.23.(2) The 2-hour X/Q value was determined as the greater value(5) calculated from either 1 (f) (6.1-1)
~~= u_ ( nojz o + A/2) or C,/ )~~
~~u3noyz o (6.1-2) where X/Q = relative concentration at ground level (seconds per cubic meter) n = 3.14159~~
~~- = mean wind speed at 10 meters (meters per second) ay = lateral plume spread (meters), a function of atmos-pheric stability and distance o = vertical plume spread (meters), a function of z~~
atmospheric stability and distance A = 1780 square meters, the smallest vertical plane cross-sectional area of the building from which the effluent is released. 6.1-8 l l L
During periods of neutral (D) and stable (E, F, and G) conditions, when the wind speed was less than 6 meters per second, credit ( for horizontal plume meander was taken, such that I
un I g (6.1-3) z where l I y is the lateral plume spread with meander, a function of atmospheric stability, wind speed, and downwind distance from the point of zelease. For distances to 800 meters, I = Ma ,
~~y M being a function of atmospheric stability and wind speed (it is based on Figure 3 of Reference 5). For distances greater than 800 meters, yy = (M - 1) ay800m + oy I")~~
~~Once 2-hour X/O values were calculated for each sector for each combination of wind speed and atmospheric stability class, cumulative probability distributions of X/Q values were deter-~~
'T mined. This was done for each distance of interest. Then, C~J for each of 16 sectors, at each distance, a X/O value that is exceeded no more than 3.125 percent (50 percent 16) of the total time was selected for use in the assessment. These values are presented in Section 2.3 and in Chapter 7.
Direction-Independent Calculations: For calculations of accident X/Q values at the exclusion-area boundary,* a direction-independent method was used. This approach is based on the same X/Q model and equations as those used for the direction-dependent calculations. However, the 2-hour value is determined by calculating X/Q values for each sector at the distance of the exclusion-area boundary and computing an overall (i.e., without regard to direction)
*The exclusion area is defined by two circles drawn around Units 1 and 2, with a radius of 863 meters from the outer edge of the reactor containment building. <w 6.1-9
~~cumulative probability distribution. From this distribution, the value that is exceeded no more than 50 percent of the total~~
-) 's' time was selected. Using this overall 50 percent 2-hour X/O value, the values for longer time periods (i.e., 8 and 16 hours and 3 and 26 days) were logarithmically interpolated, as in the direction-dependent approach; however, the maximum annual average Y/Q value over the 16 sectors was used as the other end point. The calculated X/Q values for the exclusion-area boundary are given in Section 2.3 and Chapter 7.
j 6.1.3.1.3.2 Long-Term (Routine Release) Diffusion Estimates. Meteorological data collected at the PNPP site for 3 years were used to determine the long-term diffusion estimates for the site area. The 3 site-data years are May 1, 1972, through April 30, 1973;~May 1, 1973, through April 30, 1974; and September 1, 1977, through August 31, 1978. The atmospheric dilution factors ( X/0) and relative deposition
/~N rates (D/Q) were determined for the site boundary and for distan-k~s ces out to 80.5 kilometers (50 miles) from the containment struc-tures. A set of distances, by sector, was developed for the analysis by determining the shortest distance between the boundary and the closest edge of either the containment building, turbine building, or offgas building; thus, these distances are realistic to conservative for each of the three routine-release vents l
on these three buildings. A separate set of such distances was developed for Units 1 and 2. For building height wake effects, a height of 40 meters was assumed, and releases were assumed to be at ground level. The 40-meter value is the average of the heights of the three buildings, with the height of the offgas building taken to be the same as the height of the containment building. (The offgas. building is shorter than the containment building but is immediately adjacent to it.) Both X/Q and D/Q values were determined in accordance with the methods presented in NRC Regulatory Guide 1.111 I4) and the (~} us j 6.1-10
NRC code XOQDOQ. (6) The calculations were made for the site boundary and at the " population distances" discussed in NRC ! O' Regulatory Guide 1.70.(7) For conservatism, all releases were assumed to occur at ground level. Winds were determined at the 10-meter level, and the stability class was based on the vertical temperature gradient between 10 and 60 meters. In accordance with NRC Regulatory Guide 1.111, calms were distributed directionally in proportion to the directional distribution within a stability class of the lowest wind-speed group. Calms were assigned a speed one-half the threshold wind speed, 0.75 mph, of the wind vane. The following equations was used to determine X/O values: (h)D lj NE D 3 f3 where: ( X/Q) D = average effluent concentration X, normalized by V source strength Q, at a downwind distance x, for a given direction D (sec/m 3) x = downwind distance (meters) n f3 = length of time (hours) of valid data for a given wind direction D, wind-speed class i, and atmospheric stability j N = total number of hours of valid data 1 73 = effective vertical dispersion parameter (meters) for stability class j
~~= average wind speed (meters per second) for wind-I~~
! speed class i and stability class j for sector D. An effective vertical dispersion parameter' 1z., is calculated to account-for building wake effects as follows (4) m f 6.1-11
TEST TARGET (MT-3) 1'0 'am an E EE gs3 l.l $ u I- b-l1 1.4 1.6 l 1.25 l
~~= c ,~~
~~MICROCOPY RESOLUTION TEST CHART 4lI//% %p~~
//
~~StfN'I $+A4 t;9~~
~~r l gh l 9'*MRy ////[*G 4 M~~
% * %4 \ IMAGE EVALUATION NNNN TEST TARGET (MT-3) 1.0 l"Bla EM 6 IE g g g l13 ! =2.2 l,l #
~~b$ l.25 1.4 1.6 I < ._ MICROCOPY kE 0;'.:flON TEST CHART l l 5% +//p ?$>'k' ///// 1+d<~~
?
~~._=. - _- _~~
1
~
~~2' H 1.= Z3 az]. 2a~~
~~. (6.1-5)~~
O with the constraint i 1 23 $aj z d where 173 = vertical plume spread meters, a function of atmos-pheric stability j, and distance x H = maximum adjacent building height (40 meters). In depleting the X/Q values to account for deposition, the curve in Figure 2 of NRC Regulatory Guide 1.111 was used; radio-active decay was not considered. In calculating D/O values, l Figure 6 of Regulatory Guide 1.111 was used to obtain relative 4 deposition rates. The deposition rate for a given distance was then multiplied by the fraction of the release transported 1
% into the sector (wind direction frequency) and divided by the arc length of the sector at the distance of interest. From this calculation, the relative deposition per unit area, D/Q, in reciprocal units of square meters, was obtained.
In accordance with Regulatory Guide 1.111, since this taodel does not directly consider terrain-induced spatial and temporal variations in air flow, appropriate adjustments were made to j the calculated X/Q and D/Q values. The terrain adjustment i factors used are specific to the PNPP site and were developed previously(O'9) by comparing X/Q values determined by this i straight-line model and by the time-dependent, segmented-plume model NUSPUF..( 0) The adjustment factors as a function of sector and distance are presented in Table 2.3-22, the value for each sector and distance being the maximum factor within that area. The largest factor was found with the first mile to the south. It is thought that'this maximum is related to the decline and 6.1-12
subsequent decay of the lake breeze in the late afternoon and early evening.(10) Long-term X/Q at. 0/0 estimates for the PNPP site boundary, calculated with the appropriate terrain adjustment factors, are presented in Section 2.3. Values at other distances were used in Chapter 5. i 6.1.3.2 Cooling Tower Effects _ The environmental impacts that can result from the operation of an evaporative cooling system include the formation of fog, elevated visible plumes, airborne concentrations and ground deposition of dissolved solids contained in drift droplets re-l leased from the cooling system, and horizontal and vertical icing. The methods used in calculating these environmental impacts are discussed below.
' The frequencies of ground-level fog, elevated visible plumes, N airborne concentration and ground deposition rates of dissolved solids in drift, and both horizontal and vertical icing were calculated for the PNPP cooling towers by the computer code FOG.Ill) Calculations of the environmental impacts were based on 3 years (May 1972 through April 1974 and September 1977 through
~~! August 1978) of hourly meteorological data collected at the site.~~
The noise generated by the operation of the PNPP cooling system was calculated and compared with noise criteria established by the U.S. Department of Housing and Urban Development and the sound-level guidelines issued by the U.S. Environmental Protection Agency.
6.1.3.2.1 Induced Ground-Level Fogging The FOG code (described in detail in Reference 11) uses sequential 6.1-13
meteorological data to simulate plume dispersion from evaporative co,oling systems. The cooling system plume is simulated as a l bent over plume with an entrainment rite of 0.5, using the Briggs (12) ! plume rise equations to the point of plume leveloff and Gaussian dispersion equations at all distances Leyond this point. The buoyancy of the plume is computed from tra effluent temperature and air flow rate at the exit of the cooling tower and from the ambient dry bulb temperature and relative humidity. } The FOG code makes calculations over a polar grid centered on l the cooling system. This grid consists of 16 directions corres-ponding to the routinely observed wind directions and up to 20 downwind distances. The ground elevation at each grid point relative to the cooling system is used ir; calculating the effec-tive plume height. The plume is assumed to propagate rectilinearly, with any meandering effects due to wind shifts being neglected. This assumption of rectilinear propagation leads to conservatism in the calculation of ground-level centerline effects and in g visible-plume lengths. The required Pasquill stability classes 5 {"'/ N- are determined from the measured dry-bulb temperature difference between the 10- and 60-meter levels on the PNPP meteorological tower. Formulations for the critical wind speed resulting in the aerodynamic downwash of the exhaust plumes are also included in the FOG code. For the purposes of this study, ground-level fog induced by the operation of the cooling system is defined as a reduction in ground-level visibility to 1000 meters (5/8 mile) or less. According to an international definition, 1000 meters is the limit on viribility above which fog is not considered to occur.(13) The liquid water content of the plumes at ground level is calcu-lated from the Gaussian dispersion analysis discussed above, with all moisture in excess of that required to saturate the ambient air assumed to form condensed-water droplets. An empirical equation presented by Petterssen II4) is then used to relate the atmospheric water content to the horizontal visibility. e 6.1-14
~~, , - , . - , - - . - .-- - - . - , . ~ - , - , . - - - , , - . - - - , , - - , . - ,~~
6.1.3.2.2 Horizontal and Vertical Icing (~ k The FOG computer code was also used to calculate the frequencies of ice formation, in various thickness categories, due to accumu-lations of condensed-water and drift droplets released from the PNPP cooling system. Routines in the code calculate ice buildup on both horizontal surfaces (roadways) and vertical surfaces (trees, switchyards). The rate of ice buildup can be limited either by the liquid-water delivery rate to the collect-ing surface or by the heat balance necessary to sustain freezing conditions. In the case of ice formation on elevated flat vertical surfaces, ice buildup can result from the impingement of both condensed-water and drift droplets. The liquid-water delivery rate is computed as the liquid mass flux times the intercep'ed surface area. This value is then multiplied by a collection efficiency of 0.8 for the condensed-water droplets, which are generally
'" % less than 20 microns in diameter, and by a collection efficiency \' of 1.0 for the larger drift droplets. The dispersion of the relatively small condensed-water droplets is treated the same as that of the vapor plume, while the transport of the drift droplets is the same as that employed for the salt-deposition or volume of interest. Ice formation is assumed to occur only when the ambient temperature T is less than 0 C. Melting, on the other hand, is assumed to occur only when T is greater than 0 C. Under certain conditions, the ice buildup rate can be limited F- heat-transfer effects. This occurs when the heat of fusi.. released during freezing results in a surface tempera-ture TS equal to O C, even though T is less than 0 C. Since any additional ice buildup would increase TS above O C, such ice formation would be impossible.
In the case of ice formation on horizontal ground-level surfaces, l ice buildup is assumed to result only from the fallout of the t eT drift droplets. Since the much smaller condensed-water droplets
~~\_)~~
1 i 6.1-15
I , l l have negligible settling velocities, they are assumed not to l impinge on flat horizontal surfaces. The heat-transfer limita-tions on ice formation on flat horizontal surfaces are basically i the same as those discussed above for flat vertical surfaces, i j with one exception: melting from exposure to solar radiation is included in the simulation for flat horizontal surfaces, but not for flat vertical surfaces. The reason for treating 3 solar radiation in this manner is that unshielded flat horizontal ! surfaces are always exposed to solar radiation, whereas vertical j surfaces are not. i 6.1.3.2.3 Elevated Visible Plumes The FOG code as described above was used to calculate the frequen- ) cles of occurrence of elevated visible plumes over each grid 1
point under consideration. The total flux of air through a cross section of the plume normal to the plume axis is calculated at successive downwind distances. This calculation is made whether the plume is in the rising stage or has reached its maximum height and leveled off. The amount of entrained air l' is computed as the difference between the total air flow and the air flow leaving the cooling system. The entrained air

and the effluent air from the cooling system are assumed to be thoroughly mixed isobarically, and the thermodynamic properties of the resulting mixture are calculated. A visible plume is predicted to occur at a particular grid point if the mixed plume is calculated to be supersaturated.
) 6.1.3.2.4 Drift Analysis 1 The FOG code was used to calculate the transport and ground-1 deposition rate of dissolved solids contained in the entrained drift droplets released form the cooling system. ! The drift-deposition routines in the FOG code consist of the following three calculational procedures: (1) sequential release !O l l 6.1-16 1 1 1 - - - - --_ -_- , _
of the entrained drift droplets from the effluent plume, (2) g the subsequent horizontal transport of the drift droplets as
/
they fall to the ground, and (3) airborne concentrations and deposition rates at prespecified downwind distances for each of the 16 wind directions. It is hssumed in the FOG code that the excess water vapor, the temperature excess, the vertical velocity, and the concentration of drift droplets follow a Gaussian distribution normal to the plume axis. The plume is assumed to extend two standard devia-tions (i.e., 2a and 20z) away from the plume sxis. The release of the entrained droplets at any point within the plume depends on the relative magnitudes of the terminal fall velocity of the droplets and the vertical velocity of the air in the plume. At each downwind distance under consideration, these two veloci-ties are compared for the various size categories of droplets in the plume, and a fraction of the droplets is released. This process is repeated until all droplets are released from the p plume. When the plume reaches its maximum height, the vertical
\- velocity throughout the plume is zero. Any droplets remaining in the plume at the level-off point are then released. Droplets released from the plume then fall, first through the plume air, and then through the ambient air beneath the plume. This drift is carried downstream by the ambient wind until it is deposited on the ground. The rate of fall of the drift droplets is propor-tional to their terminal velocity, which in turn is dependent on the size of the droplet. The size of the droplets can be changed by evaporative processes, which depend on the physical and transport properties of the liquid droplets and the surround-ing air. For relative humidities below 50 percent, complete evaporation of the drift droplets to dry particles is possible.
A stepwise procedure is employed in the FOG code to compute the trajectory of the droplets by considering the above effects. Drift deposition rates and airborne concentrations of dry drift l particles were calculate,d for each of the sequential hourly 6.1-17 l
i meteorological records included in the 3-year site meteorological data set. These were then summarized to obtain the deposition ' { (in pounds per acre-year) and airborne concentrations of dry particles (in micrograms per cubic meters) over the entire grid. The airborne concentration is calculated for a height of 2 meters above the ground. 6.1.3.2.5 Detailed Plume Analysis Cooling tower plume trajectories were calculated by the computer code LVPM (Lagrangian Vapor Plume Model) . (15) The LVPM computer code is a one-dimensional numerical model capable of predicting the detailed behavior of either wet or dry plumes for a given meteorological condition. The model incorporates the thermodynamics and microphysics of condensation and evaporation, superimposed on a dynamic model of bouyant convection. In the case of wet plumes, the release of latent heat through the condensation of moisture enhances the vertical growth of the effluent plume. This situation is somewhat similar to the development of an [- isolated cumulus cloud, where condensation enhances the growth in the core of the plume, while mixing and evaporation take place near its edge. The dynamic framework of the LVPM code is described by the equa-tions of motion for a quasi-incompressible fluid. A steady-state plume is assumed to simulate the continuous efflux to a horizontally homogeneous atmosphere. This assumption simplifies the numerical computation and leads to practical and economic application. Ambient meteorological conditions are obtained by reducing standard rawinsonde data. 6.1.3.3 Noise The operation of the PNPP will increase the environmental sound levels in the vicinity of the site. This section briefly discusses (~ the characteristics of sound, along with the applicable regulations V) 6.1-18 l
a and noise impact criteria, to provide a basis for evaluating {} the environmental sound levels in the vicinity of the site and the noise impact of the project. The methods used during the background and construction sound-level surveys and the noise impact analysis are also described. 6.1.3.3.1 Characteristics of Sound Noise can be defined as undesirable sound. Sound is created when a pressure disturbance is propogated through air in the form of compression waves, for which the following relationship holds: c=fA (6.1-6) where c = velocity of sound (1130 feet per second for standard atmospheric conditions of 70 F and 29.92 inches of mercury) f = fregnency (hertz) A = wavelength (f eet) . The pressure fluctuation at a point in space from sound waves is measured in terms of sound-pressure levels, defined as:(16) L p = 20 log 10 (p/po) (6.1-7)
~~where p = sound-pressure _ level (decibels in reference to p0)~~
~~L p = sound pressure _(newtons per square meter)~~
~~.p0 = reference sound pressure (newtons per square meter) .~~
A sound-pressure variation that can be barely detected by the 9 {} human ear is defined as the threshold of hearing and has been 4 6.1-19
4 i established as 2 x 10 -5 newton per square meter. This value is used as the reference sound pressure p0* Sounds are composed of many frequencies, with a sound-pressure level associated with each frequency, but most humans perceive
only those in the frequency-range of 20 to 20,000 hertz. This wide frequency range is usually divided into octave bands to provide a more detailed description of noise. The upper frequen-cies of these bands are twice the lower frequencies. Since the response of people to sound is frequency dependent, a sound is often measured in terms of the A-weighted sound-pressure level (dBA re 2 x 10-5 N/m2 ), which adjusts the contribution of each octave band according to the frequency-response curve of the human ear. The A-weighted sound-pressure level is an approximation of the human ear response to a given level of noise.
, The contribution of a given noise source to the background sound levels can be estimated from its sound-power-level frequency {"% N-- spectrum. The sound-power-level frequency spectrum of a noise 2 source is a measure of the total sound energy radiated by the source per unit time as a function of frequency. The sound-pressure level at a distance r from a source is related to the sound-power level at a given frequency by the fol'owing equation:(16,17) Lp ( r , 6, f ) = L,(f) 20 log r
+ 10 log Q ( 6,F) -An(f)r - 0.5 (6.1-8) where i -5 Lp newton
~~( r , 6, f ) = cound-pressure level (decibels re 2 x 10 per square meter)~~
~~-12 Ly(f) = sound-power level (decibels re 10 watt) r = distance from source (feet) f = frequency (hertz)~~
!- 6.1-20
An(f) = excess attenuation (decibels per foot) (- Q(6,f) = directivity factor (dimensionless). The term An(f) accounts for excess attenuation from atomspheric, terrain, and vegetation effects and can be determined from field studies and empirical equations based on experimental data. The sound-power-level frequency spectrum L (f) for a given source can be evaluated from sound-level measurements around the source or calculated from measurements made around similar sources. The directivity factor Q is defined as the ratio of the mean square sound pressure, at some fixed distance, averaged over all airections from the source. The directivity index G is defined as G (6,f) = 10 log Q ( 6, F) (6.1-9) For uniform spherical sound propagation, G = 0; for uniform hemispherical sound propagation, G = 3. Several environmental factors will affect the sound leveJs at a given location, including variations in both meteorological conditions and the state of vegetation and ground cover.(16,17) Variations in vegetation and groundcover, (18,19) because of seasonal effects, will result in varying amounts of excess attenua-tion through the year, depending on the nature of the vegetation and groundcover intervening between the source and the receptor.
~
Meteorological conditions will affect the sound levels at any location.(20) Vertical temperature and wind gradients will affect the directivity of a noise source because of the variation in the speed of sound with height, sometimes resulting in shadow zones into which sound waves are not effectively propagated. i A shadow zone is commonly encountered upwind from the source, where the wind gradient refracts the sound waves upward. Down-wind, the wind gradient refracts sound waves downward, and no 6.1-21 L
] shadow zone is produced. This results in a greater noise impact downwind of a source than upwind, along the directir,n of the O. prevailing wind. Temperature-induced sound refraction tends to be symmetrical about the source. A shadow zone may completely encircle a source during unstable conditions with a strong negative temperature gradient (Pasquill stability class A or B), and low wind speeds, such as on a calm, sunny day. However, there will be no shadow , zone during stable conditions with a strong positive temperature gradient (Pasquill stability class E or F) and low wind speeds, such as on a clear, calm night. This results in a greater noise impact under very stable atmospheric conditions than under very unstable conditions. Under low-level inversion conditions, in which the temperature decreases to a certain level and then begins to increase, a channeling effect can occur in which the sound waves are refracted g back into the levels beneath the inversion, leading to higher s- ) sound levels than normal and longer range sound propagation. 6.1.3.3.2 Regulations and Criteria i U.S. Environmental Protection Agency (EPA) , In a residential environment, the time-weighted day / night outdoor average sound level L dn, below which no effects on public health and welfare occur, is 55 dBA.I II These guidelines protect the majority of the exposed population, under most conditions, against annoyance. To. determine the L dn sound level, the equivalent sound level L eg is first computed from
~
~~y y Lg /10 - L eg = 10 log 100 i fi (10 ) (6.1-10)~~
~~~ ~~~
O 6.1-22
where
~
(OJ L i = sound level in the i th time interval (dBA) f a percentage of total analysis time represented i by the i th time interval. The time-weighted day / night outdoor average sound level, Ldn is computed from
~
~~[y Ld/10 (L n + 10)/10 Ldn ='10 log I 24 15 (10 ) +9 10 k ( 6 .1-11) where Ld"b eg for the daytime (0700 to 2200 hours) L n~~
*b eg fr the nighttime (2200 to 0700 hours).
I b The L dn n ise-level guideline is recommended by the EPA; it is not a standard. According to the EPA, nearly half the nation's population is exposed to L dn sound levels of 55 dBA or greater. A long-term national strategy document for noise abatement and control, (22) recommends the following regulatory actions:
1. Immediate reduction of the environmental noise exposure of the populatio- to an Ldn value f no more than 85 dBA

2. Reduction of environmental noise exposure levels to an L dn value f 65 dBA or lower through vigorous regula-tory and planning actions

3. Aiming for environmental noise levels that do not exceed an L dn va ue of 55 dBA in M ure programs aHect-g ing environmental noise exposure.
q) 6.1-23
~ U.S. Department of Housing and Urban Development (HUD) b N/ HUD has adopted the EPA-recommended L guideline of 55 dBA l as a goal for exterior noise levels.I I However, as a standard for HUD support for housing, an L dn eve nd below are acceptable and allowable. L dn levels above 65 dBA but not exceeding 75 dBA are considered "normally unacceptable," while levels above 75 dBA are " unacceptable." The HUD noise criteria are standards only for HUD-sponsored projects and may be considered to be reconmended guidelines otherwise. Other Noise-Impact Criteria Stevens et al.(24) suggested a method of noise-impact assessment that compares the background sound levels with the intruding noise. Since its introduction, other studies have shown the validity of this method;(25,26) it is an approach commonly used i by acousticians. This method has indicated that an increase g-s in the background sound levels of up to 5 dBA usually does not ( s' generate annoyance complaints while an increase of 20 dBA could cause vigorous complaints. 6.1.3.3.3 Survey Methodology The need for background sound-level surveys that adequately i characterize th'e background sound levels of the site is shown in examining two types of established noise-impact criteria. The first type (e.g., the noise-impact criteria recommended by EPA and HUD) sets an upper limit on the resultant noise levels. The second type (see, for example, Refs. 24 and 25) recommends a limit on the increase in the background sound levels from the new source, o A given range of background sound levels, whether high or low, is potentially both an asset and a liability in terms of the
~\
. (V l 6.1-24 f t _
noise impact of a facility. To satisfy the first type of noise-
,f impact criteria, which impose an upper limit on the resultant s3 (J sound levels, a facility would benefit from low background sound levels in the site vicinity, which would contribute little to the predicted resultant sound levels. To comply with the second type of noise-impact criteria, which limit the increase allowed above the background sound level, a facility we ~i benefit from high background sound levels in the site vic i which would tend to minimize the increase and mask new noise sources.
In devising the methods used during the background sound-level surveys conducted in the vicinity of the PNPP site, consideration was given to the guidelines published by the American National Standards Institute (ANSI).I ' 0) These guidelines establish a method for evaluating noise in an area in which the ambient sound level results from the superposition of several different noise sources. Ten sampling points were selected in the vicinity of the site based on their proximity to major existing noise e~ sources and noise-sensitive land-use areas, including residences,
\/ parks, churches, and schools, in order to obtain an adequate description of the sound levels (see Section 2.7). The .3urveys were conducted on July 18-20 and November 22-23, 1974, during summer and winter conditions, respectively. Measurements were obtained during the weekday and weekend periods of daytime (0700-2200 EDST) and nighttime (2200-0700 EDST).
~~The instrumentation used during the survey consisted of the following:~~
1. Bruel and Kjaer type 2209 precision sound level meter.

2. Bruel and Kjaer type 4145 condenser microphone.

3. Bruel and Kjaer type 4220 pistonphone.
~~This instrumentation meets the requirements of the ANSI standards for a type I (precisica) sound-level meter.(29) A 1-inch-diameter~~
~
condenser microphone was used to ensure accurate low-level ambient L)3 6.1-25
sound measurements. The meter was acoustically calibrated with the Bruel and Kjaer pistonphone before and after each measurement period to ensure continued accuracy. In all measurements an open-celled polyurethane-foam wind screen was used to attenuate the effect of wind-generated noise. Headphones were used to determine any distortion, improper amplification characteristics, and intermittent electrical connections. The microphone was mounted on a tripod.and located a sufficient distance away from all vertical surfaces to minimize reflection effects. Sound-level measurements were made with the sound-level meter operated in the A-weighted slow-response mode. The instrument-reading method involved observing and recording the meter reading once every 5 seconds, regardless of the location of the needle within its swing. These measurements were repeated until a statistically reliable sample was obtained. The number of readings required to achieve this condition was determined by the variability of the ambient suund level. The approach of taking a sample every 5 seconds resulted in a statistically independent sample
~~\~- because the interval was considerably greater than the averaging time.~~
In order to document the meteorological conditions that have an effect on sound levels, hourly readings of the wind speed, w i ..a direction, temperature, and dewpoint at the 10-meter level and the vertical temperature difference between*the 10- and 60-meter levels were obtained from the PNPP meteorological tower. The barometric pressure was obtained from the National Weather Service at the Cleveland Hopkins Airport. Thirteen sound-level surveys for monitoring construction noise 4 were conducted between May 1^75 and March 1978. The results of.these surveys are presented in Section 4.5. The instrumenta-tion for the first construction noise survey was the same as listed above for the background noise surveys. On subsequent ps surveys a Bruel and Kjaer type 2203 precision sound-level meter O 6.1-26
replaced the type 2209 meter. The number and the location of g the sampling locations varied during the surveys, depending (_) on the type and location of the construction activity. The methods used during the construction ncise surveys were the same as those described above for the background noise surveys. 6.1.3.3.4 Analysis Methodology The methods used in the noise-impact analysis were based in part on the characteristics of sound and the equations for sound propagation presented in Section 6.1.3.3. Operational sound levels were predicted using the computer code SOCON. This code calculates resultant sound levels, including background, on a grid basis from an arbitrary number of noise sources at an array of locations, assuming uniform hemispherical and propagation and frequency-dependent atmospheric absorption according to Equations 6.1.-8 and 6.1-9. Inputs include the sound-power frequency spectrum and grid coordinates of each source. Outputs 7 s, include coordinates of A-weighted sound-level isopleths, which
~~\,,) are then plotted on a site map.~~
The attenuation factors used to account for atmospheric absorption in the analysis are based on design curves presented by Peranek.(17 The basic model is conservative in that no credit is taken for excess attenuation by vegetation, ground effects, terrain effects, or meteorological effects such as shadow zones induced by wind or thermal gradients. Sound levels during operation were predicted using the source terms identified and developed for Section 5.6. The operational sources were located in an array corresponding to the site layout (Figure 5.6.-1). Sound levels predicted during operation are considered to be representative of the prevailing sound levels. Since no time variation of sound levels is considered, these sou 'evels are considered to be comparable to Leq sound levels.
~~- Th'e operational noise impact was then evaluated by comparing i \_/ .~~
l l 6.1-27 1
predicted sound levels with the noise-impact criteria set forth by the EPA ( 0) and HUD.(22) O 6.1.4 LAND 6.1.4.1 Geology and Soils Information on geology and soils was developed as part of the initial baseline studies and was provided in the ER/CP. 6.1.4.2 Land-Use and Demography Information and data contained in Sections 2.1.2, " Population Distribution," and 2.1.3, "Uses of Adjacent Lands and Waters," were obtained by such means as site visits, personal communica-tions with cognizant persons and organizations (e.g., planning groups, agricultural extension agents), and the study of relevant publications, maps, and aerial photographs. The comprehensive lists of references in Sections 2.1.2 and 2.1.3 indicate the specific sources of the information and data contained in the [v} text, tables, and figures. 6.1.4.3 Ecological Parameters Baseline studies are described in the ER/CP. During the construc-tion phase at the PNID, three aspects of a terrestrial monitoring program were undertakt This program included: (1) a raptor survey; (2) a crane-fly orchid ecology study; and (3) a color infrared aerial photography study. Raptor monitoring was conducted several-times each year from late winter to summer. Surveys were conducted from 1975 through 1978. These studies were provided to determine the possible environmental stresses or changes that may be induced by construc-tion activities. As discussed in Section 2.2.2.2.2, changes in the raptor population at the PNPP have corresponded to state-(~) wide variations from year to year. v 6.1-28 l l 1
During the spring and summer from 1974 through 1978, surveys () were conducted on the crane-fly orchids. The objective of the survey was to determine whether the orchids showed evidence of stress from construction activities. From 1974 through 1975, individual plants were counted and plant vigor was recorded. In subsequent years, individual plants were marked with flags to determine which plants provided leaves and which flowers. No significant change in the number of plants has been observed since the monitoring studies were begun. 4 Color infrared aerial photography and follow-up ground verifica-tion were used to assess the condition of site vegetation. The aerial photographs were taken between the middle of July and the middle of September in a program that began in 1975 and continued each year thereafter. There were subtle changes in healthy vegetation versus stressed vegetation in the photographs. Major changes were detected by comparing recently-acquired photo-graphs with previous ones. Analysis has shown that some changes () in land use have occurred since 1977; these changes did not have any adverse impacts. There are no symptoms of vegetative stress on the site or w. thin the immediate vicinity due to con-struction of PNPP. 6.1.5 RADIATION Nuclear Regulatory Commission regulations require that nuclear power plants be designed, constructed, and operated to keep levels of radioactive materials in effluents to unrestricted areas as low as reasonably achievable (ALARA) (10 CFR 50.34a). To ensure that these criteria are met, each license authorizing reactor operation includes technical specifications (la CFR 50.36a) governing the release of radioactise effluents. In-plant moaitoring is used to ensure that the.se predetermined release limits are not exceeded. However, as a precaution against unexpected and undefined processes in the environment that might () allow the accumulation of radioactivity in any sector of man's j 6.1-29
environment, a program for monitoring the plant environs is /~T also included. V The regulations governing the quantities of radioactivity in reactor effluents allow nuclear power plants to contribute, at most, an increase of only a few percent alav- the normal background radiation. Background levels at any one location are not constant; they vary with time under the influence of fallout, and seasonal variations. These levels also can vary spatially within relatively short distances, reflecting differen-ces in the geological environment. Because of the spatial and temporal variations, the radiological surveys of the PNPP environs are divided into preoperational and operational phases. The preoperational phase of the environmental monitoring program permits a general characterization of the radiation levels and concentrations prevailing before operation along with an indica-tion of the degree of natural variation to be expected. Data obtained in the operational phase of the program will be compared () with dcta from the preoperational program to assist in evaluating the radiological impact of plant operation. The preoperational environmental radiat;on-monitoring program was directed toward the following objectives:
1. To provide a baseline of radiological characteristics for the PNPP environment for comparison with future operational data.

2. To confirm that the selected media sampled and analyzed are sensitive to the spatial and temporal variations characteristic of the PNPP environs.

3. To ensure that the selected sample media are indicative of the potentially important pathways to man.
~~6.1-30~~
~~4. To augment personnel training and provide for the evalua-() tion of procedures, equipment, and techniques.~~
The early stages of the program will be flexible, to accommodate changes in plant planning, land use, and demography and advances l in monitoring and laboratory technology. The preoperational monitoring program is designed to correspond closely with the i requirements of the operational monitoring program. In addition to the preoperational monitoring program, related programs in the area are reviewed to augment information on 9 the local background radiation levels against which the opera-i tional results will be compared. Sampling locations for the preoperational monitoring program were selected on the basis of the local ecosystem, cl imate , and the physical, demographic, and cultural characteristics of the region. The frequency of the sampling period will, as a minimum, incorporate the parameters outlined in-the NRC Branch Technical Position $ ) on Regulatory Guide 4.8.(32) [v} The radiation-monitoring program is characterized generally at this time. Final details of the program will be decided just before implementation. The preoperational phase of the program will be implemented approximately 2 years before the anticipated issuance of an operating license. The subsections that follow describe the general program to be instituted, including the expected types of samples, the collection frequency, and the analysis to be performed on each type of sample. The preoperational phase of the environmental
~~radiological program is summarized in Table 6.1-3. The locations~~
~~!- of the sampling stations are indicated in Figures 6.1-2 and 6.1-3. (~~
^
~~6.1-31~~
~
i l l 6.1.5.1 Airborne O Airborne iodine and particulates will be sampled by continuous low-volume air samplers with a flow rate of approximately 1 cubic foot per minute. Radiciodine will be collected in charcoal canisters fitted in line with the filter for particulate collec-tion. The air-sampling network will consist r; six stations. The highest ground deposition (D/Q) of airborne radiciodine and particulates is calculated to occur east, east-northeast, and south of the PNPP. On this basis, air monitoring stations will be establis'ned at the site boundaries in the east and south directions and in the vicinity of Redbird, which is in the east-northeast sector and is the location calculated to receive the highest ground deposition. Additional air monitors will be located at tae site Doundary in the southeast and southwest directions. A control station will be placed in a south-southwest direction, 10 to 20 miles from the PNPP. O V The particulate filters will be changed weekly and analyzed for gross beta radiation. (Beta analysis will be made no sooner than 24 hours from the time of collection to allow for radon and thoron daughter decay.) For each location, a filter sample will be composited quarterly and subjected to gamma isotope analysis. Individual weekly filters will be subjected to gamma isotope analysis only if gross beta results are 10 times the mean of the control location. Charcoal canisters will be analyzed weekly for iodine-131. Particulate sampling will start at least 1 year before PNPP operation; iodine-131 analysis will begin at least 6 months before operation. O-
~~-m 6.1-32~~
~~6.1.5.2 Direct Radiation~~
)
Direct radiation levels will be measured by a thermoluminescent dosimeter (TLD) system consisting of twent;-four stations. Six of the stations will be located at the air-sampling sites. Four dosimeters will be placed at each station. Two dosimeters will be collected and analyzed monthly; the other two will be exchanged annually. 6.1.5.3 Waterborne 6.1.5.3.1 Surface Water and Drinking Water Plant discharges of water into Lake Erie are described in Chapter 3. In the area of the PNPP, the pattern of currents in Lake Erie fluctuates in opposite directions along shoreline contours for [)
~
approximately equal parts of the year. Since the lake is used for drinking water, PNPP operational requirements, and other purposes, some of the water-monitoring stations will be used to monitor both surface wcter and drinking water. Irrigation within 50 miles of the PNPP is considered to be insignificant, as discussed in Section 2.1.3.7.2. Water will be collected at the PNPP cooling water intake structure and the municipal water supply system intakes for Fairport Harbor, southwest of the PNPP, and the Green Road Plant for Redbird and Madison-on-the-Lake, east-northeast of the site. A control station will be located at the Cleveland water facility closest to the PNPP. Small volumes of water will be collected intermittently by an automatic sampler. A composite monthly _ sample will be analyzed for gross beta and gamma isotope activity. A quarterly composite will be analyzed for tritium. The surface-water sampling program will begin 1 year before station operation. 6.1-33
6.1.5.3.2 Groundwater A V The radiological impact of the PNPP on local groundwater is expected to be negligible, as discussed in Section 5.3. There-fore, no monitoring for groundwater is included in the environ-mental radiation-monitoring program. o6.1.5.4 Sediment for Shoreline Samples of bottom sediments will be collected at four locations. One location will be in the vicinity of the PNPP cooling-water i discharge; two other locations will be a few miles east and west of the site. A control location will be sampled in the proximity of Mentor-on-the-Lake. Shoreline sediments will be collected semiannually and subjected to gamma isotopic analysis. Sampling will start at least 2 years before operation. 6.1.5.5 Milk O Milk sampling will be conducted at a control station and at three locations within 5 miles of the PNPP (east-northeast, east, and southeast f rom the plant) . The exact locations will be chosen after a milk-animal census to be conducted before program implementation. The control station will be located in a south-southwest direction approximately 10 to 15 miles from the PNPP. Samples will be collected twice a month during the pasture season and once a month during the remainder of
, the year. Gamma isotope analysis will be analyzed for iodine-131 by radiochemical separation. Milk sampling will begin 1 year before operation. Analysis for iodine-131 will start at least 6 months before operation and will cover the full pasture season during the year before operation.
o i 6.1-34
6.1.5.6 Fish O Fish from Lake Erie will be collected semiannually by nets, shore seines, or other legal methods at one location near the site discharge and at a control location in the vicinity of Mentor-on-the-Lake. The edible portions of collected fish will be analyzed by gamma spectrometry. Sampling will begin 2 years before PNPP operation. 6.1.5.7 Summary The specific radioassay techniques and the minimum detectable levels will depend on the laboratory performing the analyses. However, the laboratory will be required, at a minimum, to meet the lower limit of detection requirements defined and outlined in the NRC Branch Technical Position I on Regulatory Guide 4.8.(32) The laboratory will also adhere to the quality control procedures recommended by NRC Regulatory Guide 4.15, Revision () 1,(33) and participate in the EPA's interlaboratory cross-check program, or its equivalent, to provide assurance of the accuracy of the analysis. The specific instrumentation for the measurement of radioactivity in the sample will also depend on the laboratory performing the measurements. When necessary to enhance the sensitivity of detection, radiochemical procedures will be used. These procedures are used mainly to separate or concentrate the radionuclide of interest from the
~~. inorganic or organic matrix.~~
I a (a~T l 6.1-35 I
() REFERENCES FOR SECTION 6.1
1. No Reference

2. U.S. Nuclear Regulatory Commission, Regulatory Guide 1.23, "Onsite Meteorological Programs," February 1972.

3. U.S. Nuclear Regulatory Commission, Regulatory Guide 4.2,
~~" Preparation of Environmental Reports for Nuclear Power Stations," NUREG-0099.~~
~~4. U.S. Nuclear Regulatory Commission, Regulatory Guide 1.111,~~
~~" Methods for Estimating Atmospheric Transport and Dispersion of Gaseous Effluents in Routine Releases from Light-Water-Cooled Reactors," Revision 1, July 1977.~~
~~5. U.S. Nuclear Regulatory Commission, Draft Regulatory Guide~~
~~() 1.XXX, " Atmospheric Meteorology Model for Potential Accident Conseguence Assessment at Nuclear Power Plants," November 9, 1978.-(Issued August 1979 as R.G. 1.145)~~
6. J. F. Sagendorf and J. T. Goll, XOQDOQ, Program for the Meteorological Evaluation of Routine Effluent Releases at Nuclear Power Stations, NUREG-0324 (draft), Nuclear Regulatory Commission, September 1977.

7. U.S. Nuclear Regulatory Commission, Regulatory Guide 1.70, j " Standard Format and Content of Safety Analysis Reports for Nuclear Power Plants LWR Edition," Revision 2, September 1975.
l- 8. -D. R. Davidson, Perry Nuclear Power Plant Docket Nos. 50-l 440 and 50-441, Terrain-Corrected Atmospheric Dispersion Factors, letter to the Director of Nuclear Reactor Regulation 6.1-36 l
from Vice President, Engineering, the Cleveland Electric () Illuminating Company, April 27, 1976.
9. D. R. Davidson, Perry Nuclear Power Plant Docket Nos. 50-440 and 50-441, Terrain-Corrected Atmospheric Dispersion Factors, letter to the Director of Nuclear Reactor Regulation from Vice President, Engineering, the Cleveland Electric Illuminating Company, July 2, 1976.

10. M. W. Chandler, J. R. Fleming, S. L. Shipley, and M. S.
Tapparo, NUSPUF - A Segmented Plume Dispersion Program for the Calculation of Average Concentrations in a Time-D.ependent Met.- ygical Regime,itUS-TM-260, NUS Corporation, Rockville, Md., March 1976.
~~11. G. E. Fisher, FOG Model Description, NUS-TM-S-185, NUS Corporation, Rockville, Md., July 1974.~~
~~(Oj 12. G. A. Briggs, Plume Rise, Atomic Energy Commission Critical Review Series, TID-25075, 1969.~~
13. R. E. Huschke, Glossary of Meteorology, American Meteorological Society, Boston, Mass., 1959, pp. 227-228.

14. S. Petterssen, Weather Analysis and Forecasting, Vol.
~~II, McGraw-Hill, New York, 1956. 4~~
15. J. Lee, The Lagrangian Vapor Plume Model - Version 3, NUS-TM-S-184, NUS Corporation, Rockville, Md., July 1974.

16. C. M. Harris, Handbook of Noise Control, McGraw-Hill, New York, 1957.
~~O b i 6.1-37~~
~~17. L. L. Beranek, Noise and Vibration Control, McGraw-Hill,~~
~~(} New York, 1971.~~
~~18. F. M. Wiener, and D. N. Keast, "An Experimental Study of the Propagation of Sound Over Ground," J. Acoust. Soc.~~
~~Am., Vol. 31, No. 6, June 1969, pp. 724-733. , 19. D. Aylor, " Noise Reduction by Vegetation and Ground," J. Acoust. Soc. Am., Vol. 51, No. 1 (Part 2), 1972.~~
~~20. U. Ingard, "A Review of the Influence of Meteorological Conditions on Sound Propagation," J. Acoust. Soc. Am., Vol.~~
~~25, No. 1, May 1953, pp. 405-411.~~
~~21. U.S. Environmental Protection Agency, Information on Levels of Environmental Noise Requisite to Protect the Public Health and Welfare with an Adequate Margin of Safety, EPA 550/-~~
~~74-004, March 1974.~~
22. U.S. Environmental Protection Agency, Toward a National Strategy for Noise Control, April 1977.

23. U.S. Department of Housing and Urban Development, Noise Abatement and Control, 24 CFR 51.100, 44FR40860, July 12, 1979.

24. K. N. Stevens, W. A. Rosenblith, and R. H. Bolt, "A Community's Reaction to Noise, Can It Be Forecasted?," Noise Control, January 1955, pp. 63-71.

25. F. G. Haag, " Community Response to Industrial Noise," Noise Control, July-August, 1974, pp. 10-13.

26. K. M. Eldred, " Assessment of Community Noise," Noise Control Engineering, September-October, 1974, pp. 88-95.
~~i O V 6.1-38 L~~
~~27. American National Standards Institute, Draft Method for~~
~~() Measurement of Community Noise, ANSI S3W50, November 11, 1969.~~
28. American National Standards Institute, Method for the Measure-ment of Sound Pressure Levels, ANSI S1.13-1971, August 14, 1971.

29. American National Standards Institute, Specifications for Sound Level Meters, Sl.4-1971, 1971.

30. Vegetation Monitoring with Aerial Photography and Ground Observations at the Perry Nuclear Power Plant Site During 1978, NUS Corporation, December 1978.

31. U.S. Nuclear Regulatory Commission, Branch Technical Position on Regulatory Guide 4.8, Revision 1, November 1979.
~~s 32 U.S. Nuclear Regulatory Commission, Regulatory Guide 4.8,~~
~~" Environmental Technical Specifications for Nuclear Power Plants," Issued for Comment, December 1975.~~
~~33. U.S. Nuclear Regulatory Commission, Regulatory Guide 4.15,~~
~~" Quality Assurance for a Radiological Monitoring Program (Normal Operations-Ef fluent Stream and the Environment) ,"~~
Revision 1, February 1979. O 6.1-39
o o o TABLE 6.1-1 PNPP METEOROLOGICAL SYSTEM EQUIPMDIT SPECIFICATIONS (April 1972 to August 1978) Parameter Manufacturer Model Level Threshold, Accuracy Wind Speed-Direction Climet Wind Direction 10m, 60m Threshold 0.75 mph WD-012-10 Accuracy 130 sensor Wind Speed Threshold 0.6 aph WS-Oll-1 Accuracy ilt of the ! wind speed reading or D.15 mph, whichever is greater Translator 025-2 Temperature Endevco 4470.114 Universal T(10m) T (scale -200F to 1000F) Signal Conditioner AT (60-10m) Accuracy +.120F 4473.2 RTB Conditioner AT (scale -40F to 80F)
=
GEDTECH M327 Aspirators Accuracy 1 020F) Rosemount 104MB12ADCA Y four wire RTB 6 o Precipitation Belfort 5-405 H Rain Gauge Ground Accuracy 12% (in) for Weather Measure P565 windshield 1 in/h (after 1978) Dew Point Cambridge 110S-M 10m Accuracy 10.50F ! EG&G (after August 1977) 220 10m, 60m Accuracy 10.40C Station Pressure Teledyne Geotech BP-100 (28-32) 2m Accuracy 10.02 in of Hg (after August 1977) ;
~~, Multipoint Recorder Esterline-Angus Ell 24E Shelter Accuracy 10.25% of full ^~~
T(10m) , AT(60-10m) scale dew points, pres-sure, precipitation l
O O TABLE 6.1-1 PNPP METEORDIDGICAL SYCTEM EQUIPMENT SPECIFICATIONS (Contittued) (April 1972 to August 1978) Parameter Manufacturer Model Level Threshold, Accuracy Strip Recorders Esterline-Angus E1102R Shelter Accuracy of +1% of full (2 ea.) (ws/wd) scale Minicomputer (after DEC LSI-ll with Shelter Accuracy of converter is l August 1977) ADV ll-A converter +0.10% of full scale t i 4 i e ( N f j i ' H i 1 1 i i ' 1 i Jl i t
o o o TABLE 6.1-2 i METEOROIOGICAL DATA RECOVERY (PERCENT) AT THE FNPP Three years: (a) May 1, 1972 to April 30, 1973 (b) May 1,1973 to April 30, 1974, (c) September 1, 1977 to August 31, 1978 (' ' = parameter not monitored at the time) 60-m 10-m Joint 10-m Joint 60-m 10-m 60-m 10-m Ambient Winds (a) windsI*) AT(60-10m) Winds & &T Winds & &T Dewpoint Dewpoint Precipitatiorn Temperature i January 1972-1973 85 99 95 99 85 57 - 99 99 1973-1974 96 100 100 100 96 100 - 99 99 1977-1978 99 96 99 96 99 45 99 99 99 February 1972-1973 85 90 93 83 79 0 - 96 95 1973-1974 99 100 99 99 99 98 - 99 99 1977-1978 100 100 99 99 99 99 43 99 99 March 1972-1973 88 99 99 99 88 45 - 99 99
1973-1974 57 98 98 97 55 98 - 98 99 e 1977-1978 90 90 94 88 87 53 41 98 95 1
A April N 1972-1973 99 100 100 100 99 96 - 100 99 1973-1974 38 100 100 100 38 100 - 100 99 1977-1978 100 100 85 85 85 60 25 98 96 May 1972-1973 97 90 97 88 95 47 - 97 98 1973-1974 100 100 100 100 100 50 - 100 99 1977-1978 98 98 95 95 95 94 83 99 98 June 1972-1973 100 99 99 99 99 43 - 99 - 1973-1974 50 99 96 96 50 57 - 99 96 1977-1978 90 96 98 98 96 74 74 99 98 July 1972-1973 77 74 76 73 76 44 - 67 77 1973-1974 24 99 97 97 23 97 - 99 94 1977-1978 99 99 99 99 99 83 90 100 99 August 1972-1973 100 100 100 100 100 99 - 100 99 1973-1974 81 99 96 96 79 94 - 96 96 1977-1978 98 97 96 96 96 63 98 90 96 September 1972-1973 98 98 93 92 92 66 - 93 92 1973-1974 100 100 99 99 99 99 - 99 99 1977-1978 99~ 95 99 95 99 0 0 99 99
O O
~~%/ O TABLE 6.1-2 (Continued)~~
METEOROLOGICAL DATA RECOVERY (PERCENT) AT THE PNPP Three years (a) May 1, 1972 to April 30, 1973: (b) May le 1973 to April 30, 1974, (c) September 1,1977 to August 31, 1978 (* * = parameter not monitored at the time) 60-m 10-m Joint 10-m Joint 60-m 10-m 60-m 10-m Ambient Winds (a) winds (*) ST(60-10m) winds & AT winds & AT Dewpoint Dewpoint Precipitation Temperature October 1972-1973 100 100 99 99 99 99 - 99 99 1973-1974 99 100 100 100 99 100 - 100 99 1977-1978 100 99 95 95 95 86 7 95 96 November 1972-1973 100 100 100 100 100 99 - 100 99 1973-1974 100 100 99 99 99 99 - 99 99 1977-1978 84 91 98 90 83 65 67 99 96 Dece e er
~~1972-1973 90 92 100 92 90 97 - 100 99 h 1973-1974 1977-1978 86 100 96 99 84 99 82 99 75 99 84 83 99 99 99 98 99 b~~
W Annual 1972-1973 93 95 96 94 92 67 - 96 96 1973-1974 77 99 97 97 76 90 - 99 98 1977-1978 97 97 96 94 94 67 60 98 97 Combined 89 97 96 95 87 74 - 97 97 (a) Recoverable wind data defined as the hourly availability of valid wind speed and direction data
Q, - TABLE 6.1-3 PNPP PREOPERATIONAL E2 7IRONMENTAL RADIOIDGICAL MONI'IORING PRC'3 RAM Analysis Sample Media Location Sampling Frequency Type Frequency Airborne radiciodine(a) ENE--Redbird Continuous sampler operation Radioiodine Weekly following and E-Site Boundary with collection weekly or I-131 canister change particulates(b) as required by dust load- Particulates Weekly following S--Site Boundary ing, whichever is more Gross (d) canister change SE-Site Boundary frequent SW--Site Boundary Gamma Composite, by loca-Isotopic (*) tion, quarterly SSW--10 to 15 miles distant (control)
, Direct Radiation (c) At each airborne Continuous sampling, two Gamma Dose Monthly y (4 TIDs/ location) monitoring location TIDs exchanged monthly a NE--Site Boundary Continuous sampling, tw<' Gamma Dose Annually
~~ENE-Site Boundary TLDs exchanged annually E--Site Boundary SSE--Site Boundary SSW--Site Boundary WSW--Site Boundary ENE-5 mi. (Vicinity of Madison-on-the-Lake)~~
~~E-5 mi.~~
ESE--5 mi. SE--S mi. SSE--S mi. S--S mi. SSN--5 mi. 1 SW--5 mi. WFW--5 mi. SW--Painesville j WSW--Fairport Harbor j SW--Control (Greater flan 10 mi . )
d D TABLE 6.1-3 (Continued) PNPP PREOPERATIONAL ENVIRONMENTAL RADIOIDGICAL MONITORING PROGRAM Analysis Sample Media Location Sarpling Frequency Type Frequency Waterborne PNPP Cooling Water Composite (f) H-3 Composite, by loca-surface (a) Intake Structure tion, quarterly drinking (a) Fairport Harbor Water Gross Monthly Supply System Ganuna Monthly Isotvic
~~, . Redbird / Madison-on-the-Lake Water 7~~
s Supply System Control--Cleveland Water Supply Facility (approximately 25 miles SW of PNPP) Sediment from NNW--PNPP Discharge Semiannually--Spring and Gamma Semiannually shoreline (c) Fall as weather permits Isotopic
ENE--Vicinity of Redbird WSW--Vicinity of Fair-port Harbor WSW--Control--Vicinity of Mentor-on-the-Lake Ingestion Milk (9) ENE-Approximately Monthly when animals are not Gamma Iso- All samples 2.0 miles on pasture topic (b) i
~~O o o TABLE 6.1-3 (Continued)~~
~ e- PNPP PREOPERATIONAL ENVIRONMDITAL RADIOIDGICAL MONI'IORING PROGRAM Analysis Sample Media Location Sampling Frequency Type Frequency E-Approximately Semimonthly when animals are I-131(a) All samples 4.0 miles' on pasture SE-Approximately 4.0 miles SSW--Approximately 10-15 miles (Control)
~~Fish (c) NNW--Vicinity of PNPP Semiannually-Spring and Gamma Semiannually Discharge Fall as weather permits Isotopic~~
~~. (edible y portion) s~~
~~WSW--Control--Vicinity of Mentor-on-the-Lake (a) Sampling begins at least six months prior to PNPP operation, including one pasture season.~~
(b) Sampling begins at least one year prior to PNPP operation. (c) Sampling begins at least two years prior to PNPP operation. (d) Particulate sample filters will be analyzed for gross beta 24 hours or more after sampling to allow for radon and thoron daughter decay. If gross beta activity in air or water is greater than ten times the mean of control samp.les for any medium, gamma isotopic analysis will be performed on the individual samples. (e) Gamma isotopic analysis means the identification and quantification of gamma-emitting radio-nuclides that may be attributable to the effluents from the facility. (f)Ccaposite samples will be collected with equipment that is capable of collecting an aliquot at time intervals that are very short (e.g. , hourly) relative to the compositing period (e.g. , monthly) . (9) Definitive sampling locations will be determined by a milk-aniul census prior to initiation of preoperational monitoring.
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7 ' ' .H . 'fs j R ADIOLOGICAL MONITORING PROGRAM [' ' I ' ~- ?~, g "O SAMPLING LOCATIONS WITHIN 5 MILES OF SITE 1
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* */ --- t - - ' 6.i*- PERRY NUCLEAR POWER PLANT 1 & 2
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~~THE CLEVELAND ELECTRIC ILLUMINATING COMPANY FIGURE 6.1-2 6.1-48 l l~~
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~~isaa LEGEND C47 Road DATA 1956 PARTIALLY REvlSED 1966 7 i~~
~~(. f 1 PGPULATED PLACES O BOSTON '~~
NNE - o,,5m.000 100.000 to 500.000 RIGMOND 25.000 to 100.000 EVANSTON 5.000 to 25.o00 Hialeah 1.000 to 5.000 Sar Martner Less th.g 1.000 Fishkill NE waterworks in ,o,os "A'.9.'"','!!h".*i.7..'".*a. " * ' " " o., a, )g T. . i. ,.. ., .; r.4.... .. . ,n.. ., p
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R ADIOLOGICAL MONITORING PROGR AM {fl{f, o , , , , , O *** c SAMPLING LOCATIONS > 5 MILES FROM SITE e gl*(M i N SCALE
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~~Q gy ' M .'r/F f" N Q ,)J7p f' { - ,J.u - y . )~~
PERRY NUCLEAR POWER PLANT 1 & 2 THE CLEVELAND ELECTRIC fLLUMIN ATING COMPANY FIGURE 6.1-3 6.1-49
() 6.2 PROPOSED OPERATIONAL MONITORING PROGRAMS 6.2.1 ENVIRONMENTAL RADIATION MONITORING The operational radiation-monitoring program is designed to detect and measure potential changes in the concentration of radionuclides in the environment with respect to reactor opera-tion. The analysis of environmental samples in detecting and quantifying these changes is complicated by potential variations in natural background radiation and analytical limitations. To overcome these limitations, data are collected from the pre-operational program and from the results of the background (con-trol) sampling stations in the operational program to supply a spatial and temporal baseline for comparison with indicator analytical results. I' Any changes in circumstances that have a bearing on the design V) of the program will be assessed. An annual census of milk animals i and vegetable gardens producing broadleaf vegetation will be conducted to determine the nearest milk animal and vegetable garden in each of the 16 meteorological sectors around the plant. This census will be limited to a radius of 5 miles. The tentative operational monitoring program is a direct continua-tion of the preoperational program described in Section 6.1.5. Analytical sensitivities for the reqaired analyses will be updated to comply with changing regulations as appropriate in the future. Quality assurance to support the validity of the results of the radiological program will be provided as required beginning with the preoperational program. The laboratory performing the analyses will follow the quality control procedures recom-mended in NRC Regulatory Guide 4.15, Revision 1,III and partici-O x_/ l l l 6.2-1 i
pate in the EPA-sponsored interlaboratory cross-check program (]) or a recognized equivalent. Data collected from the environmental radiation monitoring program will be reported by the contractor laboratory within 30 days of the end of the calendar quarter. If abnormal values are observed, they will be reported to the responsible utility person-nel immediately, and steps will be taken to confirm the results. Confirmed results that ire not attributable to a cause other than reactor operation and that are in excess of the limits defined in Table 4 of heference 2 or other applicable limits will be reported to the appropriate NRC office within 30 days of the end of the gnarter. An annual report will be submitted by May 1 of each year. This report will contain the summarized results of the radiation-monitoring program. The results of each analysis will be averaged separately for indicator and control locations. The means and O) g ranges (minima and maxima) will be listed, along with similar parameters for the location with the highest annual mean. The proportion of the total number of analyses with the detectable results will be given, and the number of nonroutine reports issued will be listed. The results will be discussed, and the monitoring program, sampling, and laboratory methods will be described. 6.2.2 NONRADIOLOGICAL SURVEILLANCE Nonradiological surveillance will be described in proposed environ-mental technical specifications. It is anticipated that this program will include an annual, general ecological survey to determine possible effects of plant operation on important vegeta-tion and wildlife. Operational meteorological monitoring is expected to occur, as well as periodic water quality surveillance. 6.2-2
() REFERENCES FOR SECTION 6.2
~~1. U.S. Nuclear Regulatory Commission, Regulatory Guide 4.15,~~
~~" Quality Assurance for a Radiological Monitoring Program (Normal Operations - Ef fluent Stream and the Environment) ,"~~
~~4 Revision 1, February 1979.~~
~~2. U.S. Nuclear Regulatory Commission, Radiological Assessments Branch, An Acceptable Radiological Environmental Monitoring Program, Branch Technical Position Paper, March 1978.~~
}
~~i e i~~
~~.O 6.2-3 l l~~
i 6.3 RELATED ENVIRONMENTAL MEASUREMENT AND MONITORING PROGRAMS No known environmental measurement and/or monitoring programs , are being carried out at or near the PNPP by public or other
~~agencies other than those directly supported by the applicant.~~
~~5 l .] l~~
~~;O l~~
~~f 1~~
~~O 6.3-1~~
i i 6.4 PREOPERATIONAL ENVIRONMENTAL RADIATION MONITORING DATA J Preoperational environmental radiation monitoring has not been l initiated. These data (for 6-12 months) will be submitted as a supplement when available. e i 1 1 i i f O i i l 4 1 lO i 6.4-1 _ . _ _ . . _ , . . . _ . . . . - . . _ _ _ . . , _ _ , _ _ _ _ _ . . , , , . _ . _ _ _ - , . - - , . - - , _ . , _ . , _ _ _ , . . . , - . - , . . . . . . _ . ~ . . .
CHAPTER 7 ENVIRONMENTAL EFFECTS OF ACCIDENTS This chapter provides a discussion of environmental effects of accidents involving the station. 7.1 STATION ACCIDENTS INVOLVING RADIOACTIVITY t The effects of station accidents involving radioactivity were reported in the ER/CP and have been reconsidered in light of NRC-revised dose methodology and in terms of the additional meteorological data.I } The results of the revised analysis are presented in Table 7.1-1, along with the corresponding results from the prior analysis. The most severe accident, considering whole body dose, is the control rod drop accident (Class 8.2 (b) ) . This accident also delivers the highest whole body population dose to persons living within 50 miles of the plant site. The accident which results
.in the highest thyroid dose at the exclusion area boundary is a loss-of-coolant accident with a large pipe break (Class 8.1) . t Thus, the maximum doses r'esulting from potential accidents at the Perry Nuclear Power Plant using realistic accident parameters j ar.e as follows:
~~Individual Whole Body Dose 8.0x10 -3 rem Whole Body Population 43 man-rem~~
-2 Thyroid Dose (Inhalation) 8.3x10 rem These doses can be put into perspective by comparing them with annual doses received by individuals from exposure to natural background radiation.. NCRP Report No. 45,(2) " Natural Background Radiation in the United States," reports the annual background dose rate to the thyroid of 0.08 rem and provides information
("T to indicate an annual background dose rate to the whole body s_/ 7.1-1
on the order of 0.1 rem. The maximum dose to the whole body i resulting from poten tial accidents at the Perry Nuclear Power Plant is about an order of magnitude lower than from background radiation; the maximum dose to the thyroid is about equal to that from background radiation. In summary, the estimated environmental effects of accidents in both the ER/CP and in the present analysis are very small. O l [ t } l ( 7.1-2
5 f i REFERENCES FOR SECTION 7.1
~~1. NUS Corporation, Accident Dose Asssessment, Perry Nuclear Power Plant, NUS-3459, October, 1979.~~
i
~~2. NCRP, Natural Background Radiation In The United States, NCRP Report No. 45, National Council on Radiation Protection and Meacurements, Washington, D.C., November 15, 1975.~~
i f i, i 4 O 5 r O l l 7.1-3 l l
o o o TABLE 7.1-1 SIM4ARY OF DOSES DUE 'IO ACCIDENTS Whole Body Dose Thyroid Dose Maximum Exclusion Population Dose Maximum Exclusion Area Boundary 50 Miles Area Boundary (rem) (man-rem) (rem) Accident ER/CP Present ER/CP Present ER/CP Present Class Description Result Result Result Result Result Result
~~1. 0 (a) Trivial Accidents - - - - - -~~
2.0 (a) Small Releases Outside Containment - - - - - - 3.0 Radwaste System Failures 3.1 Equipment Leakage or Malfunction - 0 - 0 1. 3 (-5) 6.8(-5) 3.2 T.ow Temperature RECHAR Rupture (c) 1. 0 (-3) (b) 1.0(-3) 1. 2 (+1) 4.9 2. l (-6 ) 1. l (-5 ) 3.3 Release of Liquid Waste Storage Tank Contents - 0 - 0 5. 4 (-5) 2. 8 (-4) 4.0 Fission Products to Primary System (BWR) [ 4.l(a) Fuel Cladding Defects - - - - - - 4.2 Off-Design Transients That Induce Fuel Failures Above Those Expected 7. 3 (-4) 6.4 (-3) 8.7 3. 5 (+1) 7. 3 (-4) 2. l (-3) 5.0 (e) Fission Products to Primary and Secondary System (PWR) - - - - - - 6.0 Refueling Accidents 6.1 Fuel Bundle Drop 1.5(-4) 5.0(-5) 1.8 2.9 (-1) 9. 6 (-6) 4. l (-5) 6.2 Heavy Object Drop Over Fuel in Core 1. 7 (-3) 5.8 (-4) 2. 0 (+1) 3.4 9.9 (-5) 4.2(-4) 7.0 Spent Fuel Handling Accidents 7.1 Fuel Assembly Drop in Fuel Storage Pool 1. 5 (-4) 5.0 (-5) 1.8 2. 9 (-1) 9.6 (-6) 4. l (-5) 7.2 Heavy Object Drop Onto Fuel Cask 8. l (-5) 2.0(-5) 9. 6 (-1) 1. 2 (-1) 1.0(-5) 4. 5 (-5) 7.3 Fuel Cask Drop 6.9 (-4) 1. l (-5) 8.3 6.7 (-2) - 0 8.0 Accident Initiation Events Considered in SAR
l 8.l(a) LOCA(d)-Small Pipe Break 1.0(-9) 6. 4 (-9) 1.2(-5) 3. 5 (-5) 6.0(-8) 4. l (-7) l 8.l(a) LOCAId)--Large Pipe Break 8. 3 (-4) 3.3(-3) 7.8 1.6 (+1) 1. 0 (-2) 8.3(-2) i
o o o TABLE 7.1-1 (Continued) St29tARY OF DOSES DUE 'IO ACCIDENTS Whole Body Dose Thyroid Dose Maximum Exclusion Population Dose Maximum Exclusion Area Boundary 50 Miles Area Boundary (rem) (man-rem) (rem) Accident ER/CP Present ER/CP Present ER/CP Present Class Description Result Result Result Result Result Result , 8.la(*) Break in Instrument Line From Primary System That Penetrates the Containment - - - - - - 8.2a(e) Rod Ejection Accident (PWR) - - - - - - 8.2b Rod Drop Accident (BWR) 9. l (-4) 8. 0 (-3) 1. l (+1) 4. 3 (+1) 9. l (-4) 2. 6 (-3) 8.3a(e) Steamline Breaks (PWR) - - - - - - 8.3b Small Steamline Break 9.9 (-6) 9.4(-6) 1. 2 (-1) 5.6 (-2) 7.9 (-5) 2. 0 (-4) , 4
~~, 8.3b Large Steamline Break 7.6(-6) 7. 2 (-6) 9. 0 (-2) 4. 3 (-2) 6. 0 (-5) 1. 5 (-4)~~
H
~~, & (a) Incidents included and evaluated under routine radioactive releases contained in Section 5.~~
(b) 6.8 (-5) = 6.8 x 10-5 (c)In ER/CP, this accident is referred to as " Release of Waste Gas Storage Tank Contents." (d)LOCA = Loss of Coolant Accident. (*)Not applicable for BWR. l 1 I 4 i 1
7.2 TRANSPORTATION ACCIDENTS INVOLVING RADIOACTIVITY O The transportation of fuel and wastes is within the scope of paragraph (g) of 10 CFR Part 51.20; the impacts of transportation
~~, are therefore as set forth in Table S-4 of 10 CFR Part 51.~~
~~(See Section 3.8 for the scope of paragraph (g).) O O 7.2-1~~
~~~ . , .~~
7.3 OTHER ACCIDENTS O The consideration of other accidents is unchanged from the ER/CP. l l l 1 I O O i 7.3-1
{} CHAPTER 8 ECCNOMIC AND SOCIAL EFFECTS OF PLANT OPERATION 8.1 BENEFITS 8.1.1 PRIMARY BENEFITS Perry Units 1 and 2 will be operational in 1984 and 1988 respec-tively, and will generate an average of 2410 megawatts (MWe) (net) reliable baseload electrical power for the area served by CAPCO. The breakdown of ownership by percentages for PNPP Units 1 and 2 is as follows: the Cleveland Electric Illuminating Company, 31.11 percent; the Ohio Edison Company, 35.24 percent; the Toledo Edison company, 19.91 percent; and the Duquesne Power
~~& Light Company, 13.74 percent.~~
l The purpose of the PNPP is to generate economical electrical I power. The PNPP is needed to meet the expected increase in the demand for electricity. The expected growth in the economy, aims of higher productivity and better working conditions in industry, an increase in the number of persons entering the labor and housing markets, and conversions to electricity from oil and gas (for reasons of economics and environmental protection) are among the factors contributing to the need for increase in the supply of electrical energy. Concern about protecting the environment from air pollu-tion is a factor favoring the use of nuclear reactors rather than coal-fired plants to produce this electrical energy. On the other hand, because of ecological concerns, higher nonpromo-tional. electricity rates, smaller families, energy conserva-tion through decreased use, better insulation, and appliances that are more energ'y efficient, the total growth in electricity sales by CAPCO is expected to moderate from the 6.5 percent {} annual rate experienced between 1963 and 1973 to 2.9 percent l l 8.1-1 i i
for the period 1974 to 1988. The total sales predicted by custo-mer class for CAPCO and for each CAPCO company for the period (]) 1984 to 1988 are shown in Tables 8.1-1 and 8.1-2, respectively. The figures presented in these tables do not include a system loss of 6 percent. The total revenues from elcctricity sales for CAPCO are also shown in Table 8.1-1. If an average capacity factor of 68.0 percent is assumed, the PNPP is expected to generate approximately 14.3 billion kilowatt-hours (kWh) annually (Table 8.1-3). According to 1989 projected data, approximately 3.4 billion kWh will go to residential custo-mers, 3.1 billion kWh to commercial customers, 7.0 billion kWh to industrial customers, and 0.7 billion kWh to street lighting, other public authorities and sales for resale. The primary benefit of the proposed plant lies in the 14.3 billion kWh of electricity to be delivered to the customers over its operational lifetime (30 years). This can also be represented () by an annual revenue of $280,143,170 in 1984, which will rise to $895,100,000 in 1988, as shown in Table 8.1-3. In 1989, the revenue will rise to S1,138,400 with Units 1 r.nd 2 on line the full year. The revenue for 1989 represents tue annual value for the remaining years of operation. This value is based on the rate structure in effect as of May 1980 with fuel clause rates in effect at that time. The 30-year primary benefit from both PNPP units is $6,489,700,431 in 1984 dollars. No sales of steam or other products or services from the plant are anticipated. Information on the primary benefits of the plant is listed in Table 8.1-4; however, there are also other benefits which can be described qualitatively. The benefits in averting the regional social and economic impacts of electricity shortages can be qualitatively described by the ('/l x-l 8.1-2 I
~
effects that an inadequate reserve capacity can have on the region served. A very real concern is the negative effect on (]} the expansion plans of industrial users who depend on a power system that is projected to have a deteriorating or uncertain level of reliability in the long term. An inadequate energy supply discourages existing industry from remaining in the area j or expanding, and it discourages new industry from locating in the area. Concerns have been expressed that Ohio is suffering an industrial decline. If projections of that decline are used as an excuse to install less future capacity, it becomes a self-
~~fulfilling prophecy.~~
l
~~. If reliability is degraded to the point that electrical service~~
must be interrupted, the resultant direct and immediate impact on employment and production is obvious. Lost wages and lost production may never be recovered. It would also impose enormous inconvenience to the public, as vital services would have to be curtailed, possibly jeopardizing health and safety.
iO Chapter 1 (Section 1.1.4.3) discusses the economic cost of delay-ing the startup of PNPP Units 1 and 2. - 8.1.2 OTHER SOCIAL AND ECONOMIC BENEFITS 8.1.2.1 Property Tax Revenues The PNPP will substantially increase the tax base of the local governmental jurisdictions in which it is located and will repre-sent a significant new source of tax revenues. Based on the assumption that a projected effective tax rate of 2.54 percent applied to the assessed value of real and personal property will continue to apply over the 30-year life of the facility, the total annual present worth of real and personal property taxes will ataunt to approximately $108,174,211 in 1984 dollars. Table _8.1-5 shows the total tax revenues generated from real (~T property, personal property, and nuclear fuel. G 8.1-3 L t
~~. ._. ._,,_~ _ _ _ _ ., -._._. _ = _ _ - - ._ . _ , - _ _ . . _ , .~~
In addition to local property tax revenue, the State of Ohio (]) will realize an average annual excise tax of $8,220,000 (in 1984 dollars) through taxes on the sale of electricity and pur-chases; the State and Federal Government will jointly realize an average annual Federal and State income tax of $35,314,855 (in 1984 dollars) paid by CAPCO on the sales of electricity generated by the PNPP. Finally, local jurisdictions as well as the State of Ohio and the Federal Government will realize 2x revenues through the collection of personal income taxes s the PNPP operational work force. These tax revenues are discussed in the subsection that follows. 8.1.2.2 Payrolls and Employment The total cost of plant construction is expected to be approxi-mately $2.092 billion in 1984 dollars. () U The projected average wages in 1980 dollars for the 317 persons who comprise the operating staff of the PNPP are broken down as follows: 51 persons with an annual average wage of $33,600; 146 persons with an annual average wage of $27,100; 102 persons with an annnual average wage of $22,600; and 18 persons with an annual average wage of $15,500. Assuming a 7.5 percent annual increase in the average annual wages for the period 1980 to 1984, the present worth of the payroll in 1984 dollars is esti-mated to be approximately $84,096,614. From the operating payroll, personal income taxes will be realized by municipalities, the State of Ohio, and the Federal Government. The estimated present worth in 1984 dollars of Federal income tax paid by the operating personnel will approximate $10,306,579, assuming 1979 tax rates. The present worth of State income taxes paid by the operating personnel is estimated at approxi-
~~~T (J mately $1,670,718 (in 1984 dollars) . In addition to Federal 8.1-4~~
and State income taxes, a municipal income tax will also be {) paid by the operating personnel; it will be paid at a varying rate, depending on the residence of the employee. The present worth of municipal taxes on income is estimated to be approxi-mately S678,968 (in 1984 dollars). 8.1.2.3 Enhancement of Environmental, Aesthetic, and Recreational Values, and Improvement of Roads The operation of the PNPP will core.ibute to knowledge of the environment. This contribution will result from environmen'al monitoring activities conducted to obtain a permit under the National Pollutant Discharge Elimination System and to meet other requirements of the Environmental Protection Agency and Nuclear Regulatory Commission. In addition, che Applicant has taken steps to improve the recrea-tional nature of the area by leasing 23 acres of company-owned land (adjacent to the PNPP site) to the Lake County Metropolitan [} Park System. The land is located north of Parmly Road just west of the Neff-Perkins Plant and adjacent to, but not part of, the PNPP site property. 8.1.2.4 Fuel Oil Conservation The construction of PNPP Units 1 and 2 will result in a signifi-cant savings in crude oil. As depicted on Table 1.3-17 and discussed in Section 1.3.3.5, a 1-year delay in the operation of PNPP Unit 1 will result in the use of an additional 238.7 million gallons of No. 2 and No. 6 oil; a 3-year delay in Unit 1 will result in the use of an additional 738.4 million gallons, assuming that the same customer load will be served in all cases. O v
^:
8.1-5 i i t-
O O O TABLE 8.1-1 CAPCO (COMBINED) GENERATION AND REVENUE FORECAST BY CUSTOMER CLASS (1984 TO 1988) Generation = (MWhr) Revenue (a) . (g} Year Customer Class (FPC Acct. No.) 1984 1985 1986 1987 1988 440 Residential 17,920,218 18,327,957 18,771,102 19,218,129 19,647,337 442 Commercial 15,902,830 16,433,290 16,967,380 17,465,230 17,982,410 442 Industrial 35,397,772 36,597,068 37,709,181 38,955,407 40,322,530 444 Street Lighting 515,633 523,013 530,487 536,854 543,212 445 Other Public Auth. 789,659 802,186 815,089 828,379 842,067 446 Railroads 447 Sales for Resale 2,575,544 2,638,244 2,704,044 2,768,844 2,837,044 Total Sales 73,101,656 75,321,758 77,497,283 79,772,843 82,174,600 Total Revenue (a) ($) 4,279,729,000 4,686,505,000 5,205,361,000 5,622,893,000 6,148,670,000 co (a) Revenue forecast is based on the May 1980 rate structure with the fuel clause rates in ef fect O' at the time. 4
o o o TABLE 8.1-2 CAPCO (BY COMPANY) SALES FORECAST BY CUSTOMER CLASS (1984 TO 1988) (Megawatt Hours)
a. Clevelarid Electric Illuminating Company Year Customer Class (FPC Acct. No.) 1984 1985 1986 1987 1988 440 Residential 4,814,900 4,914,500 5,014,700 5,115,500 5,216,700 442 Commercial 4,617,400 4,756,000 4,898,600 5,045,600 5,197,000 442 Industrial 10,853,200 11,189,100 11,536,800 11,896,700 12,269,100 444 Street Lighting 153,500 155,000 156,600 158,200 159,800 445 Other Public Auth. 310,000 310,000 310,000 310,000 310,000 446 Railroads 447 Sales for Resale 469,000 478,000 488,000 498,000 508,000 Total Sales 21,218,000 21,802,600 22,404,700 23,024,000 23,660,600 m

b. Duquesne Light Company 440 Residential 3,010,000 3,040,000 3,110,000 3,180,000 3,220,000 442 Commercial 4,215,000 4,345,000 4,475,000 4,565,000 4,615,000 442 Industrial 7,980,000 8,230,000 8,450,000 8,79C,000 9,180,000 444 Street Lighting 115,000 115,000 115,000 115,000 115,000 445 other Public Auth. 40,000 40,000 40,000 40,000 40,000 446 Railroads 447 Sales for Resale 10,000 10,000 10,000 10,000 10,000 Total Sales 15,370,000 15,780,000 16,200,000 16,700,000 17,180,000 4
~~~ %/~~
~~TABLE 8.1-2 (Continued) CAPCO (BY COMPANY) SALES FORECAST BY CUS'IOMER CLASS (1984 20 1988) (Megawatt Hours)~~
c. Ohio Edison Company Including Pennst 'Ivania Power Company Year Customer Class (FPC Acct. No.) 1984 1985 1986 1987 1988 440 Residential 7,828,300 8,056,000 8,279,000 8,500,900 8,729,500 442 Commercial 5,537,700 5,717,400 5,904,800 6,094,200 6,294,100 442 Industrial 11,895,000 12,289,300 12,682,400 13,049,000 13,434,100 444 Street Lighting 185,600 190,600 195,600 199,500 203,400 445 Other Public Auth. 9,300 9,300 9,300 9,300 9,300 446 Railroads 447 Sales for Resale 1,433,000 1,486,700 1,542,500 1,597,300 1,655,500 Total Sales 26,888,900 27,749,300 28,613,600 29,450,200 30,325,900 co e d. Toledo Edison Company b 2,267,018 2,317,457 2,367,402 2,421,729 2,481,137 440 Residential 442 Commercial 1,532,730 1,614,890 1,688,980 1,760,430 1,876,310 442 Industrial 4,669,752 4,888,668 5,039,981 5,219,707 5,439,330 444 Street Lighting 61,533 62,413 63,287 64,154 65,012 445 Other Public Auth. 430,359 442,886 455,789 469,079 482,767 446 Railroads 447 Sales for Resale 663,544 663,544 663,544 663,544 663,544 Total Sales 9,624,936 9,989,858 10,278,983 10,598,643 11,008,100
o o o TABLE 8.1-3 PNPP GENERATION AND REVI!NUE FORECAST BY CUSTOMER CLASS (1984 'IO 1988) Generation (a) = (mihr) - RevenueID) =($) Year Customer Class 1984 1985 1986 1987 1988 Residential 1,427,728 1,597,877 1,572,657 2,093,072 3,101,779 commercial 1,267,000 1,432,696 1,421,540 1,902,162 2,838,932 Industrial 2,820,188 3,190,625 3,159,304 4,242,686 6,365,828 Street Lighting 41,081 45,597 44,445 58,469 85,758 O ther 62,913 69,937 68,289 90,220 132,939 Sales for Resale 205,197 230,009 226,547 301,559 447,892 Total Generation (a) 5,824,107 6,566,741 6,492,782 8,688,168 13,973,128 Total Revenue (b) ($) 280,143,170 446,610,000 482,140,000 505,970,000 895,100,000 Y e (a)No ef fect of system losses was taken into account. Based on a 68% plant capacity factor. (b) Revenue forecast is based on current (May 1980) rate structure, i l
TABLE 8.1-4 ANNUAL BENEFITS FROM PNPP UNITS 1 AND 2 DIRECT BENEFITS Expected Average Annual Generation (a) 13.0 x 109 kWh/yr Capacity 24.1 x 106 kWe Proportional Distribution of Electrical Energy Expected: Idust rial 6.4 x 109 kWh/yr Commercial 2.8 x 109 kWh/yr Residential 3.1 x 109 kWh/yr Other 0.7 x 109 kWh/yr Expected Average Annual Steam Sold frcxn the Facility 0 Expected Average Annual Delivery of Other Beneficial Products O Pevenues (b) frcza Delivered Benefits: Electrical Energy Generated $346.2 x 10 6 /yr Steam Sold 0 Other Products 0 INDIRECT BENEFITS Annual Taxes (b) Local $108.9 x 10 6 /yr State & Federal $55.5 x 10 6 /yr . Environmental Enhancement Recreation Lease or 23 acres for park Navigation None Savings of burning oil (c) 190 x 106 gal /yr Air Quality Reducing associated emissions into the atmosphere associated with burning oil Environmental Monitoring Meteorological, Ecological, Radiological Operating Employment. 317 people (a) Based on 68.0 percent plant capacity factors. (b) 1984 dollars. (c) Represents increased running of peaking units if PNPP not in service. In practice the availability of PNPP for base load will probably save additional fossil fuels which would have been consumed in some base-load fossil plants. 8.1-10
TABLE 8.1-5 t U ESTIMATED REAL AND PERSONAL PROPERTY TAXES FOR PNPP Real Personal Nuclear Property (a) Property (b) Fuel i 1988 Year-End Investment: 99,720,031 1,496,552,239 238,000,000 Year-End Tax Valuation Rate: 35% 50% 50%
~~$34,902,011 $ 748,276,120 $119,000,000 Taxes (d)~~
Real Personal Nuclear Tax Rate (c) Property Property Fuel County $ 6.40 223,378 4,789,070 761,616 School 16.00 558,432 11,972,418 1,904,000 7111 age 3.00 104,706 2,244,828 357,000 Total $25.40 886,516 19,006,316 3,022,616 Present worth based on $6,763,142 $144,997,284 $23,0e3,235 30-year plant life (*) Total present worth (*) = $174,819,661 in tax revenues over the life of the plant [ N- ' (a)Real Property is made up of land and structures. (b) Personal Property is the remainder of taxable property in PNPP, excluding fuel. (c) Tax rates are estimates of rates in North Perry Village after comple-tion of PNPP. (d)The estimate is based on practices and procedures of the Ohio Depart-ment of Taxation as of year 1979. (e)The present worth factor to 1988 at 12.75% equals 7.6289 for the 30-year life of the plant. (\_)h i 8.1-11
8.2 COSTS O
~~\~/~~
8.2.1 INTERNAL COSTS PNPP Unit 1 is to be operational for 29 years and Unit 2 for 33 years. In developing operational costs, a 30-year average operational life was used. As summarized in Table 8.2-1, the primary costs associated with the construction and operation of PNPP include:
1. The total cost of plant construction is estimated to be $2,092 million (in 1984 dollars). This value is a sunk cost incurred whether or not the plant is ever operated.

2. The total cost of fuel for the plant over its operating life, is estimated to be $1,544.5 million (in 1984 dollars) , or an average of 3.626 mills /kWh.
(}
3. The projected operation and maintenance costs are expec-ted to rise from $17.4 million in 1984 to $32.6 million (in 1984 dollars) in 1988. The total annual levelized operating and maintenance costs are estimated to be
~~$83.0 million per year. The present value of operation and maintenance costs expressed in 1984 dollars is i~~
~~calculated to be $741.1 million.~~
~~4. There is an NRC fee of $1.243 million for the construc-tion permit and an estimated fee of $1.327 million for the operating license for the two custom units.~~
In addition, under the current schedule, annual NRC operating fees amount to approximately $160,000; thus the total NRC operating fees over the life of the facili-ty will be approximately $1.22 million in 1984 dollars. O v 8.2-1
The above fees are in accordance with the current schedules (~) published in 10 CFR Part 170.I1)
%)
5. Plant decommissioning alternatives and costs are discussed in Chapter 5, Section 5.8. For the purpose of calculating internal costs, the highest cost alternative, mothballing with delayed dismantlement, is used. The estimated cost for this alternative for the two-unit PNPP is
$142 million in 1978 dollars. Expressed as a present worth cost in 1984 dollars using an average Gross National Product deflator value of 6.5 percent for the period 1978 to 2014, the estimated cost for decommissioning is $37.4 million.
~~6. Research and development costs associated with operation and maintenance are included in the overall operation and maintenance costs (i.e. , cost element 3 above) .~~
( } As shown in Table 8.2-1, the present worth in 1984 dollars of the total primary internal operational cost for the anticipated 30-year operational life of the plant is $2.33 billion and the total cost in 1984 dollars is $4.42 billion. As indicated in Section 8.1.1, the corresponding present worth of the primary benefits is $6.49 billion. Hence, the present worth value in 1984 of the net primary benefits of the PNPP is approximately
~~$2.07 billion.~~
8.2.2 EXTERNAL COSTS Present forecasts indicate that 317 personnel will be employed at the PNPP during its operation. Some of the operating personnel have already been hired; they comprise 20 percent of the total work forc-e to be employed at the PNPP. More than half of this work force relocated from (')
~~\_/~~
outside the local area, two-thirds were married, and most moved 8.2-2 1 t- _. l
significant distances averaging more than 500 miles per family. (]) However, many of these persons are nuclear specialists and techni-cal personnel who came from military service. Thus, the distance factor may not apply to the entire work force. Rather, it is expected that a significant portion of the operating work force will be filled by personnel trcnsferring from other CEI facilities who will not relocate or new employees from the local area. Assuming that the same ratio of relocating workers, marital status, and family size applies to the remainder of the work force, 174 persons can be expected to relocate in the vicinity of the PNPP. Approximately 116 of these relocating workers will be married with two children per family, with the number of school students increasing by one per family. From CEI experience with the Eastlake Generating Plant, it is expected that approximately 8 to 10 percent of the total increase in projected population and school enrollment will directly I ) affect Perr/, Ohio. In consideration of past school enrollment
~~'% J and population, this increase is considered to be insignificant.~~
~~These external effects that are expected to be induced by the operation of the PNPP are discussed in Chapter 5. '} l f a n-m i 8.2-3~~
~~REFERENCE FOR SECTION 8.2 I~~
! 1. U.S. Nuclear Regulatory Commission, Fees for Facilities and > Materials Licenses and Other Regulatory Services Under the Atomic Energy Act of 1954, as Amended, 10 CFR, Part 170, September 1, 1978. i i i !O l O l 8.2-4 \
f TABLE 8.2-1 3^ PNPP INTERNAL COSTS OVER 30-YEAR OPERATIONAL LIFE j Description Cost (1984$) Plant Cost 2,092.0 x 106 Fuel 544.5 x 106 Operation & Maintenance 741.1 x 106 NRC Fees 1.3 x 106 NRC Operating License 1.3 x 106 NBC Annual Operating Fees 1.2 x 106 Decommissioning 481.2 x 106 Total 3,862.6 x 106 i 4 -I i i a 3 i i i I iO 8.2-5 t-I _, _ . .., __-, , _ . .~. . , _ -- . m_._ _ - .,--- - _
CHAPTER 9 (} ALTERNATIVE ENERGY SOURCES AND SITES l This chapter presents the basis for the choice of site and nuclear fuel from among available alternatives.
~~-9.1 ALTERNATIVES NOT REQUIRING THE CREATION OF NEW GENERATING j CAPACITY 9.1.1 PURCHASE OF ENERGY REQUIREMENTS i~~
The CAPCO planning criterion is that " sufficient' capacity shall i be provided so that the dependence on generation reserves outside i the CAPCO Group shall not, unless unanimously otherwise agreed, i exceed one day per calendar year." (See Section 1.1.2.2). The current projection of dependence on supplemental capacity resources (on Table 1.1-11) indicates that this criterion will
~~- not be met for the years 1984 through 1992. Therefore, the 4~~
(} predicted purchases of power with PNPP on schedule exceed that ! required tar the planning criterion and making t4? the power from PNPP by purchases'is clearly not possible. 9.1.2 USE OF FACILITIES PRESENTLY WITHIN THE SYSTEM j Increased use of present facilities could include reactivation of old plants, continued use of plants scheduled for deletion or rerating, or base-load use of peaking facilities. However, l these alternatives are not feasible. i Although CAPCO has effected or scheduled 795 MWe of capacity for deletion or rerating (Table 1.1-10) in the period 1973 to
~~' 1982,'actually onlyz a reduction of 676 MWe would occur because~~
!~ . some: facilities were scheduled'to be up-rated (Table 1.1-9). This reduction in capacity is due to actual base-load capabilities () of the facilities and-to pollution-control and environmental-f E 9.1 .
~~,,.~: - , . - + - +,e * * * - * " -* -*-m~t*--i -"-*-~~
v e- e --- , - - - ~ w-, - w -,.rv-,nv-rg2an-,-g- .% t----1'* w r er-
protection requirments in the case of fossil-fired facilities. In some cases modification to be responsive to requirements (]) was either physically impossible or economically impractical. In other cases, additional capacity is available only for emer-gency peaking after which extensive maintenance or facility shut down may be required. Therefore, neither reactivating old plants nor continuing the use of plants scheduled for rerating are practical alternatives. The CAPCO system projects that the peaking capacity during the years 1984 through 1985 will be 821 MWe (Table 1.1-7). However, the peaking capacity would only be available for non-peak days since the peaking capacity has already been included into the probablistic assessment of the need for power (Chapter 1). Hence, continuous operation of peaking facilities cannot offer a possible alternative. 9.1.3 CONSERVATION O In recent years, the consumption of electrical energy has been moderated by various conservation measures. The load forecast in Chapter 1 takes this fact into account; the effect is a reduc-tion in the expected rate of increase in the demand for electric-ity from that projected in the ER/OL. As shown in Chapter 1, however, conservation does not negate the need for the PNPP. () 9.1-2
l 9.2' ALTERNATIVES REQUIRING THE CREATION OF NEW GENERATING CAPACITY O
Questions related to the use of other fuels or other sites to

produce the electricity needed in the period immediately after the PNPP is planned to go on line are moot because such other systems at other places cannot be built in the time available.
~~i l I i ) l t 4~~
~~O i~~
~~I O 9.2-1~~
~~. = . .. . __ _. --~~
9.3 COST-EFFECTIVENESS ANALYSIS OF CANDIDATE SITE-PLANT ALTERNATIVES 4 Since a capital investment in the PNPP has already been made or committed, it is clear that possible alternative site-plant combinations with the required additional capital investments could not compete with the PNPP in terms of cost effectiveness. 3 l O l
~~) \~~
O 4 f 9.3-1
l 1
~~. i i~~
9.4 COSTS OF ALTERNATIVE POWER-GENERATION METHODS O Since a capital investment has already been made or committed to the PNPP, the production of replacement electricity by some other method would have to be burdened by this capital investment. The costs of alternative power-generation methods would, therefore, j be substantially greater than those of the PNPP. 1 i i i i i O i i O 9.4-1 I
CHAPTER 10 (]) _ STATION DESIGN ALTERNATIVES l No new station desig.. alternatives have been considered since ! the submittal of the ER/CP except for the cooling towers which are now part of the heat dissipation system. i i With regard to liquid and gaseous radwaste systems, the applicant f has elected to exercise the option cited in the September 9, 1975, amendments to Appendix I of 10 CFR Part 50 and has not j performed the cost / benefit analysis described in paragraph II.D i I of Appendix I. l 1 I l l O 4 i l l I i-0 l 10.1-1 l I - , ._ , _ . _ . , . , . , _ , _ , , - - , . . . _
CHAPTER 11
~~SUMMARY~~
~~COST-BENEFIT ANALYSIS~~
~~11.1 INTRODUCTION~~
This chapter presents a summary cost-benefit analysis, which shows the aggregate benefits of the PNPP outweigh the aggregate costs. This conclusion is derived from analyses of'(1) the need for electrical energy, (2) the socioeconomic and social benefits and costs of operating the PNPP, and (3) the environ-mental impacts of operating the PNPP. 4 O I 1 l l I 11.1-1
I 11.2 BENEFITS l 11.2.1 DIRECT BENEFITS The direct benefits of the PNPP, as indicated in Section 8.1, will be the generation of an average of 14.3 billion kilowatts of electrical energy annually for use in the participants' service areas. Chapter 1 demonstrates that in the 1980s there will be a need for new generating capacity in the areas served by the PNPP and the CAPCO pool. This generating capacity will be necessary to meet forecastad load demands and to retain the reserve margins required for reliable service. 11.2.2 INDIRECT BENEFITS , Numerous indirect benefits will be derived from the operation of the PNPP, as discussed in Section 8.1: o (v) In the local jurisdictions, the PNPP will annually provide more than $100,000,000 in revenues in the form of real and personal property taxes. In addition, it will provide Federal and state " tax revenues, and through its payroll it will indirectly produce addition-al personal income tax revenue. (See Section 8.1. 2. ) o The PNPP will employ more than 300 operating personnel and provide an annual payroll of more than $92,000,000. (See Section 8.1.2.) o As a consequence of the jobs directly created by operat-ing the PNPP, new jobs and employment-will arise in the regional industrial and service sectors. o Regional and economic impacts of electricity shortages will be averted. l l (~>T l l l 11.2-1
o The'PNPP will result in an annual savings of 190 million gallons of oil because it will not be necessary to (]) continuously operate existing oil-fired peaking units. , (See Section 8.1. 2. ) Moreover, to produce the electri-cal energy generated by the PNPP through the combustion of nonrenewable fossil fuels would require approximately 21 million barrels of oil or 5 million tons of coal per year. j o The recreational park to be leased by the Applicant i will enhance the environment in the area of the site. Furthermore, the environme- al monitoring to be con-ducted by the Applicant v i add to the knowledge of the environmental characteristics and resources < of the area. O O i
~~s l~~
~~l l~~
-g*
(_/ 11.2-2 L
11.3 COSTS O 11.3.1 DIRECT COSTS The direct costs of the plant (see Section 8.2) will be borne by the customers within the participants' service areas. 11.3.2 INDIRECT COSTS 11.3.2.1 Socioeconomic Impacts The operation of the PNPP will not result in any significant socioeconomic impacts. The number of operational employees and their families is too small to significantly affect local public services, including schools. i 11.3.2.2 Environmental Impacts O ( j The environmental impacts expected from the operation of the PNPP (Chapter 5) are summarized in Table 11.3-1. It should be noted that no significant impact on the biotic community is expected from the operation. The overall environmental impacts of the PNPP will be small and temporary. l l l l l
~~~s '~~
11.3-1
O n v O TABLE 11.3-1 PREDICTED IMPACTS OF PNPP OPERATION ON THE ENVIRONMENT ER/OL Section Resource Affected Description Reference Type of Impact Aesthetics External 3.1 External appearance of station shielded by mature Appearance trees along many roads, minimized to small degree from Lake Erie. Smooth hyperbolic contours of cooling towers dominate. Land Use Operating Plant 4.1 Although about 1,000 acres will be within the plant site boundary, only about 25 percent will be con-struction areas. Lake Erie Water Discharge 5.1.1 Water quality within Ohio Water Quality Standards. 5.1.1 Thermal discharge of 6.85 x 106 Btu / minute within temperature change standards. U 5.3.1 Slight decrease in dissolved oxygen; slight in-w crease in biochemical oxygen demand. 3
~~" 5.3.2 No effect on life inhabiting lake due to chemical discharge.~~
5.3.2 No buildup of chemicala in bottom sediments. 5.4 Small amounts of nutrient from treated sanitary waste will have negligible effect on aquatic life. Aquatic Biology Cooling Tower 5.1.3 Impingement of adult fish and the entrainment of Intake / Discharge fish eggs and larvae is reduced slightly in the immediate vicinity of the intake, but there is no discernible effect on Lake Erie populations. No thermal shock to fish due to shutdown. Atmosphere Cooling Tower 5.1 Release 1.7 x 1010 Btu / hour and up to 29,000 gallons / minute of water vapor and 110 gallons / minute of drift for both towers.
V ' TABLE 11.3-1 (Continued) PREDICTED IMPACTS OF OPERATION ON THE ENVIRONMDIT ER/OL Section Resource Affected Description Reference Type of Impact Atmosphere 5.1.4 Ground-level fog. None. (continued) Horizontal and Vertical Icing. No significant horizontal icing. Maximum of 7 millimeters of ice on a 60-foot elevation at a 3-mile distance for an average of 26 hours during an average winter. Elevated Visible Plume. Expected ap-proximately 220 hours / year in the immediate vicinity of the cooling towers. Offsite, the month of maximum frequency is January for 78 hours. Airports and population centers within 6 miles of PNPP to experience 4 to g 41 hours / year. The impact is lessened F- since shadowing of the sun will occur less w frequently. O Ground Deposition. The maximum deposition of dis-solved solids from drift droplets is calculated to be 0.08 pounds / acre-year at 2.25 miles ENE of PNPP. Airborne Concentrations. Insignificant levels from evaporated drift droplets. Increased Ground-Level Temperatures. Less than 0.10 F. Increased Ground-Level Humidity. Less than 0.1 percent. Terrestrial Biota Radiation 5.2.3 Negligible. Doses to biota similar to those to Exposure humans. Aquatic Biota Radiation 5.2.3 Negligible. Impact is less than same dose to Exposure h umans.
O O O TABLE 11.3-1 (Continued) PREDICTED IMPACTS OF OPERATION ON THE ENVIRONMENT ER/OL Section Resource Affected Description Reference Type of Impact Humans Radiation 5.2.4 Well within limits of 40 CFR 190 and 10 CFR 50, Exposure App. I. Liquid pathway 50-mile population dose to an adult' is 3.59 x 10-1 manrem/ year by commercial fish ingestion to the total body and 6.42 manrem/ year by drinking water to the thyroid. The maximum dose to an adult individual for the liquid pathways is 1,42 x 10-2 manrem/ year to the total body, 1.41 x 10-1 manrem/ year to the thyroid, and 4.60 x 10-2 manrem/ year to the bone. g The maximum gamma and beta air doses at the site F' boundary are 8.21 and 5.68 millirads/ year, c3 respectively. 1 The airborne pathway 50-mile popalation dose to an adult is 11.7, 29.8, and 14.1 manrem/ year, respectively, to the whole body, thyroid, and bone. The direct radiation from the facility is esti-mated at 14.0 manrem/ year at the site boundary and 1.75 manrem/ year at the nearest residence. Noise Plant Operations 5.6.2 Levels are estimated to be 56 and 55 dBA, r es pec-tively, at site boundary and nearest residence. Levels expected to be attenuated by vegetation to below EPA 55-dBA guideline. Air Quality Auxiliary Boilers 3.7.2 152,690 pounds / year of sulf ur dioxide, 27,064 and Ditsel 5.6.4 pounds / year of nitrogen oxides, 5,066 pounds / Generators year of carbon monoxide, 583 pounds / year hydrocarbons, and 3,554 pounds / year of particulates. Operation to comply with EPA. 4 d
(] Og Pi u . \g Q TABLE 11.3-1 (Continued) PREDICTED IMPACTS OF OPERATION ON THE ENVIRONMDIT ER/OL Section Resource Affected Description Reference Type of Impact Biota Transmission 5.5 No significant environmental effects as a result Line (ER/ CPS.6) of maintenance prograir.a. 2 No adverse effects due to corona noise, ozone, ground currents, etc., are expected. Material Resources Operational 5.7 20,000 tons of uranium yellowcake; 100,200 cubic Consumption feet of resins; 1,583,880 cubic feet of precoat: 139,980 tons of sulfuric acid; 1,250 tons of sodium hydroxide; 4,400 tons of sodium hypochlo-riten; 136 tons of sodium sulfite; 2 tons of ammonia; 2 tons of hydrozine; 1,900 tons of lime; g 700 tons of ferrous sulfate. H e W l Ut l
~~- - -. . . . .- .- . ._ ~ ..~~
~~11.4 CONCLUSION~~
O The generation'of electrical energy by the PNPP will ensure a reliable supply of economical electrical energy to the popula-l tion of the Applicant's service area. This energy production l 'is needed to meet the projected electricity demands of the area
~~served by the PNPP and represents the major benefit of the PNPP.~~
The environmental and socioeconomic costs of operating the PNPP 4 will be very low. i J 0 t i i l 1 t i l l 11.4-1 _ _. -. . . . . _ . _ . _ . - _ _ _ . . - _ _ _ . ~ . . - _ , . _ _ . - _ _ . . .
() CHAPTER 12.0 ENVIRONMENTAL APPROVALS AND CONSULTATION This chapter presents the licenses, permits, and other approvals of station construction and operation for Units 1 and 2 of the Perry Nuclear Power Plant required by federal, state, local, and regional authorities for the protection of the environment. 12.1 GENERAL 12.1.1 FEDERAL 12.1.1.1 Atomic Energy Commission Limited Work Authorization 1 for certain non-safety related construction on Units 1 and 2; Atomic Energy Act of 1954 as amended, and regulations under Title 10 CFR Part 50; i.ssued () October 21, 1974, and amended November 8, 1974, August 27, 1975 (NRC), and June 4, 1976 (NRC). 12.1.1.2 Nuclear Regulatory Commission Limited Work Authorization 2 for certain safety-related construc-tion on Units 1 and 2; Atomic Energy Act of 1954, as amended, and regulations under Title 10 CFR Part 50; issued December 31, 1975, and amended May 12, 1976, and September 17, 1976. 12.1.1.3 Nuclear Regulatory Commission l Construction permits (permit numberr CPPR-148 and CPPR-149) ; ! Atomic Energy Act of 1954, as amended; issued May 3, 1977. , /'N kj' 12.1-1
12.1.1.4 Nuclear Regulatory Commission y
/
Special nuclear material / material byproduct license to receive and store nuclear fuel; Atomic Energy Act of 1954, as amended; application to be filed in 1981. 12.1.2 STATE 12.1.2.1 State of Ohio Environmental Protection Agency Permit to install; Chapter EP-30 of the regulations of the Ohio Environmental Protection Agency; application number 02-074; application date June 10, 1974; permit date December 2, 1975. (~\
~~\s/~~
i l l jN [L) 12.1-2
12.2 WATER-USE AND PLANNING O 12.2.1 FEDERAL 12.2.1.1 U.S. Army Corps of Engineers, Buffalo District Permit to place two subsurface current monitoring structures offshore in Lake Erie, Referenca NCBCO-S Number 1-OH-72-ll; Section 10 of the Rivers and Harbors Act of 1899 (33 U.S.C. 403); application date May 31, 1972; permit date July 14, 1972. 1 12.2.1.2 U.S. Army Corps of Engineers, Buffalo District Permit to construct a barge slip and dredge an approach channel, Reference NCBCO-S Number 070-OX2-1-051595; Section 10 of the Rivers and Harbors Act of 1899 (33 U.S.C. 403); application date October 23, 1974; permit date May 13, 1976. A (') 12.2.1.3 U.S." Army Corps of Engineers, Buffalo District a Permit to maint.ain 35 feet of existing stone riprap shore protec-tion, Reference NCBCO-S Number 75-477-5; Section 10 of the Rivers and Harbors Act of 1899 (33 U.S.C. 403); application date June 3, 1975; permit date August 12, 1976. 12.2.1.4 U.S. Army Corps of Engineers, Buffalo District Permit to construct water intake and discharge structures, Refer-ence NCBCO-S Number 76-477-6; Section 10 of the Rivers and Harbors Act of 1899 (33 U.S.C. 403), and Section 404 of the Federal Water Pollution Control Act (86 Stat. 816, P.L. 93-500); applica-tion data March 8, 1976; permit date March 29, 1977. p. O 12.2-1
12.2.1.5 U.S. Army Corps of Engineers, Buffalo District O Permit to install temporary barge slip protection and to perform maintenance dredging, Reference NCBCO-S Number 77-477-1; Section 10 of the Rivers and Harbors Act of 1899 (33 U.S.C. 403), and Section 404 of the Federal Water Pollution Control Act (86 Stat. 816 , P . L . 92-500); application date January 4, 1977; permit date June 6, 1977. 12.2.1.6 U.S. Army Corps of Engineers, Buffalo District Ten-year permit for maintenance dredging of the barge slip and approach channel, and to extend the period for which the protec-tive barges may remain in place, assigned application number 80-477-10; Section 10 of the Rivers and Harbors Act of 1899 l
~~; (33 U.S.C. 403), and Section 404 of the Federal Water Pollution Control Act (86 Stat. 816, P.L. 92-500); app 12. stion date April 25, 1980; permit processing in progress.~~
O 12.2.2 STATE 12.2.2.1 State of Ohio Environmental Protection Agency Water quality certification permit to use and discharge lakewater; Section 401 of the Federal Water Pollution Control Act, as amended, 33 U.S.C.A. Sec. 1341; application date May 8, 1973; certification date June 21, 1974. 12.2.2.2 State of Ohio-Environ ental Protection Agency Temporary National Pollutant Discharge Elimination System (NPDES) permit for onsite water treatment facility start-up and operation and preoperational discharges; Federal Water Pollution Control Act, as amended by Public Law 95-217 enacted December 28, 1977; application date July 6, 1979; permit pending. 12.2-2 i e.--. , - . - . - ,. -
12.2.2.3 State of Ohio Environmental Protection Agency NPDES permit for all water discharges associated with plant operation. Federal Water Pollution Control Act, as amended by Public Law 92-500 enacted October 18, 1972; application to be filed in May 1982; permit by May 1984 for Unit 1 operation. g, U i n/ 12.2-3
~~.._.._m _ _ . . . _ _ _ _ _ _ _ _ - - - _ . _ _ - . _ . _ ._ __. . _. . _ _ _ _ . _ _ -~~
12.3 AIR i l iO 12.3.1 STATS l 12.3.1.1 State of Ohio Environmental Protection Agency i, i Permit to operate auxiliary boilers, diesel generators, and { l j diesel fuel storage tank; Ohio Administrative Code, Rule 3745- ! I 35-02; applications to be filed 30 days prior to placing equfpment i in service.- t I i I i 1 I i d i i l , + s i i } 4 4 ) f. ! O- l . 1 i [ 12.3-1 > c l
.-._ __ _ ._. _ _ . _ _ . . . . . . . _ _ _ . _ _ . . . . - - . - . _ _ . . ~ . - - . _ _ . _ - . . . _ . . . . . _ , . _ , . _ . , _ , _ . _ _ _ . . _ . , - _ _ . . _ . . - , _ . , _ . . _ .
12.4 AVIATION A V FEDERAL 12.4.1 12.4.1.1 Federal Aviation Administration Approval to construct meteorological tower; Federal Aviation Administration (49 USCA Sec. 1501) under regulation Title 14 CFR Part 77; Aeronautical Study Number 72-GL439-OE; issued April 1972 (for original meteorological tower location); Aeronautical Study Number 77-GL445-OE; issued May 6, 1977 (:for present meteoro-logical tower location). 12.4.1.2 Federal Aviation Administration Approval to construct two natural draft cooling towers; Federal Aviation Regulations, Part 77, Subchapter B; Aeronautical Study Number 76-GL-1678-OE; issued February 11, 1977. 12.4.1.3 Federal Aviation Administration Approval to construct a 300-foot-high microwave tower, Federal Aviation Regulations, Part 77, Subchapter B; Aeronautical Study Number 76-GL-729-OE; reassigned Aeronautical Study Number 77-GL-743-OE; issued June 24, 1977. 12.4.1.4 Federal Aviation Administration Approval to construct 2 tower cranes; Federal Aviation Regula-tions, Part 77, Subchapter B; Aeronautical Study Number 75-GL-1691-OE; issued January 7, 1976; reassigned Aeronautical Study Number 78-GL-1781-OE; issued December 1, 1978. 12.4-1
-~
~~~_ _ -. - __- - . . - . _ - - . -.~~
12.5 ENVIRONMENTAL MONITORING ! C) 4 12.5.1 FEDERAL 12.5.1.1 U.S. Army Corps of Engineers, Buffalo District i Work permits for construction and dredging in navigable waters ' to install water monitor; Rivers and Harbors Act of 1899 (33 U.S.C. 403); application spring 1972; permit July 1972. i 12.5.1.2 U.S. Coast Guard i Navigable markers and lights for ecology study buoys; U.S. Coast Guard regulations 33 U.S.C. Sec. 241; application spring 1972; permit renewed October 1972. i l O 1 i f 1 L e l O 12.5-1
12.6 TRANSMISSION' i () . 12.6.1 STATE 12.6.1.1 Ohio Power Siting Commission i Certificate of Environmental Compatibility and Public Need for the Perry-Macedonia-Inland and Perry-Hanna Transmission Lines; i Chapter 15 of the Rules and Regulations of the Ohio Power Siting Commission and PSC-5-02 of those regulations; Perry-Macedonia-Inland application filed NoJember 1974; certification issued March 1976; Perry-Hanna application filed February 1978; certifi-cation pending. O i l 12.6-1 _}}

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