ML14339A433

Updated Final Safety Analysis Report, Revision 21, Section 9, Auxiliary Systems

ML14339A433
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Site:	Beaver Valley
Issue date:	11/24/2014
From:	FirstEnergy Nuclear Operating Co
To:	Office of Nuclear Reactor Regulation
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{{#Wiki_filter:BVPS-2 UFSAR Rev. 13 9-i CHAPTER 9 TABLE OF CONTENTS Section Title Page 9 AUXILIARY SYSTEMS...............................9.1-1

9.1 FUEL STORAGE AND HANDLING.......................9.1-1

9.1.1 New Fuel Storage................................9.1-1

9.1.2 Spent

Fuel Storage..............................9.1-3 9.1.2.1 Design Bases....................................9.1-3 9.1.2.2 Facilities Description..........................9.1-3 9.1.2.3 Safety Evaluation...............................9.1-5 9.1.3 Spent Fuel Pool Cooling and Cleanup System......9.1-8 9.1.3.1 Design Bases....................................9.1-8 9.1.3.2 System Description..............................9.1-10 9.1.3.3 Safety Evaluation...............................9.1-12 9.1.3.4 Inspection and Testing Requirements.............9.1-12a 9.1.3.5 Instrumentation Requirements....................9.1-13

9.1.4 Light

Load Handling System......................9.1-14 9.1.4.1 Design Bases....................................9.1-14 9.1.4.2 System Description..............................9.1-15 9.1.4.3 Safety Evaluation...............................9.1-23 9.1.4.4 Tests and Inspections...........................9.1-29 9.1.4.5 Instrumentation Requirements....................9.1-32

9.1.5 Overhead

Heavy Load Handling Systems............9.1-32 9.1.5.8 Reference for Section 9.1.......................9.1-50

9.2 WATER

SYSTEMS...................................9.2-1

9.2.1 Station

Service Water System....................9.2-1

9.2.2 Cooling

Systems for Reactor Auxiliaries.........9.2-15

9.2.3 Demineralized

Water Makeup System...............9.2-28

9.2.4 Potable

and Sanitary Water Systems..............9.2-32

9.2.5 Ultimate

Heat Sink..............................9.2-33

9.2.6 Condensate

Storage Facilities System............9.2-36

9.2.7 Turbine

Plant Component Cooling Water System....9.2-37

9.2.8 Primary

Grade Water System......................9.2-41

9.2.9 Reference

for Section 9.2.......................9.2-43

9.3 PROCESS

AUXILIARIES.............................9.3-1

9.3.1 Compressed

Air Systems..........................9.3-1

9.3.2 Process

Sampling System.........................9.3-11 9.3.3 Equipment and Floor Drainage System.............9.3-22 9.3.4 Chemical and Volume Control System..............9.3-29 9.3.5 Reference for Section 9.3.......................9.3-64

9.4 AIR-CONDITIONING, HEATING, COOLING, AND VENTILATION SYSTEMS.............................9.4-1

BVPS-2 UFSAR Rev. 1 9-ii TABLE OF CONTENTS (Cont) Section Title Page 9.4.1 Control Building Ventilation System.................9.4-2 9.4.2 Spent Fuel Pool Area Ventilation System.............9.4-9

9.4.3 Auxiliary

Building and Radwaste Area Ventilation System..............................................9.4-12

9.4.4 Turbine

Building Area Ventilation System............9.4-16 9.4.5 Engineered Safety Features Building Ventilation Systems.............................................9.4-19

9.4.6 Emergency

Diesel Generator Building Ventilation System..............................................9.4-20 9.4.7 Containment Ventilation System......................9.4-23

9.4.8 Intake

Structure Ventilation System.................9.4-33 9.4.9 Main Steam and Feedwater Valve Area.................9.4-39 9.4.10 Service Building Ventilation System.................9.4-42 9.4.11 Safeguards Area Ventilation System..................9.4-50 9.4.12 Cable Vault and Rod Control Area Ventilation System.9.4-52 9.4.13 Decontamination Building Ventilation System.........9.4-56b 9.4.14 Cooling Tower Pumphouse Ventilation System..........9.4-59 9.4.15 Gland Seal Steam Exhaust Ventilation System.........9.4-61 9.4.16 Condensate Polishing Building Ventilation System....9.4-63

9.5 OTHER

AUXILIARY SYSTEMS.............................9.5-1

9.5.1 Fire Protection System..............................9.5-1 9.5.2 Communications Systems..............................9.5-42 9.5.3 Lighting Systems....................................9.5-45

9.5.4 Emergency

Diesel Generator Fuel Oil Storage and Transfer System.....................................9.5-49 9.5.5 Emergency Diesel Generator Cooling Water System.....9.5-54a

9.5.6 Emergency

Diesel Generator Air-Starting System......9.5-59 9.5.7 Emergency Diesel Generator Lubrication System.......9.5-62b 9.5.8 Emergency Diesel Generator Combustion Air Intake and Exhaust System..................................9.5-66 9.5.9 Reactor Plant Gas Supply System.....................9.5-69 9.5.10 Containment Vacuum System...........................9.5-71

APPENDIX 9.5A FIRE PROTECTION EVALUATION REPORT

BVPS-2 UFSAR Rev. 0 9-iii LIST OF TABLES Table Number Title 9.1-1 Fuel Pool Cooling and Cleanup System Principal

Components, Design and Performance Parameters

9.1-2 Applicable Overhead Load Handling Systems 9.1-3 Overhead Load Handling Systems that Do Not Operate Over Safety-Related Equipment or Equipment Required for Safe Shutdown

9.1-4 Loads Carried by Each Piece of Equipment 9.2-1 Station Service Water Systems Component Design Data 9.2-2 Service Water System Flow Requirements

9.2-3 Operation of Service Water Valves 9.2-4 Primary Component Cooling Water System Component Flow Requirements

9.2-5 Primary Component Cooling Water System Subsystem Component Design Data

9.2-6 Chilled Water System, Principal Component and Design Parameters

9.2-7 Neutron Shield Tank Cooling Water System Component Design Data

9.2-8 Demineralized Water Makeup System Component Design Data 9.2-9 Potable and Sanitary Water System Principal Components 9.2-10 Turbine Plant Component Cooling Water System Component Flow Requirements

9.2-11 Turbine Plant Component Cooling Water System Subsystem Component Design Data

9.3-1 Station Air and Condensate Polishing Air Systems Principal Components and Design Data

9.3-2 Station Air and Condensate Polishing Air Systems Consequences of Component Failures

BVPS-2 UFSAR Rev. 15 9-iv LIST OF TABLES (Cont)

Table Number Title 9.3-3 Containment Instrument Air System Principal Components and Design Parameters

9.3-4 Containment Instrument Air System Consequences of Component Failures

9.3-5 Reactor Plant and Process Sampling System Sampling Capabilities

9.3-6 Nuclear Vents and Drains System Principal Components and Design Parameters

9.3-7 Chemical and Vol ume Control System Design Bases and Design Parameters

9.3-8 Chemical and Volume Control System Principal Components and Design Parameters

9.3-9 Failure Modes and Effects Analysis-Chemical and Volume Control System Active Components - Normal Plant

Operation, Load Follow, and Safe Shutdown 9.3-10 Boron Recovery System Component Design Data 9.4-1 Plant Ventilation Systems Modes of Operation 9.4-2 Control Building Area Design Temperatures

9.4-3 Control Building Air-Conditioning and Ventilating Systems Principal Components and Design Parameters

9.4-4 Control Room Area Air Conditioning System Description of Operation

9.4-5 Control Room Area Ventilation System Outside Air Rates in Terms of Air Changes per Hour

9.4-6 Spent Fuel Pool Area (Fuel Building) Ventilation System Principal Components and Design Parameters

9.4-7 Auxiliary Building and Radwaste Area Ventilation System Principal Components and Design Parameters

9.4-8 Turbine Building Ventilation System, Principal Components and Design Parameters

BVPS-2 UFSAR Rev. 17 9-v LIST OF TABLES (Cont) Table Number Title 9.4-9 Emergency Diesel Generator Building Ventilation System Principal Components and Design Parameters

9.4-10 Containment Atmosphere Recirculation System Performance Characteristics

9.4-11 Containment Atmosphere Recirculation System Principal Components and Design Parameters

9.4-12 DELETED 9.4-13 CRDM Ventilation System Principal Components and Design Parameters

9.4-14 Primary Intake Structure Ventilation System Principal Components and Design Parameters

9.4-15 Alternate Intake Structure Ventilation System Principal Components and Design Parameters

9.4-16 Main Steam and Feedwater Valve Area Ventilation System Principal Components and Design Parameters

9.4-17 Normal Switchgear and Cable Spreading Area Ventilation System Principal Components and Design Parameters

9.4-18 Battery Room Ventilation System Principal Components and Design Parameters

9.4-19 Emergency Switchgear Room Ventilation Syste m Principal Components and Design Parameters

9.4-20 Service Building Equipment Room Ventilation System Principal Components and Design Parameters

9.4-21 Safeguards Area Ventilation System Principa l Components and Design Parameters

9.4-22 Cable Vault and Rod Control Area Ventilation System Principal Components and Approximate Design Parameters 9.4-23 Decontamination Building Ventilation System, Principal Components and Design Parameters

BVPS-2 UFSAR Rev. 17 9-vi LIST OF TABLES (Cont) Table Number Title 9.4-24 Cooling Tower Pumphouse Ventilation System, Principal Components and Approximate Design Parameters

9.4-25 Gland Seal Steam Exhaust System Principal Components and Design Parameters

9.4-26 Condensate Polishing Building Ventilation System Principal Component Design and Parameters

9.5-1 Emergency Diesel Generation Fuel Oil St orage and Transfer System Component Design Parameters

9.5-2 Emergency Diesel Generator Fuel Oil Storage and Transfer System Major Oil Distributors within 40 Miles of Site 9.5-3 Emergency Diesel Generator Intercooler and Jacket Water Cooling Systems Principal Components and Design Parameters 9.5-4 Reactor Plant Gas Supply System Principal Components and Design Parameters

9.5-5 Reactor Plant Gas Supply System Summary of Nitrogen System Requirements

9.5-6 Containment Vacuum System Principal Components and Design Parameters

9.5-7 Emergency Diesel Generator Cooling Water System Leakage Summary Per Diesel Engine

9.5-8 Emergency Diesel Generator Lube Oil System Principal Components and Design Parameters

9.5-9 Crankcase Vacuum Pumps Design Parameters 9.5-10 Emergency Diesel Generator Air Starting System Principal Components and Design Parameters

9.5-11 Diesel Engine Air Start Test Data

9.5-12 Areas In Which Fire Detection/Suppression Is Outside Scope of 10 CFR 50.48 Fire Protection

BVPS-2 UFSAR Rev. 15 9-vii LIST OF FIGURES 9.1-1 Arrangement - Fuel and Decontamination Building

9.1-2 Arrangement - Fuel and Decontamination Building

9.1-3 DELETED 9.1-4 Spent Fuel Pool Cooling and Cleanup System 9.1-5 DELETED

9.1-6 Fuel Transfer System 9.2-1 Service Water System

9.2-2 DELETED 9.2-3 DELETED

9.2-4 DELETED

9.2-5 DELETED 9.2-6 DELETED

9.2-7 DELETED

BVPS-2 UFSAR Rev. 11 9-viii LIST OF FIGURES (Cont) Figure Number Title

This page is intentionally blank.

BVPS-2 UFSAR Rev. 15 9-ix LIST OF FIGURES (Cont) 9.2-8 DELETED 9.2-9 DELETED

9.2-10 Primary Component Cooling Water System

BVPS-2 UFSAR Rev. 12 9-x LIST OF FIGURES (Cont) 9.3-1 Station Air Systems 9.3-2 DELETED

9.3-3 DELETED 9.3-4 DELETED 9.3-5 DELETED

9.3-6 DELETED 9.3-7 DELETED 9.3-8 DELETED

9.3-9 DELETED 9.3-10 DELETED 9.3-11 DELETED Sheet 1

9.3-11 DELETED Sheet 2

9.3-12 DELETED

9.3-13 DELETED 9.3-14 DELETED 9.3-15 DELETED

9.3-16 DELETED 9.3-17 DELETED 9.3-18 DELETED

9.3-19 DELETED 9.3-20 DELETED 9.3-21 Piping: Chemical and Volume Control System (207-1) 9.3-22 DELETED

BVPS-2 UFSAR Rev. 15 9-xi LIST OF FIGURES (Cont) 9.3-23 DELETED

9.3-24 DELETED

9.3-25 DELETED 9.3-26 Boron Recovery System

9.4-1 Computer and Control Room Air-Conditioning and Ventilation System 9.4-2 Control Building Ventilation System

9.4-3 DELETED

9.4-4 Auxiliary Building Air-Conditioning and Ventilation System - Safety Related Equipment

9.4-5 DELETED 9.4-6 DELETED 9.4-7 Turbine Building Ventilation System 9.4-8 Emergency Diesel Generator Building Ventilation System 9.4-9 Containment Area Ventilation System 9.4-10 DELETED 9.4-11 Primary Intake Structure Ventilation System

9.4-12 Main Steam, Safeguards, and Pipe Tunnel Ventilation and Air-Conditioning System

9.4-13 Service Building Ventilation System - Safety Related Equipment

9.4-14 Cable Vault and Rod Control Area Air-Conditioning and Ventilation Systems

BVPS-2 UFSAR Rev. 15 9-xii LIST OF FIGURES (Cont) 9.5-1 Water-Fire Protection System 9.5-2 Water-Fire Protection System

9.5-2A Water-Fire Protection System (Sheets 1 and 2) deleted

9.5-3 DELETED 9.5-4 DELETED 9.5-5 CO2-Fire Protection System 9.5-6 DELETED 9.5-6A Halon Fire Protection System 9.5-7 Emergency Diesel Generator Fuel Oil Storage and Transfer System

9.5-8 Emergency Diesel Generator Cooling Water System

9.5-9 Emergency Diesel Generator Cooling Water System 9.5-10 Emergency Diesel Generator Air Starting System 9.5-11 Emergency Diesel Generator Lubrication System

9.5-12 Emergency Diesel Generator Combustion Air Intake, Exhaust and Vacuum System

BVPS-2 UFSAR Rev. 14 9.1-1 CHAPTER 9 AUXILIARY SYSTEMS 9.1 FUEL STORAGE AND HANDLING

9.1.1 New Fuel Storage The new fuel storage area, located in the fuel building, is

designed to provide a safe, effective means for dry storage of the new fuel assemblies.

9.1.1.1 Design Bases The new fuel storage area is designed in accordance with the

following criteria:

1. General Design Criterion 2, as it relates to the ability of structures housing the facility components to withstand the effects of natural phenomena such as earthquakes, tornadoes, hurricanes, and floods.

2. General Design Criterion 5, as it relates to shared structures, systems, and components important to safety being capable of performing required safety functions.

3. General Design Criterion 61, as it relates to the facility design for fuel storage.

4. General Design Criterion 62, as it relates to the prevention of criticality by physical systems or the process utilizing geometrically safe configurations.

5. Regulatory Guide 1.29, as it relates to the seismic design classification of facility components.

6. The capability to store sufficient fuel for one refueling (one-third core) plus 17 spares, for a total of 70 assemblies, and maintain the fuel subcritical (K 0.95) when fully loaded and flooded with non-borated water. With fuel of the highest anticipated

enrichment, assuming optimum moderation, the effective

multiplication factor (K) will not exceed 0.95. 9.1.1.2 Facilities Description

The new fuel storage area is shown on Figures 9.1-1 and 9.1-2. New fuel storage is provided for one-third core (53 fuel assemblies) plus 17 spare assemblies. New fuel assemblies are stored dry in a steel and concrete structure within the fuel building. The new fuel storage racks consist of a stainless steel support structure into which 70 stainless steel fuel guide assemblies are bolted in 14 parallel rows of five fuel guide assemblies each. Due to the design of the fuel guide supporting

BVPS-2 UFSAR Rev. 14 9.1-2 structure the necessary minimum spacing between nearby fuel assemblies is ensured. The spacing of the new fuel assemblies, located in the new fuel guide assemblies, is a minimum of 21 inches center-to-center. Fuel assemblies are loaded into the fuel guide assemblies through the top. Adequate guidance is provided in each fuel

guide assembly by means of a flared lead-in opening to preclude damage to the fuel assemblies during insertion or withdrawal. The accumulation of liquid in the new fuel storage area is

prevented by a 4-inch floor drain located in the area. 9.1.1.3 Safety Evaluation

The new fuel storage area is located in the Seismic Category I fuel building. Handling of new fuel is done by a separate 10-

ton hoist on the motor-driven platform crane (Section 9.1.4). New fuel assemblies are stored vertically, with a minimum center to center spacing of 21 inches. This will maintain the fuel in a

subcritical condition with the effective multiplication factor, K less than or equal to 0.95, for both the full density (water at 68F and 1gm/cm) and low density (0.075 gm/cm) optimum moderation conditions. The new fuel storage racks are designed to Seismic Category I requirements. A detailed analysis of the storage racks have been performed to verify the adequacy of the design to withstand the loadings encountered during normal operation, an operating basis earthquake (OBE), and the safe shutdown earthquake (SSE).

The motor-driven platform crane, which is used for transfer of fuel, is the only overhead crane which can pass over the new fuel. Damage to the fuel assemblies and the new fuel racks by excessive uplift forces from the new fuel handling hoist are

prevented by operating procedures and by a load cell attached to the crane. In addition, the new fuel storage area is protected from the effect of dropped heavy objects by interlocks on the fuel handling hoist, which limit the lifting capability of the crane to the weight of a fuel cell and its handling tool. Heavier loads will be handled by an administrative procedure, which will define the area over which these loads may be handled to prevent damage to the new fuel.

BVPS-2 UFSAR Rev. 12 9.1-3 9.1.2 Spent Fuel Storage The spent fuel storage area, located in the fuel building, is designed to provide a safe and effective means of storing spent fuel. 9.1.2.1 Design Bases

The spent fuel storage area is designed in accordance with the following criteria:

1. General Design Criterion 2, as it relates to structures housing the facility and the facility itself being capable of withstanding the effects of natural phenomena, such as earthquakes, tornadoes, hurricanes, and floods.

2. General Design Criterion 4, as it relates to structures housing the facility and the facility itself being capable of withstanding the effects of environmental conditions, external missiles, internally generated missiles, pipe whip, and jet impingement forces associated with pipe breaks, such that safety functions will not be precluded.

3. General Design Criterion 5, as it relates to shared structures, systems, and components important to safety being capable of performing required safety

functions.

4. General Design Criterion 61, as it relates to the facility design for fuel storage and handling of radioactive materials.

5. General Design Criterion 62, as it relates to the prevention of criticality by physical systems or processes utilizing geometrically safe configurations.

6. General Design Criterion 63, as it relates to monitoring systems provided to detect conditions that could result in the loss of decay heat removal capabilities, to detect excessive radiation levels, and to initiate appropriate safety actions.

7. The requirements of Regulatory Guides 1.13, 1.29, 1.115, and 1.117.

9.1.2.2 Facilities Description

The spent fuel storage area, shown on Figures 9.1-1 and 9.1-2 , is divided into three areas separated by a stainless steel-lined concrete wall, with a removable gate provided between each area to allow movement of fuel elements between them. Each gate is equipped with an inflatable seal to prevent leakage from one area to another. The three areas are defined as the fuel cask

BVPS-2 UFSAR Rev. 20 9.1-5 The Metamic fuel storage racks consist of freestanding modules, made primarily from austenitic stainless steel containing honeycomb storage cells interconnected through longitudinal welds. A panel of Metamic metal matrix composite containing a high areal loading of the boron-10 (B-10) isotope provides neutron attenuation between adjacent storage cells. The baseplates on all fuel rack modules extend out beyond the rack module periphery wall such that the plate protrusions act to set a required minimum separation between the facing cells in adjacent rack modules. Each fuel rack module is supported by four or five pedestals, which are remotely adjustable. The rack module support pedestals length adjustment is primarily provided to accommodate minor level variations in the pool floor flatness. Thus, the racks are installed in a vertical position and the top of the racks are co-planar with each other. Some pedestals are supported by the sub-base beams remaining from the removed Boraflex spent fuel storage racks. Between the rack module pedestals and the pool floor liner is a bearing pad, which serves to diffuse the dead load of the loaded racks into the reinforced concrete structure of the pool slab. The bearing pads are part of the Metamic rack installation. The Metamic fuel storage racks have storage cells that are regionalized for loading purposes into three distinct regions, with independent criteria defining each region: Region 1 is designed to accommodate fresh fuel with a maximum initial enrichment up to 5.0 wt% U-235. Region 1 storage cells are located on the periphery of each rack (outer row only) and are therefore separated from other Region 1 cells in adjacent racks by the gap between the racks. Region 1 cells are additionally separated from other Region 1 cells within the same rack by Region 2 cells (including a Region 2 cell in the diagonal direction). Since Region 1 cells are qualified for the storage of fresh fuel, any fuel assembly (fresh or burned) meeting the maximum enrichment requirement may be stored in a Region 1 location. Region 2 is designed to accommodate fuel with a maximum initial enrichment of up to 5.0 wt% U-235 and a high burnup defined according to the calculated Region 2 initial enrichment and burnup combination. Region 2 cells are located on the rack periphery (outer row) interspaced with (separating) Region 1 cells and are also located in the second row of cells (from the outside of the rack) separating the Region 1 cells from the Region 3 cells. Region 3 is designed to accommodate fuel with a maximum initial enrichment of up to 5.0 wt% U-235 and a moderate burnup defined according to the calculated Region 3 initial enrichment and burnup combination. Region 3 cells are located on the interior of the rack and are prohibited from being located in the outer two rows of the rack.

BVPS-2 UFSAR Rev. 18 9.1-8 9.1.3 Spent Fuel Pool Cooling and Cleanup System

The fuel pool cooling and cleanup system, shown on Figure 9.1-4 , removes decay heat generated by the spent fuel stored in the fuel pool and provides clarification and purification of water in the fuel pool, refueling cavity, and RWST. Table 9.1-1 lists the principal component design and performance characteristics.

9.1.3.1 Design Basis

The fuel pool cooling and cleanup system is designed to remove the heat generated by the stored spent fuel assemblies, to permit unrestricted access to the working area around the spent

fuel storage pool, and to maintain the optical clarity of the water in the spent fuel storage pool and the refueling cavity.

The system is designed for continuous service whenever spent

fuel is stored in the pool.

Two fuel pool heat exchangers and two fuel pool cooling pumps are provided to remove the heat produced by the spent fuel stored in the fuel pool in the event the reactor is emptied of fuel at anytime during BVPS-2 life (Section 9.1.2). Standard Review Plan (SRP) 9.1.3 specifies maximum normal heat load

conditions and maximum abnormal conditions to be used in

evaluating cooling system performance. Cooling system design is sufficient to satisfy SRP performance criteria for these conditions (UFSAR Section 9.1.3.3). Purification facilities are provided to permit unrestricted access to required areas and to maintain optical clarity of the spent fuel pool and refueling

cavity. The design of all the components in the fuel pool cooling and

cleanup system complies with the following codes:

1. Fuel pool heat exchangers - ASME III, Class 3

2. Fuel pool cooling pumps - ASME III, Class 3

3. Fuel pool cooling piping, valves, and fittings - ASME III, Class 3

4. Fuel pool filters and demineralizers - ASME VIII.

5. Fuel pool cleanup system piping, valves, and fittings - ANSI B31.1

The ASME Code Baseline Document identifies the specific ASME III edition/addenda for these components.

The fuel pool cooling and cleanup system is designed in

accordance with the following criteria:

1. General Design Criterion 2, as it relates to structures housing the system, and the system itself, being capable of withstanding the effects of natural

phenomena such as earthquakes, tornadoes, and

hurricanes. BVPS-2 UFSAR Rev. 0 9.1-9 2. General Design Criterion 4, with respect to structures housing the system, and the system itself, being capable of withstanding the effects of external missiles.

3. General Design Criterion 5, as it relates to shared systems and components important to safety being

capable of performing required safety functions.

4. General Design Criterion 44, to include:

a. The capability to transfer heat loads from safety-related structures, systems, and components to

heat sinks under both normal operating and accident conditions, b. Suitable redundancy of components so that safety functions can be performed, assuming a single active failure of a component coincident with the

loss of all offsite power, and

c. The capability to isolate components, systems, or piping, if required, so that the system safety function will not be compromised.

d. Calculation of heat loads in accordance with Branch Technical Position ASB 9-2.

5. General Design Criterion 45, as it relates to the design provisions to permit periodic inspection of safety-related components and equipment.

6. General Design Criterion 46, as it relates to design provisions to permit operational functional testing of

safety-related systems or components to assure structural integrity and system leak tightness, operability, adequate performance of active system

components, and the capability of the integrated system to perform required functions during normal, shutdown, and accident situations.

7. General Design Criterion 61, as it relates to the system design for fuel storage and handling of

radioactive materials, including the following elements:

a. The capability of periodic testing of components important to safety, b. Provisions for containment, c. Provisions for decay heat removal, d. The capability to prevent reduction in fuel storage coolant inventory under accident conditions in BVPS-2 UFSAR Rev. 13 9.1-10 accordance with the guidelines of position C.6 of Regulatory Guide 1.13, and

e. The capability and capacity to remove corrosion products, radioactive materials, and impurities from the pool water, thus reducing occupational exposures to radiation.

8. General Design Criterion 63, as it relates to monitoring systems provided to detect conditions that

could result in a loss of decay heat removal capability, to detect excessive radiation levels, and to initiate appropriate safety action.

9. Paragraph 20.l(c) of 10 CFR 20, as it relates to radiation doses being kept as low as is reasonably

achievable in accordance with Regulatory Guide 8.8, Positions C.2F(2) and C.2F(3).

10. Regulatory Guide 1.13, as it relates to system design to prevent damage resulting from the SSE.

11. Regulatory Guide 1.26, as it relates to quality group classification of the system and its components.

12. Regulatory Guide 1.29, as it relates to the seismic design classification of system components.

9.1.3.2 System Description The fuel building, the spent fuel pool, the fuel pool cooling

portion of the spent fuel pool cooling and cleanup system, and all supporting structures are designed: for the SSE and OBE seismic loads described in Section 3.8.4; for the effects of

tornadoes and hurricanes, as described in Sections 3.3.1 and 3.3.2; and to withstand the effects of external missiles, as described in Section 3.5.1.1. The cooling portions of the spent fuel pool cooling and cleanup system are designed to Seismic Category I requirements and are constructed to Quality Group C.

All components of the spent fuel pool cooling and cleanup system have minimum design pressures and temperatures of 74 psig and 200F, respectively. All parts of equipment and piping in contact with borated fuel pool water are constructed of stainless steel. The fuel pool water flows from the suction connection of the pool via either of the two fuel pool cooling pumps, through the tube side of either of the two fuel pool heat exchangers, and returns to the pool. The fuel pool heat exchangers are cooled by component cooling water (Section 9.2.2) flowing through the shell side.

BVPS-2 UFSAR Rev. 20 9.1-11 The normal source of makeup water for the fuel pool to account for losses due to evaporation is from the primary grade water

system (Section 9.2.8). To ensure an adequate supply of makeup

water to the fuel pool under all conditions, an emergency supply from the service water pumps (Section 9.2.1) via the Seismic

Category I service water system piping is provided. A backup

supply of makeup can also be provided from the fire protection system (Section 9.5.1) which has hose racks available in the fuel building. The source of water is the Ohio River. Connection to the fuel pool can either be made by attaching to the temporary piping connections on the fuel pool heat exchanger inlets or running fire hoses directly into the pool. Boric acid is added manually, as required, to provide additional neutron

absorbing capability.

The fuel pool cooling pumps are provided with cross-connecting piping such that either pump can be used with either or both heat exchangers. For additional safety, each fuel pool heat

exchanger and fuel pool cooling pump can be isolated from the rest of the system for repairs. As an added measure of cooling assurance, temporary piping connections are provided in the inlet piping of the heat exchangers for connecting a temporary pump, which would take suction from the spent fuel pool via a

temporary line.

The fuel pool cooling pump suction line penetrates the spent fuel pool in the spent fuel area. The discharge line penetrates the spent fuel pool in the spent fuel area and in the cask area, thus ensuring that an adequate supply of cooling water is

available in both areas, and provides for the mixing of fuel pool water to produce a uniform temperature distribution under

all conditions.

Two fuel pool cleanup pumps, in parallel, purify the spent fuel pool water. These pumps can be lined up to discharge from the

spent fuel pool either through the fuel pool filters only (two filters are provided, each rated at 400 gpm flow) or through a

single mixed bed fuel pool ion exchanger, and then through the

filters, before returning to the spent fuel pool. Operation of the system is such that one pump is normally operating while the

other pump is on standby. Local sample connections are provided for taking samples to determine the decontamination factor of

the ion exchanger and efficiency of the filters.

Connections are provided from the RWST to allow for cleanup of the RWST and for fuel pool makeup, and from the fuel pool ion exchanger to the solid waste disposal system (Section 11.4) for resin discharge. The RWST connection is isolated by series automatic valves that receive a safety-injection signal. These valves provide a class break with the non-safety Fuel Pool Purification piping.

A connection from the residual heat removal (RHR) system (Section 5.4.7) is provided on the fuel pool purification lines

inside the containment to permit circulation of RHR water in the refueling cavity as well as in the reactor vessel during

refueling operations.

BVPS-2 UFSAR Rev. 13 9.1-12 The activity levels in the spent fuel pool are determined by the analysis of samples taken periodically from the spent fuel pool. The allowable dose rates for personnel working in the fuel building are described in Section 11.3.

Ambient radioactivity concentrations in the access areas above the pool are monitored by radiation detection equipment, as

described in Sections 11.5 and 12.3. The detector sample points are located in the inlet plenum of the exhaust ventilation duct. Ventilation in the fuel building is designed to maintain a

negative pressure and is described in Section 9.4.2. Fuel pool and refueling cavity skimmers keep the water surface

of the spent fuel pool and refueling cavity free of floating dust and other material. The skimmer system is not in continuous use but is operated as needed to maintain the

cleanliness of the spent fuel pool. Drains from the fuel building air-conditioning unit (Section 9.4.2) are directed to the air-conditioning unit drain tank (Figure 9.1-4) and its contents are subsequently pumped to the fuel pool. 9.1.3.3 Safety Evaluation

The spent fuel pool cooling and cleanup system consists of two cooling trains, each with a pump, a heat exchanger, and separate

piping loops. The pumps are environmentally qualified, as described in Section 3.11, and are powered from the Class 1E

emergency buses such that the pumps can be operated during all

normal and emergency plant conditions. The spent fuel pool cooling system is designed to remove the spent fuel heat load of a full core after 100 hours decay. Calculated fuel pool temperature assuming this heat load condition does not exceed 170F, assuming failure of one cooling pump. The spent fuel pool cooling system also removes decay heat assuming a full core removed from the reactor and stored in the pool with 100 hours decay plus one-third core stored in the pool with 36 days decay and one-third core stored in the pool with 400 days decay. Calculated maximum pool temperature during this condition is 173F assuming no concurrent failure. All analyses assume that all available storage spaces in the spent fuel pool are full. Administrative controls ensure acceptable fuel pool temperature by controlling offloading of fuel based on component cooling water temperature and decay time (refer to License Amendment No. 126 of the Unit 2 Technical Specifications). Water level in the spent fuel pool cannot be lowered below 10 feet above the top of the fuel stored in the spent fuel racks due to the design of the pool, as described in Section 9.1.2, and by the design of the piping, which does not allow any piping

termination below this elevation. Tell-tale drains are provided to detect leakage from the pool in the event of a fuel pool liner failure. The fuel building is provided with a sump and

sump pumps to collect leakage in the

BVPS-2 UFSAR Rev. 12 9.1-12a building, as described in Section 9.3.3. An alarm will sound in the main control room if a low water level occurs in the fuel pool. A Seismic Category I source of makeup water is provided from the service water system in the event that fuel pool cooling is rendered inoperable. To prevent contamination of the pool during normal operation, a spool piece with a spectacle flange is provided on the service water line in the valve pit. The blind face of the spectacle flange is normally installed in the flow path.

A failure modes and effects analysis (FMEA) to determine if the

instrumentation and controls (I & C) and electrical portions meet the single failure criterion, and to demonstrate and verify how the General Design Criteria and IEEE Standard 279-1971 requirements are satisfied, has been performed on the spent fuel pool cooling system. The FMEA methodology is discussed in Section 7.3.2. The results of this analysis can be found in the

separate FMEA document (Section 1.7). 9.1.3.4 Inspection and Testing Requirements

The fuel pool level and temperature instrumentation is tested and calibrated on a periodic basis. Operating and standby components are alternated periodically to verify operability of all equipment. Visual inspection of system components and instrumentation is BVPS-2 UFSAR Rev. 1 9.1-13 conducted periodically. Preoperational tests are performed as described in Chapter 14. All safety class pumps and valves are in-service inspected as specified in Section 6.6. In addition, containment isolation valves are tested as specified in Section 6.2.4.

Balance of Plant Testing is performed periodically to assess operational readiness of the fuel pool cooling pumps over their service life.

9.1.3.5 Instrumentation Requirements

Control switches with indicating lights are provided in the main control room for the fuel pool cooling pumps. These pumps are operated manually.

Control switches with indicating lights are provided in the main control room for the fuel pool heat exchanger cooling water

isolation valves. These valves are operated manually. Control switches with indicating lights are provided in the main

control room for the pool purification pumps. One pump is started manually and the second pump is placed in a standby mode to start on failure of the first pump.

Selector switches with indicating lights are provided in the main control room for the ion exchanger bypass valves. These

valves are operated manually. Level indicators are provided in the main control room for spent

fuel pool level. Temperature indicators are provided in the main control room for spent fuel pool temperature and refueling cavity water temperature.

Flow indication is provided in the main control room for fuel pool ion exchanger flow.

Annunciation is provided in the main control room for the following:

1. Fuel pool cooling pumps discharge pressure low, 2. Fuel pool cooling pumps auto trip,

3. Spent fuel pool temperature high,

4. Spent fuel pool level low, 5. Spent fuel pool level high,

6. Refueling cavity level low, BVPS-2 UFSAR Rev. 0 9.1-14 7. Refueling cavity level high, 8. Refueling cavity temperature high,

9. Pool purification filters differential pressure high, 10 Pool purification pumps thermal overload,

11. Pool purification pumps discharge pressure low,

12. Fuel pool ion exchanger inlet temperature high, and

13. Fuel pool ion exchanger differential pressure high.

These points are also monitored by the plant computer system.

Area radiation monitors are provided as described in Section 11.5.

9.1.4 Light

Load Handling System The light load handling system (LLHS), in conjunction with the new and spent fuel storage facilities (Sections 9.1.1 and 9.1.2) and the spent fuel pool cooling and cleanup system (Section 9.1.3), provide a safe and effective means of transporting and

handling fuel from the time it reaches the station in an unirradiated condition until it is loaded into a spent fuel shipping cask after post-irridation cooling. The LLHS does not

handle any loads heavier than a single fuel assembly. The handling of the spent fuel shipping cask and other heavy loads related to refueling operations are discussed in Section 9.1.5.

9.1.4.1 Design Bases

The following design bases apply to the LLHS:

1. Fuel handling devices are designed to avoid dropping or jamming of fuel assemblies during the fuel transfer

operation.

2. Handling equipment is designed to avoid dropping of fuel handling devices and fuel assemblies during the

fuel transfer operation.

3. Handling equipment used to raise and lower spent fuel assemblies have a limited maximum lift height so that the minimum required depth of water shielding is maintained over the fuel, as required by General Design Criterion (GDC) 61.

4. The fuel transfer system (FTS), where it penetrates the containment, has provisions to preserve the integrity of the containment pressure boundary.

BVPS-2 UFSAR Rev. 13 9.1-15 5. Criticality during fuel handling operations is prevented by the geometrically safe configuration of the fuel assemblies and fuel handling equipment, as required by GDC 62.

6. Handling equipment will not fail in such a manner as to damage Seismic Category I equipment in the event of a SSE, as required by GDC 2, and Regulatory Guide 1.29. 7. The inertial loads imparted to the fuel assemblies or core components during handling operations are less than the loads which could cause damage.

8. Physical safety features are provided for personnel operating the handling equipment.

9. The BVPS-2 FTS and associated handling equipment are not shared among other nuclear power units, as it relates to GDC 5.

10. General Design Criterion 61, as it relates to the appropriate containment, confinement, and filtering systems, decay heat RHR system, and the prevention of significant reduction in the spent fuel pool inventory.

11. The equipment used in the LLHS is not classified as safety-related and is not required for safe shutdown of BVPS-2 nor used to mitigate the consequences of an accident.

9.1.4.2 System Description The LLHS consists of the equipment needed for the refueling

operation on the reactor core and for handling spent and new fuel in the fuel building. The LLHS is comprised of fuel handling equipment and a FTS. The areas associated with the

fuel handling operations are the refueling cavity, the refueling canal, the spent fuel storage area, and the new fuel storage area. 9.1.4.2.1 Fuel Handling Description New fuel assemblies received for core loading are removed one at a time from the shipping container and temporarily stored in both the new and spent fuel storage racks. All new fuel assemblies received after the initial fueling are stored in the new fuel storage racks located in the new fuel storage area, or in the spent fuel racks. The fuel handling equipment is designed to handle the spent fuel assembly underwater from the time it leaves the reactor vessel until it is placed in a cask for shipment from the site. Water provides an effective, economic, and transparent radiation shield, as well as a reliable cooling medium for removal of

decay heat.

BVPS-2 UFSAR Rev. 13 9.1-16 The associated fuel handling areas may generally be divided into three areas: the refueling cavity and refueling canal, which are flooded only during plant shutdown for refueling; the spent fuel pool, which is filled with water and is always accessible to operating personnel; and the new fuel storage area, designed for dry storage. The refueling canal in the reactor containment and the spent fuel pool in the fuel building are connected by a fuel transfer tube. This tube is fitted with a blind flange on the refueling canal end and a valve on the spent fuel pool end. The blind flange is kept in place except during refueling to ensure containment integrity. Fuel is transferred through the tube on an underwater transfer car.

Fuel is moved between the reactor vessel and the refueling canal by the manipulator crane. A rod cluster control (RCC) changing fixture is located on the refueling canal wall for transferring

control elements from one fuel assembly to another. The fuel assembly then is placed in the fuel container, and the upender at either end of the fuel transfer tube is used to pivot the fuel container to the horizontal position. After the transfer car transfers the fuel assembly through the transfer tube, the upender at that end of the tube pivots the container to a vertical position so that the fuel assembly can be lifted out of the fuel container.

In the spent fuel pool, spent fuel assemblies are moved about by the motor-driven platform crane, which has two hoists rated at 10 tons each. When lifting spent fuel assemblies, the hoist

uses a long-handled tool to ensure that sufficient radiation shielding is maintained.

A shorter tool (new fuel handling tool) is used to handle new fuel assemblies from the new fuel storage racks to the fuel elevator. The new fuel elevator is used to lower the assembly to a depth at which the hoist, using the long-handled tool, can place the new fuel assembly into or out of the fuel transfer container in the upending device. The new fuel elevator is used to lower the assembly to the bottom of the spent fuel pool to avoid immersing the hoist block and cable in the spent fuel pool water. Decay heat, generated by the spent fuel assemblies in the spent fuel pool, is removed by the spent fuel pool cooling system. After a sufficient decay period, the spent fuel assemblies are removed from the spent fuel racks and loaded into spent fuel shipping casks for removal from the site.

9.1.4.2.2 Refueling Procedure

The refueling operation follows a detailed procedure which provides a safe, efficient refueling operation. Prior to initiating refueling operations, the reactor coolant system (RCS) is borated to the cold shutdown boron concentration and cooled down to the refueling shutdown conditions specified in the Technical Specifications. Criticality protection for

refueling operations, including a requirement for daily checks

BVPS-2 UFSAR Rev. 13 9.1-17 of boron concentration, is specified in the Technical Specifications (Chapter 16). The following significant points are assured by the refueling procedure:

1. The refueling water and the reactor coolant contain a minimum of 2,400 ppm boron. This concentration is sufficient to keep the core approximately 5 percent

k/k subcritical during the refueling operations. It is also sufficient to maintain the core subcritical in the unlikely event that all of the RCCAs were removed

from the core.

2. The water level in the refueling cavity keeps the radiation level within acceptable limits while fuel assemblies are being removed from and inserted into the core.

The refueling sequence is controlled by the Refueling Procedure. The sequence is based on the current Westinghouse fuel cycle loading plans, fuel handling specifications and the scheduled refueling operations.

The reactor fuel may be refueled in one of two ways. The core offload or the core shuffle. The core offload removes all of the fuel assemblies from the core, performs the insert changeouts, and then reloads the desired fuel assemblies into the core. The core shuffle, simultaneously offloads the spent fuel, performs fuel insert changeouts, and reloads the new fuel. These variations in the refueling sequence are necessary to support major maintenance on the reactor and reactor support systems, fuel handling, fuel insert changeouts and fuel

inspection considerations, and to optimize the outage schedule. Both the core shuffle and offload are performed with the

equipment described as follows: The manipulator crane transports fuel assemblies to and from the reactor, RCC change fixture and fuel transfer system upender. Fuel assemblies are lifted to a predetermined height sufficient to clear the reactor vessel and still leave sufficient water

covering the fuel assembly. This limits any radiation hazard to the operating personnel. Limit switches are provided to ensure that the fuel assembly is in the fully up position before the

manipulator crane can be moved. The fuel transfer system transports fuel assemblies to and from the manipulator crane and motor-driven platform crane. The fuel assembly container of the fuel transfer car is pivoted to the vertical position by the upender. The manipulator crane is moved to line up the spent fuel assembly with the fuel assembly container. The manipulator crane loads the spent fuel assembly into the fuel assembly container of the transfer car. The container is pivoted to the horizontal position by the upender. The fuel transfer car with the fuel container is moved through the fuel transfer tube to the

BVPS-2 UFSAR Rev. 2 9.1-18 fuel storage area. At the fuel storage area the fuel assembly container is pivoted to the vertical position. This sequence is reversed to transport fuel assemblies to containment.

The motor-driven platform crane transports the fuel assemblies to and from the fuel transfer system and spent fuel racks. The spent fuel assembly is unloaded from the container by the spent fuel handling tool attached to the motor-driven platform crane. The spent fuel assembly is placed in a spent fuel storage rack.

The motor-driven platform crane also transports new fuel assemblies to and from the new fuel storage racks, fuel transfer system, and the spent fuel storage racks. This is accomplished with the use of the new and spent fuel assembly handling tools and the new fuel elevator. New fuel assemblies are usually staged in the spent fuel pool prior to the core offload or core

shuffle. The motor-driven platform crane, with the appropriate handling tool is used to install and remove any of the fuel assembly inserts. This operation is performed either during the fuel shuffle or between the core offload and reload.

The RCC change fixture can be used to changeout RCCA inserts and inserts with RCCA type hubs. If the spent fuel assembly contains an RCC type unit, the fuel assembly may be placed in the RCC changing fixture by the manipulator crane. The RCC type insert is removed from the spent fuel assembly and put in a new

fuel assembly or into another spent fuel assembly that had been previously placed in the changing fixture.

BVPS-2 UFSAR Rev. 12 9.1-19 9.1.4.2.3 Component Description 9.1.4.2.3.1 Manipulator Crane

The manipulator crane is a rectilinear bridge and trolley system with a vertical mast extending down into the refueling cavity. The bridge spans the refueling cavity and runs on rails set into the edge of the refueling cavity. The bridge and trolley servo system is used to position the vertical mast over a fuel assembly in the core. A long tube with a pneumatic gripper on the end is lowered out of the mast to grip the fuel assembly. The gripper tube is long enough so that the upper end is still contained in the mast when the gripper end contacts the fuel. A

hoist mounted on the trolley raises the gripper tube and fuel assembly into the mast tube. The fuel is transported while inside the mast tube.

All controls for the manipulator crane are mounted in a console on the trolley. The bridge and trolley are positioned in relation to a grid pattern referenced to the core by an X-Y servo system. The design capacity of this crane is 2.25 tons. Bridge and trolley position is indicated by an electric position

repeat back system. Readout dials are read directly by the operator at the console. The drives for the bridge, trolley, and hoist are variable speed types and include a separate

inching control on the bridge and trolley. The maximum speed for the bridge is 40 feet per minute (fpm) and for the trolley and hoist is 20 fpm. The auxiliary monorail hoist on the

manipulator crane has a two-step magnetic controller to give hoisting speeds of approximately 7 fpm and 20 fpm.

Electrical interlocks and limit switches on the bridge and trolley drives prevent damage to the fuel assemblies. The hoist is also provided with redundant limit switches to prevent a fuel assembly from being raised above the safe shielding depth should the limit switch fail. In an emergency, the bridge, trolley, and hoist can be operated manually, using a handwheel on the

motor shaft. The manipulator crane is designed to permit the handling of thimble plugs using a tool supported from the auxiliary hoist, which is rated at 1.5 tons.

9.1.4.2.3.2 Motor-Driven Platform Crane

The motor-driven platform crane is a gantry type, multiple girder, electric traveling crane with two top-running trolleys that run on parallel sets of bridge rails, and with a lower

operating platform extending the span of the crane. The motor-driven platform crane operates over the spent fuel pool, the spent fuel cask loading area, fuel transfer canal, new fuel storage area, and the new fuel receiving area. The capacity of the gantry platform is 20 tons, with each trolley and hoist having a capacity of 10 tons.

The motor-driven platform crane is seismically designed, meets all requirements of Crane Manufacturers Association of America (CMAA) BVPS-2 UFSAR Rev. 2 9.1-20 Specification No. 70 for Class C moderate service, and meets all mandatory requirements of ANSI B30.2.0. Each crane motion utilizes a variable speed control, with a speed regulation of at least 10 to 1, to provide for gradual acceleration and deceleration. Each hoist has a load indicating and limiting system and is provided with upper and lower travel limit switches.

The motor-driven platform crane is equipped with two single pendant stations having controls and indicators for all motions

of the gantry platform, trolley, and hoists. The pendants are suspended from each trolley unit. Interlocks are furnished to prevent platform and trolley movement while the hoists are being operated. An alarm bell is sounded to indicate if the load indicator exceeds its preset weight.

The hoist motors are provided with thermal detectors which trip the motor in the event of overheating. The trip will automatically reset itself upon motor cool-down.

One hoist is primarily used for handling new fuel and the other is for spent fuel. The west trolley is designated as the new fuel hoist. It utilizes the new fuel assembly handling tool to lift and transfer new fuel from the new fuel shipping container to the new fuel storage racks, and then from these storage racks to the fuel elevator. The east trolley is designated as the spent fuel hoist. The spent fuel hoist is dual rated for 10 and 2 tons. The dual rating is dependent upon which hook is installed. A two ton clevis type hook is used for handling fuel assemblies and the various refueling tools and is normally installed on the hoist. A ten ton hook is used to handle loads greater than two tons and is normally stored. The spent fuel hoist utilizes the spent fuel assembly handling tool to lift and transfer spent fuel from the fuel transfer system in the fuel

transfer canal to the spent fuel storage racks, and then from these storage racks to the spent fuel shipping cask. This hoist unit can also transfer new fuel from the fuel elevator to the upended transfer car utilizing the same spent fuel assembly handling tool.

The high hook interlock elevations of the platform hoists are such that with the spent fuel assembly handling tool attached, a spent fuel element cannot be raised above a safe shielding

depth. 9.1.4.2.3.3 Fuel Elevator

The fuel elevator includes an electric winch located at the edge of the fuel pool and a fuel assembly carriage located in the

fuel pool. The carriage runs on tracks which extend vertically along the wall of the fuel pool. New fuel is loaded into the elevator at the raised position. The fuel is then lowered to the bottom of the pool and is removed using the spent fuel hoist and the spent fuel assembly handling tool. The design capacity of the elevator which is BVPS-2 UFSAR Rev. 14 9.1-21 2,600 pounds. The design capacity of the fuel assembly carriage is 2,000 pounds (125 percent of assembly weight). The maximum hoisting and lowering speed of the elevator carriage is 10 fpm. The fuel elevator carriage and tracks are designed to withstand

full SSE seismic loads. 9.1.4.2.3.4 Fuel Transfer System

The FTS (Figure 9.1-6) includes an electric motor-driven winch cable drive, an underwater transfer car that runs on tracks extending from the refueling canal through the transfer tube and into the spent fuel pool, and an operator-actuated upender at each end of the transfer tube. The fuel container in the

refueling canal receives a fuel assembly in the vertical position from the manipulator crane. The fuel container is then lowered to a horizontal position for passage through the transfer tube. After passing through the tube, the fuel container is raised to a vertical position for removal of the fuel assembly by the spent fuel handling tool suspended from the east hoist mounted on the motor-driven platform crane in the spent fuel pool. The motor-driven platform crane then moves to a storage position and places the spent fuel assembly in the

spent fuel storage racks. During reactor operation, the transfer car is stored on the reactor side of the transfer tube. A blind flange is bolted on the refueling canal end of the transfer tube to seal the reactor containment. The terminus of the tube outside the containment

is closed by a gate valve. 9.1.4.2.3.5 Rod Cluster Control Changing Fixture

The RCC changing fixture is supplied for periodic RCC element inspections and for transfer of RCC elements from one fuel assembly to another. The major subassemblies which comprise the changing fixture are the frame and track structure, the carriage, the guide tube, the gripper, and the drive mechanism.

The carriage is a moveable container supported by the frame and track structure. The tracks provide a guide for the four flanged carriage wheels and allows horizontal movement of the carriage during changing operation. The positioning stops on both the carriage and frame locates each of the three carriage compartments directly below the guide tube. Two of these compartments are designed to hold individual fuel assemblies while the third is made to support a single RCC element. Situated above the carriage and mounted on the refueling canal wall is the guide tube. The guide tube provides for the guidance and proper orientation of the gripper and RCC element as they are being raised and lowered. The gripper is a

pneumatically-actuated mechanism responsible for engaging the RCC element. It has two flexure fingers which can be inserted into the top of the RCC element when air pressure is applied to

the gripper piston. Normally, the fingers are locked in a radially extended position. Mounted on the operating deck is the drive mechanism assembly which consists of the manual carriage drive mechanism, the revolving stop operating handle, the BVPS-2 UFSAR Rev. 17 9.1-22 pneumatic selector valve for actuating the gripper piston, and the electric hoist for elevation control of the gripper. 9.1.4.2.3.6 Spent Fuel Assembly Handling Tool

The spent fuel assembly handling tool is used to handle new and spent fuel assemblies in the spent fuel pool. It is a manually-actuated tool, suspended from the motor-driven platform crane, that uses four cam-actuated latching fingers to grip the underside of the fuel assembly top nozzle. The operating handle to actuate the fingers is located at the top of the tool. When the fingers are latched, a pin is inserted into the operating handle to prevent the fingers from being accidentally unlatched

during fuel handling operations. 9.1.4.2.3.7 New Fuel Assembly Handling Tool

The new fuel assembly handling tool is used to lift and transfer fuel assemblies from the new fuel shipping containers to the new

fuel storage racks and to transfer fuel assemblies from the new fuel storage racks to the fuel elevator. It is a manually-actuated tool, suspended from the motor-driven platform crane, that uses four cam-actuated latching fingers to grip the underside of the fuel assembly top nozzle. The operating handles to actuate the fingers are located on the side of the tool. When the fingers are latched, the safety screw on the handle post is turned in to prevent the accidental unlatching of the fingers.

9.1.4.2.3.8 Reactor Vessel Stud Tensioner

The stud tensioners are employed to secure the head closure joint at every refueling. The stud tensioner is a hydraulically-operated device that uses oil as the working fluid. The device permits preloading and unloading of the reactor vessel closure studs at cold shutdown conditions. Stud tensioners minimize the time required for the tensioning or

unloading operation. A single hydraulic pumping unit operates the tensioners, which are hydraulically connected in series.

The studs are tensioned to their operational load in two steps

to prevent high stresses in the flange region and unequal loadings in the studs. Relief valves on each tensioner prevent over-tensioning of the studs due to excessive pressure.

BVPS-2 UFSAR Rev. 2 9.1-22a 9.1.4.2.3.9 RCC (Portable) Change Tool The rod cluster control (RCC) change tool is a device used to remove an RCC from one fuel assembly and transfer it to another in the spent fuel pit. During use, this tool is supported from the spent fuel pit bridge hoist and is designed to operate from the bridge walkway.

The RCC change tool consists of three basic assemblies. The first is the guide tube. Guide plates in the lower end of the tube provide guidance for the gripper and the RCC. The upper portion of the guide tube has guides that orient and align the gripper assembly as the RCC is removed from the fuel assembly.

Second, above the guide tube is the support tube that gives the proper length to the tool and provides support for the gripper actuator and protection for the lift cable. The gripper actuator consists of a pneumatic system that provides for the engagement and disengagement of the latch mechanism to the RCC

spider. A limit switch will indicate the engage or disengage position for the gripper actuator as an additional safety feature. Third, the drive mechanism consists of an electric-powered winch and an enclosure with controls for gripper actuation and winch operation. Limit switches prevent winch over-travel in either direction, and an overload switch protects the system during RCC lifting operations. Lamps on the enclosure face display the

status of all switches. The bottom of the tool is equipped with locating pins to orient

the tool with respect to the fuel assembly nozzle. The RCC tool is lowered onto a fuel assembly in the spent fuel racks. The gripper is then inserted into the RCC hub and activated to engage. The gripper and RCC are withdrawn from the fuel assembly and into a guide structure in the lower portion of

the tool. Once the RCC is fully withdrawn from the fuel, the tool is raised to permit movement to another fuel assembly. The tool is then lowered into the top nozzle of the other fuel assembly, the RCC is inserted into the fuel, and the gripper mechanism is

disengaged. 9.1.4.2.4 Applicable Design Codes

The design codes and standards used for the fuel handling system (FHS) are given in Section 9.1.4.3 and in Table 3.2-1. BVPS-2 UFSAR Rev. 0 9.1-23 9.1.4.3 Safety Evaluation 9.1.4.3.1 Safe Handling

9.1.4.3.1.1 Design Criteria for the Fuel Handling System The primary design requirement of the manipulator crane, fuel elevator, and motor-driven platform crane is reliability and

safety. A conservative design approach is used for all load

bearing parts. Where possible, components are used that have a

proven record of reliable service. Throughout the design, consideration is given to the fact that the cranes and hoists will spend long idle periods stored in an atmosphere of 105 F and high humidity. The design and fabrication of the manipulator crane is in accordance with the CMAA Specification No. 70 for Class Al service, and Class C for the motor-driven

platform crane. Seismic considerations are discussed in Section 9.1.4.3.2. All components critical to the operation of the cranes and parts which could fall into the reactor are positively restrained from loosening. Fasteners above water that cannot be lock-wired or tack welded are coated with a locking compound.

9.1.4.3.1.2 Industrial Codes and Standards Used

Manipulator crane and motor-driven platform crane: applicable sections of CMAA Specification No. 70.

Structural: manipulator crane: AISC Specification for the Design, Fabrication, and Erection of Structural Steel for Buildings. Motor-Driven Platform Crane: ANSI 30.2, 7th

Edition. Electrical: manipulator crane: applicable standards and requirements of the National Electric Code (NFPA 70 1975) and NEMA Standards MGI and ICS are used in the design, installation, and manufacturing of all electrical equipment; motor-driven

platform crane: NEC Article 670, NEMA MG1, and NEMA IS1.1 1977. Materials: manipulator crane: main load supporting materials

are procured with certified chemical and physical properties. Safety: manipulator crane: Occupational Safety and Health Act (OSHA) Standards 29 CFT 1910 and 29 CFT 1926, including load testing requirements, the requirements of ANSI N.18.2, Regulatory Guide 1.29, 10 CFR 50, Appendix A, and GDC 61 and 62; Motor-driven Platform Crane: OSHA Standard 29 CFT 1910 and CFT 1926. 9.1.4.3.1.3 Manipulator Crane The manipulator crane design includes the following provisions

to ensure safe handling of fuel assemblies:

BVPS-2 UFSAR Rev. 0 9.1-24 1. Electrical interlocks

a. Bridge, trolley, and hoist drives are mutually interlocked, using redundant interlocks to prevent simultaneous operation of any two drives and therefore, can withstand a single failure.

b. Bridge and trolley drive operation is prevented except when the gripper tube up position switches are actuated. The interlock is redundant and can

withstand a single failure.

c. A gripper interlock is supplied which prevents the opening of a solenoid valve in the air line to the gripper except when a zero suspended weight is indicated by a force gage. As backup protection

for this interlock, the mechanical weight-actuated lock in the gripper prevents operation of the gripper under load even if air pressure is applied to the operating cylinder. This interlock is redundant and can withstand a single failure.

d. Two redundant excessive suspended weight switches open the hoist drive circuit in the up direction when the loading is in excess of 110 percent of a fuel assembly with control rod weight. The interlock is redundant and can withstand a single failure. e. An interlock for the hoist-gripper position in the hoist drive circuit in the up direction permits the hoist to be operated only when either the engaged or disengaged indicating switch on the gripper is actuated. The hoist-gripper position

interlock consists of two separate circuits that work in parallel such that one circuit must be closed for the hoist to operate. If one or both interlocking circuits fail in the closed position, an audible and visual alarm on the console is actuated. The interlock is not redundant but can withstand a single failure since both an interlocking circuit and the monitoring circuit must fail to cause a hazardous condition.

2. Bridge and trolley hold-down devices Both manipulator crane bridge and trolley are horizontally restrained on the rails by two pairs of guide rollers, one pair at each wheel location on one truck only. The rollers are attached to the bridge truck and contact the vertical faces on either side of the rail to prevent horizontal movement. Vertical

restraint is accomplished by anti-rotation bars located at each of the four wheels for both the bridge and trolley. The anti-rotation bars are bolted BVPS-2 UFSAR Rev. 0 9.1-25 to the trucks and extend under the rail flange. Both horizontal and vertical restraints are adequately designed to withstand the forces and overturning moments resulting from the SSE.

3. Design load The design load for structural components supporting the fuel assembly is the dead weight of the mast (1,000 pounds) plus three times the fuel assembly

weight (4,800 pounds).

4. Main hoist braking system The main hoists are equipped with two independent braking systems. A solenoid-release, spring-set, electric brake is mounted on the motor shaft. This brake operates in the normal manner to release upon application of current to the motor and to set when current is interrupted. The second brake is a mechanically-actuated load brake internal to the hoist gear box that sets if the load starts to overload the

hoist. It is necessary to apply torque from the motor to raise or lower the load. In raising, this motor cams the brake open. In lowering, the motor slips the brake, allowing the load to lower. This brake actuates upon loss of torque from the motor for any reason and is not dependent on any electrical

circuits. Both brakes are rated at 125 percent of the hoist design load.

5. Fuel assembly support system The main hoist system is supplied with redundant paths of load support such that failure of any one component will not result in free fall of the fuel assembly. Two wire ropes are anchored to the winch drum and carried to a load equalizing mechanism on the top of the gripper tube. The working load of fuel assembly plus gripper is approximately 3,000 pounds. The gripper itself has four fingers gripping the fuel, any two of which will support the fuel assembly weight.

The gripper mechanism contains a spring-actuated mechanical lock which prevents the gripper from opening unless the gripper is under a compressive load. During each refueling outage and prior to removing fuel, the gripper and hoist system is routinely load-tested to 125 percent of the maximum setting on the secondary hoist load limit. 9.1.4.3.1.4 Motor-Driven Platform Crane

The motor-driven platform crane design includes the following provisions to ensure safe handling of fuel assemblies: BVPS-2 UFSAR Rev. 14 9.1-26 1. Electrical interlocks

a. Bridge, trolley, and hoist interlocks are furnished to prevent platform and trolley movement

while hooks are being operated.

b. An interlock is provided to prevent lifting the fuel transfer system upender if the platform crane is nearby.

c. Each hoist load indicating device has an adjustable interlock which will stop hoist motion and sound an alarm if the preset weight is exceeded. The set point is based upon the weight of a single fuel assembly.

d. The platform and trolleys are interlocked to provide a signal to the crane operator whenever the crane travels over the upender area.

2. Seismic requirements

The crane bridge and trolleys are provided with suitable restraints so that they do not leave their

rails during an SSE.

3. Hoist braking system Each hoist has a control brake compatible with the motor controller and two load holding brakes. The load holding brakes consist of two independent, spring-set, electrically released brakes.

9.1.4.3.1.5 Fuel Transfer System

The following safety features are provided for in the fuel transfer system:

1. Transfer car permissive switch A transfer car permissive switch allows an operator on either the spent fuel pit side or containment side to control the car movement if conditions visible to the operator warrant such control. Transfer car operation is possible only when both upenders are in the down position, as indicated by the proximity switches. The load system and upender frame up proximity switch are the backups for the transfer car upender interlock. Assuming the fuel container is in the upright position

in the containment and the upender interlock circuit fails in the permissive condition, neither operator can operate the car because of the permissive switch and mechanical interlock. The interlock can withstand a single failure. Also, a communications system has been provided so that the transfer car operator in the fuel building can talk directly to the transfer car operator during the fuel handling process.

BVPS-2 UFSAR Rev. 14 9.1-27 2. Upender: transfer car position A proximity switch interlock allows upender operation only when the transfer car is at the respective end of its travel. This interlock can withstand a single failure since the control system determines the transfer car position.

3. Transfer car: valve open An interlock on the transfer tube valve permits transfer car operation only when the transfer tube

valve position switch indicates the valve is fully

open. 4. Transfer car: upender The transfer car upender interlock is primarily designed to protect the equipment from overload and

possible damage if an attempt is made to move the car when the fuel container is in the vertical position. This interlock can withstand a single failure since the control system determines the upender position.

5. Upender: manipulator crane The refueling canal upender is interlocked with the manipulator crane. Whenever the transfer car is located in the refueling canal, the upender cannot be operated unless the manipulator crane mast is in the full retracted position or the manipulator crane is over the core or the gripper is released and inside the core.

6. Upender: motor-driven platform crane The upender is interlocked with the motor-driven platform crane. The upender cannot be operated when

the motor-driven platform crane is nearby. 9.1.4.3.1.6 Fuel Handling Tools and Equipment

All fuel handling tools and equipment handled over an open reactor vessel are designed to prevent inadvertent decoupling from machine hooks (for example, lifting rigs are pinned to the machine hook and safety latches are provided on hooks supporting

tools). Tools required for handling internal reactor components are designed with fail safe features that prevent disengagement of the component in the event of operating mechanism malfunction. These safety features apply to the following tools:

BVPS-2 UFSAR Rev. 14 9.1-28 1. Control rod drive shaft unlatching tool The air cylinders actuating the gripper mechanism are equipped with backup springs which close the gripper in the event of loss of air to the cylinder. Air-operated valves are equipped with safety locking rings to prevent inadvertent actuation.

2. Spent fuel handling tool When the fingers are latched, a pin is inserted into the operating handle and prevents inadvertent

actuation. The tool weighs approximately 400 pounds and is pre-operationally tested at 125 percent of the weight of one fuel assembly (1,600 pounds).

3. New fuel assembly handling tool When the fingers are latched, a safety screw is engaged to prevent inadvertent actuations. The tool weighs approximately 100 pounds and is pre-operationally tested at 125 percent of the weight of

one fuel assembly (1,600 pounds).

9.1.4.3.2 Seismic Considerations

The safety classifications for all fuel handling and storage equipment are listed in Table 3.2-1. These safety classes provide criteria for the seismic design of the various components. Class 1 and Class 2 equipment is designed to withstand the forces of the OBE and SSE. For normal conditions plus OBE loadings, the resulting stresses are limited to the allowable working stresses, as defined in ASME Section III, Appendix XVII, Subarticle XVII-2200, 1971 up to and including Winter 1972 addenda, for normal and upset conditions. For normal conditions plus SSE loadings, the stresses are limited to within the allowable values given by ASME III, Subarticle XVII-2110, for those critical parts which are required to maintain the capability of the equipment to perform its safety function. Permanent deformation is allowed for the loading combination, which includes the SSE to the extent that there is no loss of safety function.

The Class 3 fuel handling and storage equipment satisfies the Class 1 and Class 2 criteria given previously for the SSE. Consideration is given to the OBE only insofar as failure of the

Class 3 equipment might adversely affect Class 1 or 2 equipment. For non-nuclear safety (NNS) class equipment, design for the SSE

is included if its failure might adversely affect a Safety Class 1, 2, or 3 component. Design for the OBE is included if failure of the NNS class component might adversely affect a Safety Class

1 or 2 component.

BVPS-2 UFSAR Rev. 5 9.1-29 9.1.4.3.3 Containment Pressure Boundary Integrity The fuel transfer tube, which connects the refueling canal (inside the reactor containment) and the fuel storage area (in the fuel building), is closed on the refueling canal side by a blind flange at all times, except during refueling operations. Two seals are located around the periphery of the blind flange

with leak-check provisions between them. 9.1.4.3.4 Radiation Shielding

During all phases of spent fuel transfer, the gamma dose rate to operating personnel due to a raised fuel assembly is less than 15 mRem/hr in accordance with the radiation zone designation on Figure 12.3-16. The three fuel handling devices used to lift spent fuel assemblies are the manipulator crane, the mo tor-driven platform crane and the new fuel elevator during top nozzle reconstitution. The manipulator crane contains positive stops which prevent the top of a fuel assembly from being raised to within a minimum of 93 inches of the water level in the refueling cavity during refueling operations. The hoist on the motor-driven platform crane moves spent fuel assemblies with a long-handled tool. Hoist travel limit switches and tool length limit the maximum lift of a fuel assembly to within a minimum of 100 inches of the water level in the fuel storage area during refueling operations. The new fuel elevator may handle partially spent fuel assemblies during top nozzle reconstitution. The hoist will have travel limits set at 108

inches (9.0 ft.) below the water level and physical stops placed at 102 inches. In addition, an area radiation monitor is mounted on the manipulator crane and will alarm on excessive radiation levels. Fuel handling accidents and the radiological consequences are discussed in Sections 15.7.4 and 15.7.5.

9.1.4.4 Tests and Inspections 9.1.4.4.1 Fuel Handling System

9.1.4.4.1.1 Manipulator Crane, New Fuel Elevator, and Rod Cluster Control Change Fixture

1. The minimum acceptable tests at the shop include the following:

a. Hoists and cables are load-tested at 125 percent of the rated load.

b. The equipment is assembled and checked for proper functional and running operation.

2. The following maintenance and checkout tests are recommended to be performed prior to using the equipment:

a. Visually inspect for loose or foreign parts and remove any dirt or grease.

BVPS-2 UFSAR Rev. 0 9.1-30 b. Lubricate wheels and exposed gears with proper lubricant.

c. Inspect hoist cables for worn or broken strands.

d. Visually inspect all limit switches and limit switch actuators for any sign of damaged or broken parts. e. Check the equipment for proper functional and running operation.

9.1.4.4.1.2 Motor-Driven Platform Crane

1. The minimum acceptable tests at the shop include the following:

a. Routine motor tests are required for all motors.

b. Each hook is load-tested to 125 percent of its design rating.

c. Magnetic particle examination of each hook is performed before and after hook load test, using

the procedure as described in ASTM A275.

d. Hoisting cables are required to have a segment of the cable pull-tested to the breaking strength.

e. Hoist gears, pinions, shafts, and assemblies are 100 percent magnetic particle-tested using the procedure as described in ASTM 138, Magnetic Particle Examination.

f. The equipment is assembled, completely wired, and tested for proper operation of each hoist drive, all interlocks, indicators, limit switches, alarms, trolley tracking, and all crane functions.

2. The following maintenance and checkout tests are recommended to be performed prior to using the equipment:

a. Perform load and running tests at 125 percent of the rated capacity of each hoist.

b. Visually inspect for loose or foreign parts and remove any dirt or grease.

c. Lubricate wheels and exposed gears with proper lubricant.

d. Inspect hoist cables for worn or broken strands.

BVPS-2 UFSAR Rev. 0 9.1-31 e. Visually inspect all limit switches and limit switch actuators for any sign of damaged or broken parts. f. Check the equipment for proper functional and running operation.

9.1.4.4.1.3 New and Spent Fuel Assemblies Handling Tools

1. The minimum acceptable tests at the shop include the following:

a. The tools are load-tested to 125 percent of the rated load.

b. The tools are assembled and checked for proper functional operation.

2. The following maintenance and checkout tests are recommended to be performed prior to using the tools:

a. Visually inspect the tools for dirt, loose hardware, and any signs of damage such as nicks

and burrs.

b. Check the tools for proper functional operation.

9.1.4.4.1.4 Fuel Transfer System

1. The minimum acceptable test at the shop includes the following:

The system shall be assembled and checked for proper functional and running operation.

2. The following maintenance and checkout tests are recommended to be performed prior to using the fuel transfer system tools.

a. Visually inspect for loose or foreign parts and remove any dirt or grease.

b. Visually inspect all limit switches and limit switch actuators for any sign of damaged or broken

parts. c. Check the system for proper functional and running operation.

9.1.4.4.1.5 Reactor Vessel Stud Tensioner

1. The minimum acceptable test at the shop includes the following:

BVPS-2 UFSAR Rev. 18 9.1-32 The tensioner is assembled and checked for proper functional and running operation.

2. The following maintenance and checkout tests are recommended to be performed prior to using the equipment.

a. Visually inspect for loose or foreign parts and remove any dirt or grease.

b. Inspect hydraulic lines for wear or damage.

c. Check the hydraulic unit for proper pressurization and for leaks occurring at operating pressure.

9.1.4.5 Instrumentation Requirements

The control systems for the manipulator crane, motor-driven platform crane, and fuel transfer system are discussed in Section 9.1.4.2.3. A discussion of additional electrical controls, such as the interlocks and main hoist braking system

for the FHS, are discussed in Section 9.1.4.3.1.

9.1.5 Overhead

Heavy Load Handling Systems

The overhead heavy load handling systems (OHLHS) consist of several crane and monorail systems located throughout the plant. They are used to handle loads heavier than a fuel assembly and

its associated handling tool during the refueling process or during equipment maintenance operations. Table 9.1-2 is a list of OHLHS that operate over the reactor, the spent fuel pool, or

in the vicinity of piping and equipment required for safe

shutdown of the plant. Table 9.1-3 lists the remaining cranes and monorails in BVPS-2 which are excluded from detailed study

because they do not operate over safety-related equipment or

equipment required for safe shutdown of the BVPS-2. A two-part

report has been submitted to the USNRC concerning NUREG-0612 (USNRC 1980). (Refer to Section 1.6 for specific reference).

Design requirements of the excluded cranes and monorails are

similar to the handling systems listed in Table 9.1-2. The Beaver Valley position on the seven (7) guidelines of NUREG-0612 section 5.1.1 on "Control of Heavy Loads" is summarized as follows: 1. Guideline 1 Requirement for Safe Load Paths: Beaver Valley has an administrative procedure that defines requirements for use and control of Safe Load Path drawings. This administrative procedure contains most of the approved Safe Load Path drawings but also allows these drawings to be contained in other approved site procedures subject to the review and revision requirements of this administrative procedure. This procedure specifies that all NUREG-0612 heavy load lifts are to be performed using approved heavy load Safe Load Path drawings. This procedure also specifies that issue of new Safe Load Path drawings and changes to existing drawings are to

BVPS-2 UFSAR Rev. 18 9.1-32a be performed per the site approved 10 CFR 50.59 change process and specifies additional NUREG-0612 requirements that must be considered in making changes to safe load path drawings.

2. Guideline 2 requirement for Load Handling Procedures: Beaver Valley has an administrative procedure that defines requirements for performance of NUREG-0612 heavy load lifts. This procedure includes a checklist that must be used for performance of all NUREG-0612 heavy load lifts that ensures the requirements of Guideline 2 are met.

3. Guideline 3 on Crane Operator Training: Beaver Valley requires all Crane Operators to be trained and qualified and the training program ensures that these personnel are trained and qualified to the requirements of ANSI/ASME B30.2 and other applicable crane standards.

4. Guideline 4 on Special Lifting Devices: The design of the Beaver Valley Unit 1 Special Lifting Devices have been evaluated and determined to be in compliance with the requirements of Guideline 4. In order to ensure continued compliance, the procedures for use of these devices requires performance of a visual examination by qualified personnel of critical welds and parts prior to the initial use each refueling outage. In addition, NDE of all major load carrying welds is performed each ten year in-service inspection interval.

5. Guideline 5 for Slings and Lifting Devices Not Specially Designed: The Beaver Valley administrative procedure for Heavy Loads and the administrative procedure for the Beaver Valley Rigging and Lifting Program both require that all other rigging equipment be designed, inspected and maintained to the applicable ANSI/ASME standards including ANSI/ASME B30.9 "Slings". In addition, the Beaver Valley administrative procedure for heavy loads requires that all slings to be used on NUREG-0612 heavy load lifts be rated for at least twice the normal required capacity to account for the potential effects of dynamic loading. This method has been determined to be conservative for accounting for the sum of both the static and dynamic loading based on the potential acceleration from the maximum crane speed of all the site cranes capable of handling NUREG-0612 heavy loads.

BVPS-2 UFSAR Rev. 18 9.1-32b 6. Guideline 6 on Crane Inspection, Testing and Maintenance: The Beaver Valley administrative procedure has a checklist required to be used for performance of all NUREG-0612 Heavy Load Lifts which includes steps to verify completion of the crane periodic inspection (within previous 12 months or prior to use) and the daily "prior to use" visual inspection. In addition, periodic inspection procedures have been generated and scheduled to ensure completion of the required periodic inspections to the requirements of the applicable ANSI/ASME standards including ANSI/ASME B30.2.

7. Guideline 7 on Crane Design: All Beaver Valley cranes that handle NUREG-0612 heavy loads have been evaluated and determined to meet the requirements of Guideline 7 on crane design.

Beaver Valley followed the Nuclear Energy Institute Document, NEI 08-05, "Industry Initiative on Control of Heavy Loads, Section on Load Drop Analyses" concerning the evaluation of reactor vessel head heavy load lifts. In response to this initiative a postulated reactor vessel closure head drop analysis was performed. For the load drop scenario, it is postulated that the closure head assembly falls and impacts flat and concentrically with the reactor vessel flange. Using a dynamic finite element model a closure head assembly drop and impact with the reactor vessel flange was simulated. The responses of the reactor vessel, reactor vessel support components and main loop piping were evaluated. The stresses and strains caused by the impact were evaluated to demonstrate acceptability based on maintaining the structural integrity of the critical components such that core cooling was not compromised and the core remains covered. The analysis qualified the postulated drop of the closure head assembly 34 feet through air onto the reactor vessel flange. The analysis followed the methodology and assumptions for conducting reactor vessel head drop analyses as provided in NEI 08-05 and endorsed by NRC Regulatory Issue Summary (RIS) 2008-28, "Endorsement of Nuclear Energy Institute Guidance for Reactor Vessel Head Heavy Load Lifts." The acceptance criteria used for the coolant retaining components, reactor vessel, piping and elbows, is taken from Appendix F, Section F-1341.2 of the ASME Code. The acceptance criteria for reactor vessel support steel were from NEI 08-05 guidance. The acceptance criteria for the concrete support bearing strength in the concrete under the reactor vessel supports was based on NEI 08-05 and ACI 349-97, Section 10.15. The acceptance criteria used from NEI 08-05 is consistent with the criteria endorsed in RIS 2008-28.

BVPS-2 UFSAR Rev. 18 9.1-32c The analysis showed that the reactor vessel, main loop piping and the steel and concrete support structure for the reactor vessel are capable of meeting the acceptance criteria under a 34 foot drop of the reactor vessel closure head assembly, through air, onto the reactor vessel flange. 9.1.5.1 Design Bases

The following design bases apply to the OHLHS:

1. Heavy load-lifting devices are designed to avoid the dropping of their loads during the lifting operation.

2. Handling equipment is designed to avoid the dropping of fuel handling devices and lifting rigs during the

lifting operation.

3. The spent fuel cask trolley, used to move the spent fuel shipping casks in and out of the fuel and decontamination building, has a limited maximum lift

height so that the shipping cask is never lifted higher than the maximum height from which the cask can

be dropped and still maintain its integrity.

BVPS-2 UFSAR Rev. 18 9.1-33 4. All components and parts of the cranes and monorails which could fall into the reactor cavity or spent fuel

pool are positively restrained from loosening.

5. Handling equipment and overhead rails that are located above safety-related systems or equipment required for safe shutdown of BVPS-2 are Seismic Category II, to the extent that they will not fail in such a manner as to damage Seismic Category I equipment in the event of

a SSE.

6. Physical safety features are provided for personnel operating the handling equipment.

7. Movement and positioning of crane hooks in the fuel building is restricted to prevent damage to certain

pieces of safety-related equipment.

8. Movement of the polar crane work platform is restricted to prevent damage to equipment attached to

the containment dome.

9. The OHLHS conforms to the requirements of GDC 4, 5, and 61. The requirements of GDC 2 are satisfied for

those cranes and monorails that operate over safety-

related systems or equipment.

9.1.5.2 System Description

The OHLHS consists of the equipment needed for the lifting and

movement of any loads heavier than a fuel assembly and its associated handling tool over the reactor core, spent fuel pool, or equipment required for safe shutdown of the plant. These movements could be made either during the refueling/fuel handling process or during plant maintenance operations. The equipment consists of the cranes and monorails listed in Table 9.1-2. Table 9.1-4 lists the loads carried by each piece of

equipment. The structures associated with OHLHS are the

containment building, fuel and decontamination building, auxiliary building, cable vault area, and the intake structure.

9.1.5.2.1 Heavy Load Handling by the Motor-Driven Platform with Hoists

All loads handled by the motor-driven platform with hoists, with respect to the fuel handling operations, are considered light loads and are covered in Section 9.1.4. However, this crane is also used for maintenance operations in the fuel building where

the loads

BVPS-2 UFSAR Rev. 12 9.1-35 9.1.5.2.3.2 Heavy Load Lifts Performed by the Polar Crane During Maintenance Operations The polar crane is also available for various maintenance operations required to service equipment in the containment building. The polar crane has the capacity to lift and transport for maintenance the reactor coolant pump (RCP) motor, the control rod drive mechanism (CRDM) ventilation fans, the residual heat removal (RHR) heat exchangers and pumps, the regenerative heat exchanger, and the reactor coolant system (RCS) loop isolation valves. Table 9.1-4 lists heavy loads lifted by the polar crane.

9.1.5.2.3.3 Heavy Load Lifts Performed by the Polar Crane During Plant Outage for Refueling

The refueling operation follows a detailed procedure that provides for a safe, efficient refueling process. A typical description of the overhead heavy load handling components' movements during refueling is given as follows. Handling of light loads during the refueling process is discussed in Section 9.1.4. Load lifts made by the polar crane that are required in order to dismantle the reactor prior to refueling are listed as follows.

The equipment is removed either from the reactor cavity area or the reactor head storage area, and then stored at various locations throughout the containment building. Some pieces of equipment may be moved several times during the refueling process. The following is a list of crane movements inside containment:

1. Remove CRDM horizontal ventilation ducts with supports (3) to storage.

2. Remove reactor head lifting rig spreader assembly from storage to temporary location on CRDM missile shield.

3. Remove reactor head stud carriers (6) and stud rack bases (3) to temporary storage.

BVPS-2 UFSAR Rev. 12 9.1-36 4. Move reactor head lifting rig spreader assembly to temporary storage position within the load handling path. 5. Secure and remove CRDM missile shield to storage (includes 3 sections).

6. Remove CRDM vertical ventilation ducts with supports (3) to storage.

7. Remove CRDM missile shield and support structure with electrical tray intact to storage.

8. Remove all reactor head insulation to storage.

9. Remove the internal lifting rig assembly from the upper internals storage stand to temporary storage location.

10.Deleted

11. Lower the stud tensioners and all other necessary tools and equipment required to unbolt and remove the reactor vessel head.

12. After the reactor vessel head studs have been loaded into the stud carriers, remove the carriers to storage

on the operating floor.

13. Remove the southwest rail and platform grating from above the reactor head storage area to temporary storage.

14. The reactor vessel head is lifted slightly to check for levelness. If the closure head is not level, the head is set back on the vessel and the head lifting device sling assembly is adjusted. This procedure is repeated until the head is level when lifted. While monitoring the load cell the reactor head is lifted enough to verify that the P/L RCC element drive shafts are locked out and the F/L RCC CRDS are clear of the thermal sleeves. The reactor closure head may then be lifted out of the refueling cavity to the reactor head storage stand at el 692 ft-11 in.

15. Replace the southwest section of the manipulator crane rail and platform grating in position using the polar crane.

BVPS-2 UFSAR Rev. 11 9.1-37 16. The CRDM shafts are disconnected, and with the upper internals, are removed from the vessel using the internals lifting rig assembly to a storage stand in the refueling cavity.

17. Should the lower internals need to be removed from the reactor, all of the fuel assemblies must be removed from the reactor, as described in Section 9.1.4. Then the internals lifting rig assembly is used to lift the lower internals and place them on a storage stand in

the refueling cavity.

Reactor assembly following refueling is essentially achieved by

reversing the sequence of operations described above.

BVPS-2 UFSAR Rev. 0 9.1-39 vessel and refueling cavity, the three steam generator cubicles, and the el 767 ft 10 in operating floor. The capacity of the bridge is 334 tons, with each trolley and hoist having a capacity of 167 tons. An auxiliary hoist having a capacity of 15 tons is

located on Trolley No. 1. The polar crane is seismically designed and meets all requirements of CMAA Specification No. 70 for Class A1, moderate service, and meets all mandatory requirements of ANSI B30.2-1967. The bridge and trolley motions have infinitely variable speed controls, with a speed regulation of 10 to 1 to provide for gradual acceleration and deceleration. Each hoist has five speed-set points to allow for raising and lowering of loads at preselected speeds, and is provided with upper and lower travel limit switches.

The polar crane is equipped with a telescoping work platform located on top of Trolley No. 2 to provide access to the containment spray header nozzles. A pendant station having controls for movement of the work platform, trolley, and main bridge is provided to allow for control of the crane motion from this location.

Electrical interlocks are provided as described in Section 9.1.5.5.2.1.

Each hoist is provided with two sets of brakes that each provide 150 percent of their respective motor full load torque. The bridge brakes have a torque rating of at least 100 percent of the rated full load torque of the bridge motors. The trolley motors have brakes rated at 100 percent of the full rated motor torque.

The main hoists are used primarily during plant outages for refueling or maintenance purposes. The hoists use two special lifting devices to lift the reactor head and the internals. These lifting rigs attach to one of the polar crane hooks for use. For other lifts, field-supplied rigging is used for lifting

the loads. The auxiliary hoist is used for various maintenance lifts and lifts made during the refueling procedure to move tools and equipment (Section 9.1.4).

9.1.5.3.2 Spent Fuel Cask Trolley

The spent fuel cask trolley is an overhead type, multiple girder, electric traveling crane with a main trolley and auxiliary bridge on parallel sets of bridge rails, with a lower operating cab connected to the crane. The spent fuel cask trolley operates in the east end of the fuel building and in the decontamination building, which includes the spent fuel cask loading area and the cask washdown area. The capacity of the trolley is 125 tons, with a 30 ton auxiliary bridge.

The spent fuel cask trolley meets all requirements of CMAA Specification No. 70 for Class A1 standby service, all mandatory requirements of ANSI B30.2-1976, and Regulatory Guide 1.13. Each

BVPS-2 UFSAR Rev. 12 9.1-40 crane motion utilizes five steps of variable speed control to provide for the required control when moving loads. With the exception of the auxiliary trolley motion which is controlled by a two-speed, dual wound motor, each crane motion is provided with a separate inching motor for continuous inching speeds. The main trolley inching speed and auxiliary trolley slow speed are identical. Each hoist has a load-indicating and limiting system and is provided with upper and lower travel limit switches, which prevent the cask from being lifted higher than 30 feet at any time during its travel.

All inching motor circuits are interlocked such that the inching motors cannot be operated unless the main hoist, auxiliary

hoist, and main trolley are essentially at rest. The hoist motors are provided with thermal detectors which trip

the motor in the event of overheating. The trip will automatically reset itself upon motor cooldown.

The primary use of the main hoist and trolley is to upend and transfer the spent fuel shipping cask, that weighs approximately 100 tons, from the rail car into the fuel building for loading, and then returning the cask to a rail car for shipment from the site. The auxiliary hoist and trolley are used primarily for various small load lifts that may be required in the

decontamination and fuel building areas. 9.1.5.3.3 Motor-Driven Platform Crane

The motor-driven platform crane is a gantry type, multiple girder, electric traveling crane with two top moving trolleys

moving on parallel sets of bridge rails, and with a lower operating platform crane extending the span of the crane. The motor-driven platform crane operates over the spent fuel pool or

pit, which includes the spent fuel cask loading area and fuel transfer canal, over the new and spent fuel storage areas, and over the new fuel receiving area. The capacity of the gantry

platform is 20 tons, with each trolley and hoist having a capacity of 10 tons. The Licensing Requirements Manual contains limits for the maximum weight of any load which can be carried over the spent fuel pool. The motor-driven platform crane is seismically designed, and

meets all requirements of CMAA Specification No. 70 for Class C moderate service and ANSI B30.2-1976. Each trolley motion utilizes a variable speed control with a speed regulation of at

least 10 to 1 to provide for a gradual acceleration and deceleration. Each hoist has a load indicating and limiting system and is provided with upper and lower travel limit

switches. The motor-driven platform crane is equipped with two single pendant stations having controls and indicators for all motions of the gantry platform, trolleys, and hoists. The pendants are suspended from each trolley unit.

BVPS-2 UFSAR Rev. 0 9.1-41 Interlocks are furnished to prevent platform and trolley movement while the hooks are being operated. If the load indicator exceeds its preset weight, an interlock stops the hoist and sounds an alarm to alert the operator. The hoist motors are provided with thermal detectors which trip the motor in the event of overheating. The trip will automatically reset itself upon motor cooldown.

One hoist is primarily used for handling new fuel and the other for spent fuel. Section 9.1.4 describes the lifts made by these

hoists during the fuel transfer operation. 9.1.5.3.4 Monorail Systems

The monorail systems listed in Table 9.1-2 are all manual or electric trolley and hoist drives. The monorails operate over specific plant areas or over equipment that requires maintenance. A list of the heavy loads lifted by the monorails is included in Table 9.1-4. All monorail systems included in Table 9.1-2 are designed t o comply with the Monorail Manufacturers Association (MMA) No. 61, Specifications for Underhung Cranes and Monorail Systems. In addition, all mandatory requirements of ANSI B30.11-1973 and ANSI B30.16-1973 are met by the design of the monorails.

The electrified monorail systems have maximum hoisting speeds based on the hoist rated load. Each hoist has a load limiting

device to prevent hoist overload, and is provided with upper and lower travel limit switches.

The electrified monorail systems are provided with a single pushbutton pendant station having controls and indicators for all motions of the hoist and trolley. The pushbutton pendants are suspended from the tractor unit. Each chain hoist has a limiting device such that when an overload situation occurs, the chain wheel will revolve, but without further raising of the

load. Each monorail that is located over safety-related equipment is equipped with mechanical rail stops to ensure that the trolley is not stored over the safety-related equipment during operation.

9.1.5.3.5 Screenwell Crane

The screenwell crane, provided by BVPS-1, is an electric, overhead bridge type, traveling crane with a top running trolley. It is located in the intake structure and services the traveling screen areas, the raw water pumps, river water pumps, and the BVPS-2 service water pumps.

The screenwell crane meets all requirements of ANSI B30.2-1967, Overhead and Gantry Cranes, and Electric Overhead Crane Institute (EOCI) No. 61, Specification for Electric Overhead

Traveling Cranes for Class A Standby Service.

BVPS-2 UFSAR Rev. 0 9.1-44 1. Electrical interlocks

a. Interlocks are furnished such that when the work platform is in a raised position, it is impossible for the platform operator to bring the platform or its handrails into contact with either the containment dome or spray nozzles by either

traversing the trolley or by raising the platform.

b. Interlocks are provided to permit crane operation from only one location, the cab, or work platform.

c. Interlocks are provided to prevent operation of the crane's normal cab control when the platform is raised above its fully retracted position.

2. Seismic requirements The polar crane bridge and trolley are provided with suitable restraints so that they do not leave their rails during SSE, thus meeting Seismic Category II design criteria. Also, no part of the crane shall

become detached and fall during an SSE.

3. Main hoist braking system Eddy current control brakes are provided for hoisting and lowering motions. Each of the hoists are also

provided with independent shoe-type brakes that are automatically applied to the motor shaft when the motor is de-energized. Additionally, each of the hoists is provided with a backup shoe brake with a delayed action to prevent simultaneous application of shoe-type brakes at once. Both sets of these shoe-

brakes are rated at 150 percent of the motor full load torque. 9.1.5.5.2.2 Spent Fuel Cask Trolley The spent fuel cask trolley design include the following

provisions to ensure safe handling of spent fuel shipping casks:

1. Electrical interlocks

a. Track-type limit switch interlocks are provided for the rolling steel doors and main trolley runway to prevent the spent fuel cask trolley from passing through the doorway unless the door is in the fully open position.

b. Interlocks are provided to limit the maximum raised height of the rail or truck spent fuel cask

to 30 feet or less. BVPS-2 UFSAR Rev. 2 9.1-44a c. Each hoist is provided with an overload cutoff which senses the load on the hoist and stops the hoisting motion if the preset weight is exceeded. The preset weight is determined in accordance with

administrative procedure.

2. Seismic requirements The trolley system is provided with suitable restraints so that it does not leave the rails during an SSE, thus meeting Seismic Category II design criterion. Also, the trolley

BVPS-2 UFSAR Rev. 12 9.1-45 system is designed so that no part of the trolley system can become detached and fall during an SSE.

3. Main hoist braking system Eddy current control is provided for the hoisting and lowering motions. Each of the hoists is also provided with independent shoe-type brakes that are automatically applied to the motor shaft when the motor is de-energized. Additionally, each of the hoists is provided with a backup shoe brake with a delayed action to prevent simultaneous application of both shoe-type brakes at once. Both sets of these

shoe brakes are rated at 150 percent of the motor full load torque. 9.1.5.5.2.3 Motor-Driven Platform Crane The motor-driven platform crane design includes the following

provisions to ensure safe handling of fuel assemblies:

1. Electrical interlocks

a. Interlocks are furnished to prevent platform and bridge trolley movement while hooks are being operated.

b. An interlock is provided to prevent lifting the fuel transfer system upender if the platform crane is nearby.

c. Each hoist load indicating device has an adjustable interlock which will stop hoist motion and sound an alarm if the preset weight is

exceeded.

d. The platform and trolleys are interlocked to provide a signal to the crane operator whenever the crane travels over the upender area.

2. Seismic requirements The crane bridge and trolleys are provided with suitable restraints so that they do not leave their rails during an SSE, thus meeting Seismic Category II design criteria. No part of the crane will become detached and fall during an earthquake. In addition, the crane is designed so that a fuel element does not lower in an uncontrolled manner during or as the

result of an earthquake.

BVPS-2 UFSAR Rev. 0 9.1-46 3. Hoist braking system Each hoist has a control brake compatible with the motor controller and two load holding brakes. The load holding brakes consist of two independent spring-set, electrically released brakes. Each holding brake has the capacity to stop 150 percent of the full load

motor torque at any speed up to 200 percent of the rated speed.

4. Trolley braking system

The trolley motors are equipped with disc type brakes capable of sustaining 50 percent of the rated full load torque of the motors. A loss of electrical power automatically applies the trolley brakes to the motor

shafts. 9.1.5.5.2.4 Monorail Systems

The monorail systems listed in Table 9.1-2 have several design features to ensure safe handling of heavy loads.

1. Load limiting switches are included to prevent an overload on the hoisting mechanism.

2. Upper and lower travel limit switches are provided to restrict the raising and lowering of loads to

predetermined safe levels.

3. The hoisting ropes and cables and all other load carrying parts such as the track, fittings, hangers, and load chains are designed so that the maximum applied load does not exceed 20 percent of the

ultimate strength of the material.

4. The track for all patented track monorail systems have a specially rolled lower carrying flange meeting the requirements of the MMA Specification No. 61.

5. Each electric hoist is provided with an independent disc or shoe-type motor holding brake which is automatically applied when the motor is de-energized.

This brake has a rated braking torque of 150 percent of the motor full load torque. A load control mechanical load break is also provided for each hoist. This brake is capable of holding 125 percent of the rated load and is externally adjustable.

6. Rail stops will be used to hold trolleys in a safe location while not in use.

BVPS-2 UFSAR Rev. 0 9.1-48 d. Tests to verify proper auxiliary trolley tracking, bridge electrification, and auxiliary trolley drive operation.

e. The main and auxiliary hooks are load-tested at 125 percent of its design rating.

2. During maintenance, the following items are checked.

a. Visually inspect for loose or foreign parts and remove any dirt or grease.

b. Lubricate wheels and exposed gears with proper lubricant.

c. Inspect hoist cables for worn or broken strands.

d. Visually inspect all limit switches and limit switch actuators for any sign of damaged or broken parts. e. Check the equipment for proper functional and running operation.

9.1.5.6.3 Motor-Driven Platform Crane

1. The following include shop testing of the crane:

a. Routine motor tests for all motors.

b. Each hook is load-tested to 125 percent of its design rating.

c. Magnetic particle examination of each hook before and after hook load-testing.

d. Hoisting cables are required to have a segment of the cable pull-tested to the breaking strength.

e. Hoist gears, pinions, shafts, and assemblies are 100-percent magnetic particle tested.

f. The equipment is assembled, completely wired and tested for proper operation of each hoist drive, all interlocks, indicators, limit switches, alarms, trolley tracking, and all crane functions.

2. During maintenance, the following items are checked.

a. Visually inspect for loose or foreign parts and remove any dirt or grease.

BVPS-2 UFSAR Rev. 0 9.1-49 b. Lubricate wheels and exposed gears with proper lubricant.

c. Inspect hoist cables for worn or broken strands.

d. Visually inspect all limit switches and limit switch actuators for any sign of damaged or broken parts. e. Check the equipment for proper functional and running operation.

9.1.5.6.4 Head Lifting Rig and Internals Lifting Rig

1. The minimum acceptable test at the shop includes the following:

a. Load test to 125 percent of the rated load.

b. Inspect assembly to ensure proper component fit up. 2. During maintenance, the following items are checked.

a. Visually inspect for loose or foreign parts or damaged surfaces and remove any dirt or grease.

b. Visually inspect all engagement surfaces and lubricate with proper lubricant.

c. On the internals lifting rig, check for the proper functioning of the engagement and protection rig operators.

9.1.5.6.5 Screenwell Crane

1. The following include shop and field testing of the crane: a. No-load running test of all crane motions.

b. Loaded running test of all crane motions.

2. After erection, the crane will, be completely lubricated in accordance with the manufacturers instructions.

9.1.5.6.6 Monorail Systems

1. The following include shop testing of the monorails:

a. Routine motor tests on all motors.

b. All hooks magnetic particle tested.

BVPS-2 UFSAR Tables for Section 9.1

BVPS-2 UFSAR Rev. 16 1 of 2 TABLE 9.1-1 FUEL POOL COOLING AND CLEANUP SYSTEM principal components, design AND PERFORMANCE PARAMETERS

Fuel Pool Cooling Pumps (2FNC*P21A & B) Quantity 2 Rated flow (gpm) (each) 750 Total head (ft) 72 Net positive suction head required at rated flow (feet) 8 Fuel Pool Heat Exchangers (2FNC*E21A & B) Quantity 2 Operating flow, tube side (gpm) (each) 750 Operating flow, shell side (gpm) (each) 1,100 Design temperature ( F) 200 Operating temperature in, tube side ( F) 140 Operating temperature out, tube side ( F) 109.6 Operating temperature in, shell side ( F) 100 Operating temperature out, shell side ( F) 120.7 Total duty (Btu/hr) (each) 11.4 x 10Fuel Pool Purification Pumps (2FNC-P24A & B)

Quantity 2 Rated flow (gpm) (each) 400 Total head (ft) 143 Net positive suction head required (ft) 6.5 Fuel Pool Filters (2FNC-FLT21A & B)

Quantity 2 Design temperature ( F) 250 Operating temperature ( F) 140 - 200 Design pressure (psig) 150 Operating pressure (psig) 85 Design flow (gpm) (each) 450 Design differential pressure (psig) 25 Size range (microns absolute) 25 BVPS-2 UFSAR Rev. 16 2 of 2 TABLE 9.1-1 (Cont.)

Design/Performance Component Parameters

Fuel Pool Ion Exchanger (2FNC-IOE21) Quantity 1 Design pressure (psig) 150 Operating pressure (psig) 65 Design temperature ( F) 200 Operating temperature ( F) 140

BVPS-2 UFSAR Rev. 9 1 of 1 TABLE 9.1-3 OVERHEAD LOAD HANDLING SYSTEMS THAT DO NOT OPERATE OVER SAFETY-RELATED EQUIPMENT OR EQUIPMENT REQUIRED FOR SAFE SHUTDOWN

Equipment No. Identification Location 2FNR-CRN205-1 CRDM drive assembly monorail (Refueling Cavity manipulator crane - auxiliary monorail

hoist) Reactor containment 2MHK-CRN240 Radwaste bride crane Condensate polishing building 2MHK-CRN241 Demineralizer filter monorail Condensate

polishing building 2CR-35 Stop log monorail system Alternate intake structure 2MHK-CRN232 Cooling tower pump house crane Cooling tower pump

house 2MHK-CRN208 Solid waste handling crane Waste handling

building 2MHT-TR202-1 Turbine room crane Turbine building

2MHT-CRN239A,B Condenser water box cover removal hoist Turbine building 2MHT-CRN242 CCS heat exchanger removal hoist Turbine building 2MHP-CRN222 Waste gas charcoal bed tank monorail Auxiliary building 2MHP-CRN237 Waste gas surge tank monorail Auxiliary building 2MHP-CRN225 Charcoal delay bed, degasifier monorail Auxiliary building 2MHP-CRN238A,B Access slab monorails Auxiliary building

2MHZ-CRN243 Electrical equipment and installation monorail Service building

BVPS-2 UFSAR Rev. 15 1 of 4 TABLE 9.1-4 LOADS CARRIED BY EACH PIECE OF EQUIPMENT

2CRN*201 Bridge-334 Trolley No. 1-167/15 Trolley No. 2-167 Reactor vessel head & attachments (including temporary reactor vessel head shielding used during refueling) 134.5 Vessel head lifting device Reactor vessel internals (upper) 40 Internals lifting rig

assembly Reactor vessel internals (lower) 130 Internals lifting rig

assembly Reactor coolant pump-motor 40 Reactor coolant system loop isolation valve 15 Reactor head lifting rig spreader assembly

3.5 Removable

slabs 7.5 CRDM missile shield (3 sections) (total weight) and CRDM support structure* 42 Ventilation fans 1.0 Stud carriers (full) 3.6 Removable rail & beam 1.15 Removable platform north & south 3.0 *Lifted together to stored location Containment Air Recirculation Fan (Fan and motor) 3.0

BVPS-2 UFSAR Rev. 18 3 of 4 TABLE 9.1-4 (Cont.) Crane Mark No. Capacity (tons) Heavy Load Identification Load Weight (tons) Lifting Device Charging pumps-motor 1.95 2MHP-CRN221A,B 10/10 Primary component cooling water heat

exchangers (two monorails together) 17.5 2MHP-CRN223 10 Removable slabs 9.75 Cesium removal ion exchangers 0.95 Mixed bed demineralizers 0.95 Deborating demineralizers 1.4 Spent filter shipping cask 7.75 2MHP-CRN234 2 Primary component cooling water pumps 1.0 Primary Component cooling water motor 1.7 2MHP-CRN235 3 Removable slabs 2.8 CR-17 15 River water pumps 6.5 River water motors 2.7 Raw water pumps 9.3 Raw water motors 3.8 Electric fire pump 3.0 Electric fire pump-motor 2.0 Diesel fire pump 3.0 Diesel engine 1.9 Hydro-pneumatic tank 1.2 Removable covers (largest) 4.3 BVPS-2 service water pumps 11.8 (dry) BVPS-2 service water pump motors 3.4

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REFERENCE:

STATION DRAWING OM 20-1 BEAVER VALLEY POWER STATION UNIT N0.2 UPDATED FINAL SAFETY ANALYSIS REPORT REACTOR CAVITY CONiEVOR TUCIS REFUELING CANAL fUEL lSS' V COMUINER 11.[11. HO!U;!I; t:lHlfAI NHFNT WALL FUEL TRANSFER SYSTEM I I I \ S PHIT HJ£L I VLJ: *A!!i ltvH SPf NT fUf l STORAGE POOL fUH iSS' 1 CONI A I NH ( 'ERfOU TEO I SECTI OM l-A fUH TUN Sf U TUif FIGURE 9.1-6 FUEL TRANSFER SYSTEM BEAVER VALLEY POWER STATION-UNIT 2 Fl NAL SAFETY ANALYSIS REPORT BVPS-2 UFSAR Rev. 12 9.2-1 9.2 WATER SYSTEMS

9.2.1 Station

Service Water System

9.2.1.1 Main Service Water System The station service water system includes both the service water

system (SWS) (Section 9.2.1.1) and the standby service water system (SSWS) (Section 9.2.1.2).

The SWS is a safety-related system which provides cooling water to remove heat from the power plant auxiliary systems during all modes of operation. The SWS is shown on Figure 9.2-1. Table 9.2-1 lists the component design data for this system.

9.2.1.1.1 Design Bases

The SWS is designed in accordance with the following criteria:

1. General Design Criterion 2, as it relates to structures housing the system, and the system itself

being capable of withstanding the effects of natural

phenomena, such as earthquakes, tornadoes, hurricanes, and floods.

2. General Design Criterion 4, with respect to structures housing the system, and the system itself being capable of withstanding the effects of external and

internally-generated missiles, pipe whip, and jet impingement forces associated with pipe breaks.

3. General Design Criterion 5, as it relates to the capability of shared systems and components important to safety being capable of performing required safety

functions.

4. General Design Criterion 44, to assure:

a. The capability to transfer heat loads from safety-related structures, systems, and components to a

heat sink during both normal operating and accident conditions, b. Component redundancy so that the safety function can be performed assuming a single active failure coincident with the loss of offsite power (LOOP), and

c. The capability to isolate components, subsystems, or piping, if required, so that the system safety function will not be compromised.

BVPS-2 UFSAR Rev. 15 9.2-2 5. General Design Criterion 45, as it relates to design provisions made to permit inservice inspection of safety-related components and equipment.

6. General Design Criterion 46, as it relates to design provisions made to permit operational functional

testing of safety-related systems and components to

assure: a. Structural integrity and system leaktightness,

b. Operability and adequate performance of active system components, and

c. Capability of the integrated system to perform required functions during normal, shutdown, and accident situations.

7. Regulatory Guide 1.26, as it relates to the quality group classification of systems and components.

8. Regulatory Guide 1.29, as it relates to the seismic design classification of system components.

9. Regulatory Guide 1.102, as it relates to the flood protection of system components.

10. Regulatory Guide 1.117, as it relates to the tornado design classification of system components.

11. The system shall provide water during normal operation and shutdown conditions at the flow rates and temperatures required to remove the component heat loads, and to maintain the primary component cooling water (CCW) below 100F during all normal conditions and below 120F during cooldown or transient conditions.

12. The SWS is designed to handle all required heat loads at a maximum river water temperature of 89F at either extremes of low river water level (el 648 ft-7 in) or the probable maximum flood (PMF) (el 730 ft) (Section 2.4). 9.2.1.1.2 System Description The SWS is shown on Figure 9.2-1. Component design data for th e SWS is given in Table 9.2-1. Three SWS pumps are provided with the system. Two out of three SWS pumps are required for normal plant operation. During this mode of operation, each pump is considered to be a 50-percent capacity pump. Only one SWS pump is required for safe shutdown. During this mode of operation, each pump is considered to be a 100-percent capacity pump.

BVPS-2 UFSAR Rev. 19 9.2-3 Three SWS pumps supply service water to the two 30-inch SWS headers. Each pump is capable of delivering approximately

15,000 gpm. The SWS is designed with two pumps operating concurrently to supply the quantity of water needed for the essential cooling requirements for all operating conditions.

The minimum flow of service water required for safe shutdown is

shown in Table 9.2 2.

The SWS pumps are ac motor-driven vertical wet pit-type units. They are mounted above, and take suction from, three separate

sections of the intake structure. The pump motors are in cubicles which are protected from flooding to the PMF level.

The intakes of the pumps (el 640 ft-7 in) are located sufficiently below the low river water level (el 648 ft-7 in) to

provide the required pump submergence. One pump motor is

powered from one of the two emergency 4,160 V switchgear buses, a second pump motor is powered from the other bus, and the

third, which is not normally connected to either of the buses, can be manually connected to either. The three SWS pumps share the intake structure with the river

water and raw water pumps of Beaver Valley Power Station - Unit 1 (BVPS-1). Each SWS pump is located in a separate bay of

the intake structure. Seal water for cooling, lubricating, and sealing of the service water pumps can be provided by either the non-safety related

BVPS-1 filtered water system or by the discharge of the service water pumps via self-cleaning strainers located in the intake structure. BVPS-1 filtered water is normally isolated and service water pumps are cooled by the discharge of the service water pumps via self-cleaning strainers. The pumps discharge into two 30-inch headers which transport service water from the intake structure to the service water

valve pit. These headers are buried and separated. Each of these headers supplies a redundant valve pit section. Branches from the main headers supply water to the equipment

listed in Table 9.2-2 via buried supply lines. Portions of the headers and supply lines within the intake structure and buried

lines from the intake structure to the valve pit were installed during the BVPS-1 construction effort and under BVPS-1

procedures and specifications. Table 9.2-2 indicates what equipment is supplied during various modes of unit operation. Also, a single, 30-inch header from the SSWS (Section 9.2.1.2)

provides a backup source of water to either service water

header. During normal operation, the service water is discharged to:

1) the main circulating water lines downstream of the main condenser and travels from there to the cooling tower, and

2) the emergency outfall structure (EOS). The service water provides the necessary makeup for the main circulating system.

This makeup is required to compensate for drift and evaporation in the cooling tower and maintain circulating water concentration. Since the service water flow exceeds the makeup requirements, the excess is discharged into the blowdown line

downstream of the cooling tower basin.

BVPS-2 UFSAR Rev. 12 9.2-4 (Section 9.2.1.1.2) The SWS provides a continuous supply of cooling water to the following components during normal unit operation:

1. At least two primary CCW heat exchangers (Section 9.2.2). 2. At least one secondary CCW heat exchanger (Section 9.2.7).

3. At least two charging pump lube oil coolers (Section 9.3.4).

4. One control room air-conditioning refrigerant condenser (Section 9.4.1).

5. Two centrifugal water chiller condensers (Section 9.2.2.2).

6. One or two safeguards area air-conditioning units (Section 9.4.11).

7. Two sets of motor control center (MCC) cooling coils (Section 9.4.3).

During unit cooldown, the normal heat load on the primary CCW heat exchangers is not present as cooling of most of the components is not required. Primary CCW is then used to remove the cooldown heat loads, including the residual heat from the reactor through the use of the residual heat removal (RHR) heat

exchangers (Section 9.4.7). In the event of a design basis accident (DBA), initiating a containment isolation phase B (CIB) signal, the SWS is designed to supply sufficient cooling water to safely shutdown the unit, assuming any single active component failure coincident with a LOOP. As a minimum, cooling water would be supplied to the following components:

1. At least two recirculation spray coolers for cooling the water sprayed into the containment (Section

6.5.2). 2. At least one charging pump lube oil cooler (Section 9.3.4).

3. One control room air-conditioning refrigerant condenser or one control room air-conditioning unit (Section 9.4.1).

4. At least one emergency diesel generator cooling system heat exchanger (Section 9.5.5).

5. At least one set of MCC cooling coils (Section 9.4.3).

BVPS-2 UFSAR Rev. 17 9.2-5 6. At least one safeguards area air-conditioning unit (Section 9.4.11). On a CIB signal, motor operated valves (MOVs), located in the valve pit, divert flow from the primary CCW heat exchangers, secondary CCW heat exchangers, and chillers to the four recirculation spray coolers. Service water will continue to be supplied to the other safety-related equipment, listed previously. The motor operated inlet valves to the emergency diesel generator cooling system heat exchangers are opened on a safety injection signal, since the signal also starts the emergency diesel generators. The safety injection signal is initiated prior to a CIB signal.

On a LOOP, service water is supplied to emergency diesel generator cooling system heat exchangers through MOVs that open automatically when the diesel generators are started. The secondary CCW heat exchangers and the chillers are not required after a LOOP and will be automatically isolated, if necessary, on low pressure in both service water headers, to maintain the required flow to the other equipment.

The SWS is also designed to perform the following functions as required:

1. Provide an emergency source of makeup water to the fuel pool (Section 9.1.3).

2. Provide an emergency source of water to the steam generator auxiliary feed pumps (Section 10.4.9).

3. Provide fill water for the building service drains seal tank (Figure 9.4-1).

Each recirculation spray cooler has an MOV at both its inlet and outlet, so that it can be remotely isolated from the main header and the other recirculation spray coolers. The system is engineered and designed so that all components, pumps, and heat exchangers can be individually isolated, thus providing for continued operation during equipment repair and

maintenance.

BVPS-2 UFSAR Rev. 17 9.2-6 The SWS piping and components are Safety Class 3 and Seismic Category I from the intake structure to the service water valve pits. The redundant service water lines from the service water valve pit to the safety-related components are also Safety Class 3 and Seismic Category I, and tornado- and missile-protected. The supply lines to the chilled water unit condensers and secondary CCW heat exchangers are not seismically designed, with the exception of lines located within Seismic Category I structures. The majority of the normal flow from the primary CCW heat exchangers is discharged to the main circulating water system. This normal discharge path is not seismically designed. An auxiliary discharge path from the primary CCW heat exchangers is through two redundant Safety Class 3, 24-inch discharge lines to the two main 30-inch redundant discharge lines to the river via the EOS. The EOS is Seismic Category I and tornado- and missile-protected. A portion of the primary CCW heat exchanger discharge flow is normally directed through this auxiliary path.

Isolation between the Safety Class 3 and the nonsafety-related portions of the system is provided by double, motor operated isolation valves. These valves close on a containment isolation phase A (CIA) signal. In the event of a failure of the nonsafety-related portion of the system, one valve from each header will close on a system low pressure signal.

The operation of the various valves following a DBA or a LOOP is summarized in Table 9.2-3. Service water is supplied to the centrifugal water chiller condensers via two condenser water booster pumps (Section 9.2.2.2). These pumps, in conjunction with a temperature control valve, provide the capability to recirculate the cooling water to maintain a minimum temperature into the centrifugal

water chiller condensers. One header of the SWS can supply water to the suction of the steam generator auxiliary feed pumps (Section 10.4.7) and to the spent fuel pool (Section 9.1.3). This header can also be connected to the discharge of Beaver Valley Power Station - Unit

1 (BVPS-1) engine-driven fire pump (Section 9.5.1). In the long term, the locked closed valve separating the flow paths to the recirculation spray coolers can be opened to supply water to the

auxiliary feed pumps from the other header. An SWS backup, B Train, is provided to the containment

recirculation cooling coils (Section 9.2.2.2).

BVPS-2 UFSAR Rev. 13 9.2-6a Chemical protection for the materials of the SWS is provided in the following ways:

1. The Service Water System receives normal treatment to prevent marine growth and/or corrosion via a continuous dispersant/corrosion inhibitor feed.

2. The Emergency Diesel Generator heat exchangers are normally in standby and flowed monthly with treated Service Water during surveillance testing.

In addition to normal treatment, biodegradable chemicals can be added to the emergency diesel generator coolers for wet layup from a chemical addition tank (CAT) to prevent undue corrosion during long term shutdown.

BVPS-2 UFSAR Rev. 15 9.2-7 3. Additional injection points are provided for use in controlling corrosion macro invertebrate growth and to aid in the control of silt deposition in the SWS lines and components.

4. Water samples are taken periodically for chemical analyses to ensure that service water chemistry stays

within required specifications.

A high flow rate through the heat exchangers minimizes the possibility of pitting occurring in the stainless steel tubes due to deposition of silt.

The minimum flow requirements for the various components following a DBA, and for other modes of operation of the SWS, are given in Table 9.2-2. 9.2.1.1.3 Safety Evaluation

The safety-related portion of the SWS i s designated Safety Class 3, Seismic Category I, with pressure-retaining components

designed to ASME III, Class 3, requirements.

The SWS is designed to permit individual isolation of all pumps, heat exchangers, and piping for maintenance.

The minimum flow requirements for safe shutdown following a DBA are given in (Table 9.2-2). For this condition, the system performance is calculated on the basis of a technical specification low river level of el 654 ft and a maximum service water temperature of 89 F. The Service Water System bounding design criteria which has been determined for an extreme low river water level is:

1. A design basis accident occurs at Beaver Valley Power Station Unit No. 2 with the Ohio River at elevation of

654 ft mean sea level at the Intake Structure with an extremely low river water flow rate of 800 cfs.

2. A coincident shutdown of Beaver Valley Power Station Unit No. 1 from full power operation.

3. Ohio River water temperature of 89 F. 4. A single failure in either a) an onsite system or b) in an offsite manmade structure. The limiting design basis offsite single failure is the loss of one lock or tainter gate in the downstream New Cumberland Dam. This is a passive failure as defined in Section

3.1.1 which

culminates in an extreme low river water level of 648.6 ft mean sea level in a time frame as shown in Appendix 2.4B.

BVPS-2 UFSAR Rev. 15 9.2-7a The cooling requirements to satisfy the above scenario bounds the cooling requirements for the postulated scenario which involves the failure of one tainter gate in the downstream dam, a subsequent normal shutdown of both units prior to reaching

650 ft river level, and a single failure in an onsite system. A maximum solid blockage limit of 22 inches of silt has been established for each Intake Structure bay to ensure that sufficient ultimate heat sink cooling water remains available given the above design basis criteria for extreme low river

water level. Silt, in this application, is defined as any obstruction which completely blocks flow from the Ohio River to the pump suction in an Intake Structure bay. This silt limit

also requires that flow taken out of a single Intake Structure bay by station pumps be limited to a maximum of 7500 gpm whenever the Ohio River Water level is less than 650 ft mean sea

level to ensure sufficient water level remains in the bay for pump NPSH/submergence requirements. 7500 gpm is sufficient to meet Beaver Valley Power Station Unit No. 2 post-DBA cooling requirements in the long term. There is no limit for flow out of an Intake Structure bay with river water level greater than 650 ft mean sea level.

The SWS is designed with adequate redundancy throughout to meet the single failure criterion, either active or passive. During normal BVPS-2 operation, two pumps supply all service water required. Service water pump 2SWS*P21A is connected to emergency bus 2AE while pump 2SWS*P21B is connected to emergency

bus 2DF. Service water pump 2SWS*P21C may be operated from either emergency bus. To prevent a tie between these redundant emergency buses, a two key interlock is provided (Section 8.3.1). These pumps supply the safety-related portion of the system through two redundant trains. The nonsafety-related portion of the system is supplied by a single header, isolated from each of the Safety Class 3 trains by motor-operated isolation valves.

Only one of the three SWS pumps is needed to provide the cooling for the minimum number of components required for safe shutdown following a DBA. These components are listed in Table 9.2-2. Use of one pump is based on the required heat removal duty of the recirculation spray coolers following a DBA, as discussed in Chapter 6. Assuming a coincident LOOP, the required start-up

time for the SWS pumps is well within the sequential loading capability of the emergency diesel generators, as discussed in Chapter 8. In addition to the redundant SWS pumps, the SSWS is provided to meet an additional design basis event (Section 9.2.1.2).

BVPS-2 UFSAR Rev. 15 9.2-8 Failure of SWS piping is considered unlikely for the following reasons: 1. All safety-related SWS piping is tornado-protected either by being buried or by being located in Seismic

Category I buildings.

2. All safety-related SWS piping is designed to meet Safety Class 3 and Seismic Category I requirements and is protected from pipe break effects as described in Section 3.6.

All piping and equipment movements due to thermal or seismic effects have been analyzed for safety-related items in accordance with Section 3.9B.3. The piping and equipment is designed to ensure that no undue forces are exerted on piping or equipment nozzles.

Because the seismic movements of the intake structure and other buildings may differ from the seismic movements of the earth in which the pipe is buried, the most critical points are where the

pipes pass into the structures. If required, the pipes are provided with sleeves or enclosures which extend a short distance out from the structures. The enclosures decouple the pipe from the soil and permit the pipe to accommodate differential movements between the soil and the structures. Flexible joints are used within the enclosures, as necessary, to

limit piping stresses and to reduce the required length of the enclosure. The radial clearance between pipe and enclosure is ample to accommodate both settlement and seismic motion. Analysis of postulated cracks in piping systems is discussed in Section 3.6.

The SWS has been analyzed to verify that the system functions properly in the entire range of river water level from the technical specification low water level in the Ohio River (654 ft) to the PMF level (730 feet). All BVPS-2 equipment with a safety-related function has been located in structures of suitable design to prevent any flooding resulting from the PMF

level, including the SWS pumps located in the intake structure. Radiation monitors in the service water outlets from the recirculation spray coolers and the primary CCW heat exchangers detect leakage of radioactive material to the environment (Section 11.5). Both the shell and tube side of these heat exchangers can be manually isolated to stop leakage to the environment.

A failure modes and effects analysis (FMEA) to determine if the instrumentation and controls and electrical portions meet the single

BVPS-2 UFSAR Rev. 17 9.2-9 failure criterion, and to demonstrate and verify how the General Design Criteria and IEEE Standard 279-1971 requirements are satisfied, has been performed on the SWS system. The FMEA methodology is discussed in Section 7.3.2. The results of this analysis can be found in the separate FMEA document (Section 1.7). 9.2.1.1.4 Inspection and Testing Requirements The SWS will be tested in accordance with the ASME OM Code and inspected in accordance with ASME Section XI.

The major portion of the SWS is in continual use and requires no

periodic testing. The SWS sides of the recirculation spray coolers are tested on a

nominal 18 month frequency to verify an acceptable flow rate of service water through the coolers as specified in Table 9.2-2. The SWS (tube) sides of the recirculation spray coolers can be

flow tested in pairs. The output of one SWS pump can be diverted, by suitable valve operation, to the recirculation spray coolers through one of the 30-inch service water lines, the other line being used to supply the primary and secondary CCW heat exchangers. The emergency

diesel generators cooling system heat exchangers can also be flow tested by operation of the appropriate valves.

Preoperational tests are performed as described in Section 14.2.12. The equipment is accessible for inservice inspections.

The MOVs in the lines to and from the recirculation spray coolers are tested periodically to ensure satisfactory operation. They are normally set in the safe open position with

the header valves in the 24-inch service water lines closed. The recirculation spray cooler header valves are checked during

unit start-up and periodically to verify their proper position with the valves in the lines to the primary CCW heat exchangers.

In-service inspection will be done on the SWS pumps by measuring the specific pump operating parameters. These measurements will be compared to established reference values, as required by ASME

Section XI. The motors are equipped with a vibration monitoring cabinet and can be monitored or scanned continuously via the vibration monitoring system. The in-service inspection of the remainder of the system will be performed in accordance with ASME Section XI.

9.2.1.1.5 Instrumentation Requirements Control switches with indicating lights are provided in the main control room for the service water pumps. These pumps may be started manually or automatically from a safety injection signal or a diesel loading sequence signal. During normal operation, two pumps will supply all service water required for all unit operating conditions.

BVPS-2 UFSAR Rev. 0 9.2-10 The two modes of operation which are available, manual and automatic, may be initiated from either the control room or the emergency shutdown panel (ESP). A pushbutton is provided on the ESP which will transfer control to the ESP from the main control room. A manual reset at the relay is used to transfer control back to the main control room.

A control switch with indicating lights is provided on the alternate shutdown panel (ASP) for a service water pump. This pump is operated manually. A pushbutton on the ASP will transfer control from the ESP or from the main control room to the ASP. A manual reset at the relay will transfer control from the ASP back to the ESP or to the main control room.

Control switches with indicating lights are provided in the main control room for the service water pump discharge valves. These valves may be operated manually or automatically when their respective service water pump is running.

A control switch with indicating lights is provided on the ASP for a service water pump discharge valve. This valve is operated manually. A pushbutton is provided on the ASP which will transfer control from the main control room to the ASP. A manual reset at the relay will transfer control back to the main control room. Control switches with indicating lights are provided in the main control room for the secondary CCW heat exchangers service water isolation valves. These valves are operated manually. The valves may be closed manually, or automatically by a CIA signal or low header pressure in the system.

A selector switch with indicating lights is provided in the main control room for the containment air recirculation cooling coils

chilled water return valve. This valve is operated manually. Selector switches with indicating lights are provided locally for the SWS chemical addition pumps. These pumps are operated manually.

Control switches with indicating lights are provided in the main control room for the containment air recirculation cooler service water supply isolation valve and primary CCW heat exchanger service water inlet valves. These valves may be opened when a CIB signal is not present and may be closed manually or automatically by the CIB signal being present.

Control switches with indicating lights are provided in the main control room for the recirculation spray cooler service water

header valves. These valves may be opened manually or automatically when they receive a CIB signal and may be closed manually when the CIB signal is not present.

Control switches with indicating lights are provided in the main control room for the four diesel generator heat exchanger service

water BVPS-2 UFSAR Rev. 12 9.2-11 header valves. Two of these valves are operated automatically from an emergency diesel generator start signal or a safety injection signal. These valves may also be opened manually. The valves may be closed manually when there are no auto open

signals. The other two valves are operated only manually from the main control room.

A control switch with indicating lights is provided on the ASP for a diesel generator heat exchanger service water header valve. This valve is operated manually. A pushbutton is

provided on the ASP which will transfer control from the main control room to the ASP. A manual reset at the relay will transfer control from the ASP back to the main control room.

Control switches with indicating lights are provided for the air-conditioning condenser service water header valves at the MCC. An extra set of indicating lights is provided for these valves in the main control room. These header valves are normally locked in the open position at their respective MCCs

with power secured. Control switches are provided locally with local indicating lights for the seal water injection strainer backwash motors. These motors may be operated manually or automatically. While in the automatic mode, the motors receive a start signal from a

low seal water header pressure signal. These motors are started automatically by a safety injection signal.

Indicating lights are provided in the main control room for the service water to seal water header isolation valves. These valves operate automatically when their respective service water

pump is racked in on its bus. A clarified water pressure control valve to the seal water header is modulated to maintain clarified water pressure at set point. Control switches with indicating lights are provided in the main control room for the clarified water to seal water header isolation valves. These valves close automatically from a safety injection signal or a seal water header pressure low signal. BVPS-2 UFSAR Rev. 12 9.2-12 Control switches with indicating lights are provided on the building service control panel for the main control room refrigerant condenser recirculation pumps. These pumps may be started manually, or automatically when the service water temperature is low and the corresponding cooling unit is in operation. The pumps may be stopped manually, or automatically when the service water temperature is not low and the

corresponding cooling unit is in operation. The main control room cooling coil return temperature is controlled by throttling manual valves.

Ammeters are provided on the main board in the main control room, one each for the two service water pumps and two for the third pump.

Pressure indicators are provided in the main control room, one each for the two service water pump discharge headers.

Annunciation is provided in the main control room for service water pumps auto start/stop, control of service water pumps at the ESP, control at the ASP, and service water header pressure low. An alarm is also provided for SWS trouble, which consists of seal water header pressure low for each service water pump, seal water injection strainer differential pressure high for

each strainer, seal water injection strainer backwash motor auto start, and seal water injection strainer motor thermal overload for each strainer. These alarms are also monitored by the BVPS-

2 computer system. Annunciation is also provided in the main control room for chlorination system local panel trouble.

Computer inputs not associated with annunciation system are provided for SWS pumps start/stop, SWS valve pit area header A pressure, SWS valve pit area header B pressure, SWS pumps upper

bearing temperatures, and SWS pumps thrust bearing temperatures. 9.2.1.2 Standby Service Water System

In response to the new design basis event presented in U.S. Atomic Energy Commission (USAEC) Regulatory Staff Position 22 (BVPS-2 preliminary safety analysis report (PSAR), Q2.18, July 20, 1973), the SSWS conveys water from the alternate intake structure to provide heat sink requirements when the Seismic Category I intake structure is disabled by the postulated event (BVPS-2 PSAR, USAEC Question No. 2.18, Amendment 8, July 1973, Amendment 12, December 1973, and Amendment 13, February 1974). In accordance with Regulatory Guide 1.27, the SSWS is capable, as a minimum, of providing its design function during site-related historic events.

9.2.1.2.1 Design Bases

The SSWS is designed in accordance with the following criteria:

BVPS-2 UFSAR Rev. 11 9.2-12a 1. Historic earthquake - 0.03 g (surface motion).

2. Redundant pumps and motor-operated valves are provided to accommodate a single active failure.

3. Flood protected to el 705 feet (standard project flood).

4. Minimum site river level capability to el 654 feet.

5. No tornado protection.

6. Located to preclude damage from gasoline barge impact/explosion which may disable the Seismic Category I intake structure.

7. Regulatory Guide 1.27, as it relates to the redundant supplies of service water heat sink.

8. Capability is provided for onsite essential power for essential equipment.

9. A DBA is not considered coincident with requirements for the SSWS.

10. Electrical and control requirements to meet IEEE Standards 279-1971 and 308-1974 for essential

equipment.

11. Piping and valves meet Power Piping Code ANSI B31.1.0 and pumps are designed to applicable ANSI and Hydraulic Institute Standards.

The SSWS is designed to accommodate unit shutdown from 100-percent reactor power and subsequent cooldown of the reactor

coolant system (RCS) to less than 200F (cold shutdown requirements), after the postulated loss of the Seismic Category

I intake structure. The SSWS is designed to duplicate the cooldown cooling capacity of the SWS specified in Section 9.2.1.1.

BVPS-2 UFSAR Rev. 12 9.2-13 9.2.1.2.2 System Description The SSWS consists of two 100-percent capacity pumps discharging to a 30-inch line and connected to the redundant 30-inch Seismic

Category I service water supply lines via MOVs located in the Seismic Category I valve pit. From the point of connection to the service water lines, the cooling water flows to the systems

and equipment described in Section 9.2.1.1. The two 100-percent capacity pumps and two MOVs are provided to accommodate the single active failure criterion requirement for the system. The check valves in the Seismic Category I service water lines, located in the valve pit, will isolate the SSWS

from the disabled intake structure during the design basis event. This feature maintains the integrity of the SWS to continue unit shutdown cooling water requirements when supplied from the SSWS. The SSWS pumps share the auxiliary intake structure with the

auxiliary river water pumps of BVPS-1, but are located in a separate bay.

The SSWS is capable of operating during LOOP from redundant emergency 4,160 V switchgear buses.

Seal water for the SSWS pumps is normally provided from the discharge of the SSWS pumps via self-cleaning and Y-type strainers located in the auxiliary intake structure. These

self-cleaning strainers also provide a backup supply of seal water to BVPS-1 auxiliary river water pumps and supply wash water to both BVPS-1 and BVPS-2 traveling water screens. An automatic backup supply of seal water is provided from the discharge of the SSWS pumps via a Y-type strainer.

The SSWS pumps are provided with an automatic start capability. Although this feature is not required for the design basis event, it is provided to prevent inadvertent plant trip on loss of a running service water pump. Given a low pressure signal in either SWS header, provided there is no loss of power signal present, its associated SSWS pump will be activated and the MOV connecting the SSWS to the affected SWS header will open. The SSWS pumps can also be manually started on the emergency buses after a loss of power signal if the diesel loading sequence is completed and the associated SWS pump on the bus is not running. The postulated barge impact explosion design basis event would result in an immediate loss of pressure and flow to both redundant service water supply lines, which would result in auto start of both SSWS pumps and opening of both header MOVs. If an automatic start did not occur, the SSWS pumps can be manually

started. BVPS-2 UFSAR Rev. 19 9.2-14 9.2.1.2.3 Safety Evaluation The postulated gasoline barge impact with the intake structure and coincident explosion disabling the SWS is a low probability

event and is outside those typically postulated by the NRC for reactor sites. Nonetheless, the SSWS provides defense in depth

in assuring shutdown cooling capability. The requirement to operate the SSWS is not coincident with a postulated Design Basis Accident, but is coincident with the postulated gasoline

barge impact event. The SSWS is a non-safety system provided with redundant pumps and valves to accommodate a single active

failure. The SSWS is designed to provide cooling water to shut down the unit from 100-percent power and to subsequently cool down the

RCS to less than 200 F for as long as necessary after the postulated loss of the Category I intake structure due to the specified design basis event. A DBA is not considered

coincident with requirements for the SSWS. Redundancy of the SSWS pump and MOVs permit acceptance of a single active failure without impairing designed cooling water requirements. Furthermore, low pressure alarms and pressure

indicators in the service water lines at the primary CCW heat exchanger, as well as pump motor current (amperes), and the primary plant cooling system temperatures provide the operator

with information to evaluate the performance of the SSWS and the SWS. The SSWS pumps are also capable of operation during LOOP, as power requirements can be provided from the redundant essential buses when the SWS pumps are unavailable. The

Licensing Requirements Manual establishes the functionality requirements for the SSWS. 9.2.1.2.4 Inspection and Testing Requirements The SSWS from the alternate intake structure to the connection to the SWS in the valve pit will be tested periodically during

unit operation, shutdown, or refueling periods. During normal unit operation, cooling water is supplied to the valve pit by two SWS pumps via two 30-inch service water supply headers from the intake structure. The SSWS can be tested by operating each SSWS pump through a recirculating line provided in the alternate intake structure. Also, the SSWS may be tested by supplying the SWS with one SSWS pump in place of an SWS pump.

The performance of the SSWS can be evaluated by monitoring SSWS and SWS header pressure, SSWS pump motor current (amperes), and

temperatures of systems cooled by the SWS. The system is hydrostatically tested prior to acceptance and all active components are accessible for periodic visual inspection during unit operation. Preoperational tests are performed as

described in Section 14.2.12. 9.2.1.2.5 Instrumentation Requirements Control switches with indicating lights are provided for the SSWS pumps on the main control board. The SSWS will be put into

operation automatically upon a loss of pressure in the SWS valve

pit area header provided there is no loss of power. BVPS-2 UFSAR Rev. 11 9.2-14a Seal water injection valves are provided with indicating lights on the main control board. These valves are interlocked with the SSWS pumps. When their respective pump starts, the valve will open and when the pump stops, the valve will close.

Control switches with indicating lights are provided for the SSWS pump discharge valves in the main control room. These

valves are interlocked with their respective SSWS pump. Selector switches with indicating lights are provided locally for the wash water booster pump. An extra set of indicating lights are provided on the main control board for the pump. This pump is interlocked with the SSWS pumps high discharge

pressure to start on this signal. BVPS-2 UFSAR Rev. 12 9.2-15 Selector switches with indicating lights are provided locally for the traveling water screen. An extra set of indicating lights are provided on the main control board for the water screen. This water screen is interlocked with the wash water

booster pump running. Selector switches with indicating lights are provided locally for the self-cleaning strainer. This strainer is interlocked with the SSWS pumps high discharge pressure to start on this signal. Ammeters are provided on the main control board in the main control room for each of the SSWS pumps. A pressure indicator is provided on the main control board in the main control room for discharge pressure of the SSWS pumps. Annunciation is provided in the main control room for any standby service water pump auto start/stop and alternate intake structure local panel trouble. These are also monitored by the BVPS-2 computer system. Annunciation is provided locally for the standby service water pumps bearing temperature high. These annunciators are monitored by the BVPS-2 computer system. Annunciation is also provided locally for the SSWS pumps seal water pressure low, SSWS pumps discharge header pressure low, SSWS self-cleaning strainer differential pressure high, and SSWS alternate intake structure temperature high/low. These annunciators, however, are not monitored by the BVPS-2 computer system.

9.2.2 Cooling

Systems for Reactor Auxiliaries The cooling systems for the reactor auxiliaries consist of the

primary CCW system (Section 9.2.2.1), the chilled water system (Section 9.2.2.2), and the neutron shield tank cooling water system (Section 9.2.2.3). These systems are used individually

and in combination with each other to provide cooling water for heat removal from various reactor plant components.

9.2.2.1 Primary Component Cooling Water System The primary CCW system provides an intermediate cooling loop for removing heat from reactor plant auxiliary systems and transferring it to the SWS (Section 9.2.1). The primary CCW system is shown on Figure 9.2-10. Table 9.2-4 lists the required flows for the various equipment cooled by this system. Table 9.2-5 lists subsystem component design data.

BVPS-2 UFSAR Rev. 0 9.2-16 9.2.2.1.1 Design Bases The primary CCW system is designed in accordance with the following criteria:

1. General Design Criterion 2, as it relates to structures housing the system and the system itself

being capable of withstanding the effects of natural phenomena, such as earthquakes, tornadoes, hurricanes, and floods.

2. General Design Criterion 4, as it relates to structures housing the piping and the piping itself being capable of withstanding the effects of or being protected against externally and internally-generated missiles, pipe whip, and jet impingement forces

associated with pipe breaks.

3. General Design Criterion 5, as it relates to shared systems and components important to safety being capable of performing required safety functions.

4. General Design Criterion 44, to assure:

a. The capability to transfer heat loads from safety-related structures, systems, and components to a heat sink under both normal operating and accident conditions, b. Component redundancy so that the system can operate assuming a single active component failure coincident with the LOOP, and

c. The capability to isolate components, systems, or piping so that system safety function will not be compromised.

d. The cooling water supply to the reactor coolant pump (RCP) seals meets the recommendations of

NUREG-0737, Item II.K.3.25 (USNRC 1980).

5. General Design Criterion 45, as it relates to design provisions made to permit inservice inspection of

safety-related components and equipment.

6. General Design Criterion 46, as it relates to design provisions made to permit operational functional testing of safety-related systems and components to ensure: a. Structural integrity and system leak tightness, BVPS-2 UFSAR Rev. 2 9.2-17 b. Operability and adequate performance of active system components, and

c. Capability of the integrated system to perform required functions during normal, shutdown, and accident situations.

7. Regulatory Guide 1.26, as it relates to the quality group classification of systems and components.

8. Regulatory Guide 1.29, as it relates to the seismic design classification of system components.

9. Regulatory Guide 1.46, as it relates to pipe whip inside the containment.

10. Branch Technical Position ASB 3-1, as it relates to breaks in high and moderate energy piping systems

outside containment.

11. The system shall supply sufficient cooling water at 106 F maximum during normal operations and at 120 F maximum during initial shutdown and initial accident conditions using service water as the cooling medium.

12. The flow paths can be physically separated and isolated from each other by operator action following a passive failure.

13. The portions of the svstem required for cold shutdown or to provide cooling for spent fuel are designated

Safety Class 3. 9.2.2.1.2 System Description

The primary CCW system consists of a Safety Class 3 portion which supplies cooling water to Safety Class 3 components, and a non-nuclear safety (NNS) class portion which supplies cooling

water to NNS class components. The NNS class portion is isolated automatically on a containment isolation Phase A (CIA) signal or low surge tank level.

The CCW pumps, heat exchangers, and surge tanks are located in the auxiliary building. Components cooled by the system are located in the containment, fuel building, auxiliary building, waste handling building, and main steam valve area (Table 9.2-4). The primary CCW heat exchangers, pumps, and component cooling surge tanks are Seismic Category I. The pump motors and electrical equipment are environmentally qualified for normal, abnormal, and accident operation as described in Section 3.11.

The valves and BVPS-2 UFSAR Rev. 12 9.2-18 interconnecting piping between the previously mentioned components are Seismic Category I. The RHR heat exchangers, RHR pump seal coolers, fuel pool heat exchangers, the valves and interconnecting piping between the aforementioned components are

Seismic Category I. The component cooling piping connecting these components with the CCW pumps and heat exchangers is Seismic Category I.

The largest primary CCW heat load occurs during Beaver Valley Power Station Unit 2 (BVPS-2) cooldown when the RHR system (Section 5.4.7) is initially placed in operation. The three CCW

heat exchangers and three CCW pumps must be in operation to achieve the minimum cooldown time. A slower but acceptable cooldown rate can be maintained with a minimum of one CCW heat exchanger and one CCW pump. The cooldown rate is discussed in

Section 5.4.7. During normal operation, two primary CCW pumps and two primary CCW water heat exchangers can transfer the design heat loads from all components served, simultaneously with the service water temperature at its maximum. During most operating

conditions, only one pump will be required. Each cooling water outlet line from a component contains a valve for controlling flow. The valve is either a manually-operated valve of the globe, butterfly, or ball type, or an automatic type that is positioned by pressure or temperature control signals originating in the cooled systems. Plate type restrictive orifices in the supply or discharge piping of some of the equipment also act to control the flow to the component.

A chemical addition tank is connected to the discharge piping of the CCW pumps. To add chemicals to the system, the tank is isolated, drained down, and filled with the necessary chemicals. The isolation valves are then opened, and the discharge pressure of the pump will force water into the tank and inject the

mixture into the system at the pump suctions via the surge tank.

Sampling is performed at the sampling station in the auxiliary

building. Several local sample points are also provided. 9.2.2.1.3 Safety Evaluation

The primary CCW system is not required in the short term to mitigate the consequences of accidents (Chapter 15). The effects of a loss of cooling water on fuel pool cooling are discussed in Section 9.1.3. The CCW must be supplied to the RHR heat exchangers in the long term to bring BVPS-2 to a cold

shutdown condition.

BVPS-2 UFSAR Rev. 12 9.2-18a During normal operation, cross-ties between redundant flow paths are open. Valves are provided to allow isolation of redundant flow paths and the NNS class portions of the system, if required, ensuring that at least one primary CCW pump and heat

exchanger can supply cooling to one RHR heat exchanger in the long term.

Low flow, low pressure, high temperature, or high radioactivity level alarms alert the operator to malfunctions. If the malfunction causing low flow, low pressure, or high temperature is not corrected, components and systems served by the primary CCW system may be inadequately cooled. The affected components and systems can be protected either automatically or through

operator action (Section 9.2.2.1.5). One of three 100-percent capacity pumps supplies the system with sufficient cooling water during normal BVPS-2 operation. The CCW pump 2CCP*P21A is connected to emergency bus 2AE while pump 2CCP*P21B is connected to emergency bus 2DF. Pump 2CCP*P21C may be operated from either emergency bus. To prevent a tie between these redundant emergency buses, a two-key interlock is provided (Section 8.3.1). Redundancy in the system ensures performance of

the cooling function in the event of a single failure.

BVPS-2 UFSAR Rev. 12 9.2-19 For normal plant operation, the primary CCW water system can maintain the CCW supply temperature below 106F when the service water temperature is less than 89 F. During plant cooldown operation, due to the initially high reactor coolant system temperature and the sensible and decay heat load imposed by the reactor coolant system via the RHR heat exchangers, the component cooling temperature is permitted to rise to 120 degrees F. This maximum temperature is controlled by regulating the reactor coolant flow through the RHR heat exchangers during the early stages of cooldown. As the cooldown progresses, the reactor coolant temperature drops, the sensible and decay heat loads decrease, and the component cooling temperature returns to normal levels. The principal method of leak detection for loss of water from the primary CCW system is by the records of addition of water to the system to maintain the water level in the surge tanks. Temperature, level, and flow indicators in the main control room may be used to detect leakage at certain system points. Elsewhere, leaks can be located by manual inspection or by isolation.

Welded construction is used extensively throughout the system to minimize the possibility of leakage from pipes, valves, and

fittings. In the unlikely event of a header rupture, the cooling capacity of the system may be lost until the break can be isolated and the levels in the surge tanks are restored. The operator will be alerted to a major loss of CCW by annunciation in the main control room on low surge tank level. Following a loss of water, at least one flow path can be returned to service to supply cooling water to the RHR system within 36 hours.

In the event of a loss of CCW to the RCPs, indication will be provided in the main control room from flow transmitters on the

outlet of each CCW line from the pumps. Low flow to the upper bearing coolers, lower bearing coolers, or the stator air coolers will actuate a common trouble alarm in the main control room. The operators can initiate manual protection of BVPS-2 within 10 minutes to prevent damage to the RCPs if the CCW flow is not restored to the bearing oil coolers within this time.

Inleakage to the system can be detected from records of the discharge of water to maintain the level in the surge tanks.

A radiation monitor (Section 11.5) is provided at the inlet to the primary CCW heat exchangers. The primary CCW system is not

normally expected to contain radioactive water. Small amounts of leakage resulting in contamination could result from the leakage in a heat exchanger in the CVCS, RHR system, or sampling system, or from a leak in the thermal barrier of a RCP. Provisions are made, however, to preclude the possible spread of radioactive contamination in the event that a primary CCW leak

should occur. These precautions BVPS-2 UFSAR Rev. 0 9.2-20 include isolation of each heat exchanger by manual shutoff of the inlet and outlet CCW valves. Air-operated trip valves are installed in the outlet cooling water lines from the RCPs' thermal barriers. A check valve is installed in each inlet cooling water line to the thermal barriers. In the event that a leak occurs in the thermal barrier cooling coil, a high pressure or flow alarm annunciates in the main control room, and the high pressure reactor coolant is safely contained by automatic closure of the isolation valve. Any leakage and water samples from these heat exchangers is treated as radioactive and returned to the liquid waste disposal system (Section 11.2.4) via the auxiliary building sump pumps.

A failure modes and effects analysis (FMEA) to determine if the instrumentation and controls (I&C) and electrical portions meet the single failure criterion, and to demonstrate and verify how the General Design Criteria and IEEE Standard 279-1971 requirements are satisfied, has been performed on the primary CCW system. The FMEA methodology is discussed in Section 7.3.2. The results of this analysis can be found in the separate FMEA document (Section 1.7).

The containment isolation valve arrangement and signals which cause valve closure for the primary CCW system are described in

Section 6.2.4, and are tested as described in Section 6.2.6. 9.2.2.1.4 Inspection and Testing Requirements

The primary CCW system is inspected in accordance with applicable ASME III requirements during construction to ensure proper installation. All components are inspected prior to installation to ensure that they comply with their ASME design specification. All safety class pumps and valves undergo inservice testing, as specified in Section 3.9.6. Preoperational tests are performed as described in Section 14.2.12. 9.2.2.1.5 Instrumentation Requirements

Control switches with indicating lights are provided in the main control room and at the ESP for the primary CCW pumps. Transfer from the main board to the ESP is effected by means of a pushbutton at the ESP. Transfer back to the main board is effected by means of a local manual reset at relay. Normal operation consists of one pump operating, with the second pump

available for an automatic backup. The third pump during normal operation is arranged for manual standby. During periods of normal operation which require two operating pumps, the third pump is available for automatic backup. These pumps are automatically stopped on a containment isolation phase B (CIB) signal. One primary CCW pump is provided with a control switch with indicating lights on the alternate shutdown panel (ASP) for

manual BVPS-2 UFSAR Rev. 0 9.2-20a control. Transfer from the main board or the ESP to the ASP is effected by means of a pushbutton at the ASP. Transfer back to the main board or the ESP from the ASP is effected by means of a local manual reset at relay.

Control switches with indicating lights are provided in the main control room for the primary CCW header isolation valves. These

valves close automatically on a CIB signal.

BVPS-2 UFSAR Rev. 13 9.2-21 The primary CCW pumps have their discharge pressure indicated in the main control room. Each pump differential pressure control valve is operated automatically or manually to maintain minimum flow requirements. The primary CCW heat exchanger outlet temperature is maintained by independent heat exchanger bypass temperature control valves. These temperature control valves permit primary CCW to bypass the heat exchangers. A differential pressure control valve in series with each heat exchanger can be operated manually or automatically to maintain a constant pressure drop across the temperature control valves.

Hand/automatic control stations are provided in the main control room for the operation of the differential pressure control valves and the temperature control valves.

Hand/automatic control stations are also provided in the main control room for the primary CCW system surge tank level control valves. These valves modulate to admit water to their respective surge tanks.

The levels of the CCW surge tanks are controlled at their centerlines. Each is sufficient to accommodate minor system surges and thermal swell. Makeup from the demineralized water

system or primary grade water system is admitted to each tank through individual air-operated valves controlled automatically or by the control room operator. A local station is provided for the manual operation of the letdown of the levels in the surge tanks.

Ammeters are provided in the main control room for each of the CCW pumps.

Main control room indication is provided for CCW heat exchangers discharge temperatures, CCW pumps differential pressures, and CCW supply header flow. The CCW surge tanks also have level

indication in the main control room. Annunciation is provided in the main control room for primary CCW pump auto-start/auto-stop; primary CCW system trouble, which consists of CCW header pressure low, CCW surge tank level high or low, and CCW heat exchanger discharge temperature high;

radiation level high; control at ESP alarm for the cooling water pumps; and control at ASP for the cooling water pump. These are also monitored by the BVPS-2 computer system. The CCW pumps'

discharge pressure is monitored by the BVPS-2 computer. 9.2.2.2 Chilled Water System

The chilled water system is nonsafety-related and is designated as non-nuclear safety (NNS) class. This system provides chilled water to the following cooling coils and equipment:

1. Refueling water storage tank (RWST) coolers.

BVPS-2 UFSAR Rev. 12 9.2-22 2. Cooling coils of the reactor containment air recirculation unit.

3. Containment test skid air compressor after coolers and water jackets.

4. Gaseous waste system coolers, waste gas system air ejector vent cooler, and sweep gas chiller.

5. Turbine plant sampling system.

6. Air conditioning units of the following areas:

a. Auxiliary building, b. Pipe tunnel, c. Fuel building,

d. Control building, e. Cable vault and rod control areas,

f. Condensate polishing building,

g. Waste handling building,

h. Charcoal delay bed cubicles, and

i. Main steam valve house cooling coils

7. Post-accident sampling system.

8. Hot water heating system pumps.

9.2.2.2.1 Design Bases

The design bases for the chilled water system are as follows:

1. General Design Criterion 2, as it relates to the system being capable of withstanding the effects of

natural phenomena, as established in Chapters 2 and 3.

2. General Design Criterion 5, as it relates to shared systems. No portion of the chilled water system is

shared. 3. Regulatory Guide 1.26, as it relates to the quality group classification of system components.

4. Regulatory Guide 1.29, as it relates to the seismic design classification of systems and components.

BVPS-2 UFSAR Rev. 14 9.2-23 5. The chilled water system is designed for the full cooling capacity requirement of the previously listed building areas and components during normal plant operation. It is based on an outside design air

temperature of 90F and chilled water being supplied to all cooling coils and equipment at a temperature of

45 F. 6. That service water at a maximum temperature of 89°F is used as a heat sink.

7. The chilled water system piping is designed to meet the requirements of ANSI B31.1.

9.2.2.2.2 System Description

The chilled water system is shown on Figure 9.2-1 and the principal components and design parameters are given in Table 9.2-6. The system consists of three 50-percent capacity centrifuga l chiller units and circulating pumps, two expansion tanks, an air separator, and related distribution chilled water piping. Condenser cooling water is provided from the SWS as described in Section 9.2.1. The chilled water system is a recirculated

closed loop system where any variation in water volume, due to temperature changes and component cycling effect, is accommodated by expansion tanks. The expansion tanks are

connected to the suction side of the pumps.

System makeup is provided from the demineralized water system (Section 9.2.3). The three chilled water pumps discharge to a common discharge header and take suction from a common return header. A chiller unit cannot be started unless there is water flow in the system. Chilled water flows from the chiller units to a common header which supplies chilled water at 45°F to system components and approximately 40°F, if required, at the

end of refueling during the RWST cooldown. 9.2.2.2.3 Safety Evaluation

The chilled water system is nonsafety-related. Failure of this system will not affect the safe shutdown of the plant.

Safety-related service water or the supplementary leak collection and release system provide cooling for the safety-related areas requiring space cooling after a CIB signal, as described in Sections 9.4.1.1 and 9.4.12.2.

BVPS-2 UFSAR Rev. 0 9.2-24 9.2.2.2.4 Inspection and Testing Requirements The chilled water system piping and equipment is inspected and operated following initial installation to ensure the components are installed properly. Specific tests of the system following initial operation checkout are described in Section 14.2.12.

The chilled water system is in continuous operation, thus periodic testing is not required. Chillers and pumps are alternated in service periodically. Components are accessible

for routine visual observation during normal operation. Preliminary tests are performed as described in Section 14.2.12.

9.2.2.2.5 Instrumentation Requirements

Control switches with indicating lights are provided for the chilled water pumps and condenser water booster pumps at the local water chiller control panel.

Selector switches with indicating lights are provided for the water chillers at the local water chiller control panel.

Indicating lights are also provided at this panel for the chilled water pump discharge valves. The valves will open when the chilled water pumps start and close when the chilled water

pumps stop. A chilled water system pressure differential valve is provided

and will be modulated by chilled water supply and return header pressure.

A condenser water temperature control valve is provided and will be modulated by booster pump discharge header temperature to return the chiller condenser discharge to the booster pump

suction. A condenser water pressure control valve is provided and will be

modulated by the booster pump suction/discharge header differential pressure. This allows the chiller condenser discharge to circulate the water discharge line to maintain a

constant pressure differential across the condenser water booster pumps.

Chiller lube oil pumps are provided and will start when the water chiller is running and stop when the water chiller is stopped. A lube oil sump heater is provided and will be energized on a low lube oil temperature and will be de-energized on a normal

lube oil temperature. A cooling water inlet valve to the lube oil cooler is provided and will open when the water chiller is running and will close when the water chiller is stopped.

BVPS-2 UFSAR Rev. 12 9.2-25 Compressor inlet guide vanes are provided and will be modulated by chilled water temperature and by the chiller motor current. The vanes will be opened when the water chiller is running and will close when the water chiller is

stopped. A hot gas bypass valve is provided and will be opened when the chilled water return temperature is low and will close when the chilled water return temperature is normal.

The chilled water pumps, condenser water booster pumps, and the water chillers are manually started. The water chillers start when there is sufficient chilled water flow and

condenser cooling water flow in the system. Temperature indication is provided in the main control room

for chilled water return header temperature. Annunciation is provided in the main control room for water chiller circulating/booster pump auto trip and water chiller control panel trouble, which has the following inputs: expansion tank level high, expansion tank level low. Local panel status lights are provided with the following inputs to the water chiller control panel trouble annunciator: chilled water outlet temperature low, lube oil pressure low, chilled water flow low, condenser water flow low, chiller motor electrical protection trip, condenser pressure high, refrigerant temperature low, bearing temperature high, impeller displacement excessive, and compressor discharge gas temperature high. The annunciators are also monitored by the BVPS-2 computer system.

A local control panel is also provided for the water chillers. Pushbuttons, switches, thermostats, and status

lights are provided for chiller operation. 9.2.2.3 Neutron Shield Tank Cooling Water System

The neutron shield tank cooling water system is a closed loop system consisting of a natural convection cooler and associated piping connecting the neutron shield tank (Section 5.4.14). The neutron shield tank cooling water system is safety-related and Seismic Category I.

9.2.2.3.1 Design Basis

The neutron shield tank cooling water system is designed to circulate and cool the water in the neutron shield tank, which is heated by neutron, gamma, and thermal radiation. When filled, the neutron shield tank provides additional neutron absorption and a thermal barrier for protection of the

surrounding concrete.

BVPS-2 UFSAR Rev. 12 9.2-26 The neutron shield tank cooling water system is designed in accordance with the following criteria:

1. Regulatory Guide 1.26, as it relates to the quality group classification of systems and components.

2. General Design Criterion 2 and Regulatory Guide 1.29, as they relate to the seismic design and seismic

classification of system components.

3. General Design Criteria 45 and 46, as they relate to the testing and inspection of this system.

4. The piping of the system, except as noted in Item 6 as follows, is designed to ASME III standards. The design data of the major components of the neutron shield tank cooling water system are given in Table 9.2-7. 5. The corrosion control tank and associated piping are Quality Assurance Category II, ASME VIII, 197 1 Edition, including all addenda to Winter, 1972, and ANSI B31.1, 1967 Edition, including all addenda through June 30, 1972, respectively.

9.2.2.3.2 System Description

The system is comprised of a neutron shield tank cooler, a neutron shield surge tank, a corrosion control tank, and the necessary piping and valves. The entire system is housed in the

containment building. The neutron shield tank cooling water system is designed as a thermo-siphon system. The heated water in the neutron shield tank rises due to natural circulation to the top of the tank and flows via interconnecting piping to the neutron shield tank cooler. The heated neutron shield tank water is cooled as it circulates down through the neutron shield tank cooler by primary CCW passing in counterflow through the shell side of the

cooler. One full-duty neutron shield tank cooler is provided to perform the required cooling. A surge tank accommodates thermal expansion in the neutron shield system and a corrosion control

tank is used for the addition of corrosion inhibitors by manual operation.

BVPS-2 UFSAR Rev. 12 9.2-26a 9.2.2.3.3 Safety Evaluation Operation of the neutron shield tank water cooling system is not required for unit cooldown or for safe shutdown of BVPS-2. A malfunction of the neutron shield tank cooling water system is

improbable. The neutron shield tank cooling water system has no moving parts, so that a malfunction can occur only by loss of water due to leakage, loss of natural convection circulation, or low heat

BVPS-2 UFSAR Rev. 0 9.2-27 transfer caused by fouling. Clogging of the system is unlikely due to the cleanliness level of the supply water from the primary CCW system. Since the neutron shield tank cooling system operates at a low system pressure, a pipe break is also

unlikely. Should a pipe break occur, makeup water would be supplied to the system following a low water level indication from the surge tank water level transducer.

As a result of a loss of water from the neutron shield tank, neutron shielding would be decreased if water was not made up. This would be indicated by a low expansion tank level alarm or shield water temperature indication; however, no hazardous conditions would result. Operation of the neutron shield tank

water cooling system is not required for unit cooldown or for safe shutdown of BVPS-2.

Although the neutron shield tank cooling water system is a safety-related system, it contains no electrically controlled components whose failure would affect the safety of BVPS-2. For that reason, no failure modes and effects analysis was performed on the instrumentation and controls and electrical portions of this system.

9.2.2.3.4 Inspection and Testing Requirements

The neutron shield tank cooling water system is inspected in accordance with the applicable code requirements during construction. Inservice inspection of the system is inappropriate because the system contains no moving parts, has adequate instrumentation to remotely verify correct operation, and is inaccessible during unit operation. Preoperational tests

are performed as described in Section 14.2.12. 9.2.2.3.5 Instrumentation Requirements

A selector switch with indicating lights is provided in the main control room for the neutron shield tank cooling water makeup valve. This valve is operated manually. The primary CCW system provides water to the neutron shield tank cooling water system for filling and makeup.

A control switch with indicating lights is provided in the main control room for the neutron shield tank cooler cooling water

supply valve. This valve is operated manually. A temperature indicator is provided in the main control room for

the neutron shield tank outlet temperature. A level indicator is provided in the main control room for the

neutron shield expansion tank level. Annunciation is provided in the main control room for neutron shield expansion tank level low and temperature high. Each condition is monitored by the BVPS-2 computer system.

BVPS-2 UFSAR Rev. 12 9.2-28 The BVPS-2 computer monitors the neutron shield tank outlet temperature, neutron shield tank cooler outlet temperature, and neutron shield tank cooler cooling water outlet temperature.

9.2.3 Demineralized

Water Makeup System The demineralized water makeup system is a nonsafety-related system that supplies water to the reactor plant and turbine plant systems listed below for makeup to tanks, sample sink flushing, and other miscellaneous requirements during all modes of operation. Demineralized water for the BVPS-2 makeup system is supplied from the BVPS-1 water treatment system. All water treatment is performed by the BVPS-1 water supply and treatment

system described in the BVPS-1 FSAR, Section 9.11. 9.2.3.1 Design Bases

The demineralized makeup water system is designed in accordance with the following criteria:

1. The BVPS-2 shares the BVPS-1 demineralized water treatment system.

2. Each plant unit has a demineralized water storage tank with a nominal volume of 600,000 gallons, for a total shared capacity of 1.2 million gallons. Of the 600,000 gallons per tank, approximately 584,000 gallons is available with the tank full.

3. The BVPS-2 storage tank and distribution pumps are cross-tied with the BVPS-1 storage tank so that water can be transferred between units as necessary.

4. The system supplies demineralized water for makeup as delineated in Section 9.2.3.2.

5. The entire system is constructed of stainless steel and cleaned to Level B, in accordance with ANSI-N45.2.1, 1973 Edition.

6. The system is not safety-related and is designated non-nuclear safety.

7. The system is capable of functioning effectively with a single distribution pump operating.

8. Beaver Valley Power Station - Unit 1 has the capability to effectively store, handle, and dispense all chemicals used in the demineralizing and

regeneration process associated with the water treatment system for BVPS-1 and BVPS-2.

BVPS-2 UFSAR Rev. 12 9.2-29 9.2.3.2 System Description The demineralized water makeup system principal component design and performance characteristics are listed in Table 9.2-8. The

system consists of a 600,000 gallon storage tank and two 100 percent distribution pumps.

The 600,000-gallon demineralized water storage tank (DWST) receives water from the BVPS-1 water treatment system and stores it prior to distribution. The BVPS-1 demineralized water system, along with the BVPS-2 DWST and demineralized water storage pumps, is sufficient to supply makeup water to both units at all times, including periods of water treatment demineralizer regeneration and routine maintenance. A 6-inch line provides makeup water from the BVPS-1 system to the BVPS-2 storage tank. A return, utilizing the same 6-inch line, connects the BVPS-1 600,000 gallon tank and the BVPS-2 600,000 gallon DWST, via the BVPS-2 pumps' discharges so that water can be transferred between BVPS-1 and BVPS-2, as required. The BVPS-2 demineralized water is supplied to the following components and systems:

1. Cask washdown hose connections (Section 9.2.3).

2. Cask washdown spray ring (Section 9.1).

3. Primary component cooling water makeup (Section 9.2.2.1).

4. Leak collection filter seal tank (Section 9.4.16).

5. Primary sample sink washdown (Section 9.3.2).

6. Primary grade water system backup (Section 9.2.8).

7. Auxiliary feedwater system makeup (Section 10.4.9).

8. Jacket water expansion tank (Section 9.5.5).

9. Recirculation spray cooler tube flushing (Section 9.2.1.1).

10. Recirculation pump test loop (Section 6.2.2).

11. Hot water heating system makeup.

12. Turbine plant component cooling water makeup (Section 9.2.7).

13. Secondary demineralized water tank makeup (Section 9.2.6).

14. Backwash hold tank (Section 10.4.6).

15. Dewatering system flush (Section 10.4.6).

BVPS-2 UFSAR Rev. 13 9.2-30 16. Condensate polishing precoating system (Section 10.4.6). 17. Containment vacuum and leakage monitor system (Section 9.5.10).

18. Containment instrument air compressors (Section 9.3.1.3).

19. Gaseous nitrogen system (Section 9.5.9).

20. Auxiliary steam activity monitor (Section 10.4.10).

21. Drum inspection and labeling station (Section 11.4).

22. Condensate demineralizer backwash feed tank (Section 10.4.6).

23. Supplement leak collection and release system (Section 6.5.3.2).

24. Condensate demineralizer sludge tank (Section 10.4.6).

25. Service water radiation monitor flush (Section 9.2.1).

26. Radioactive liquid discharge radiation monitor flush (Section 11.2).

27. Secondary chemical feed mixing tanks.

28. Turbine lube oil purifier (Section 10.2.2).

29. Primary component cooling water activity monitor (Section 9.2.2.1).

30. Primary chemical lab supply (Section 9.3.2.1).

31. Secondary chemical lab supply.

32. Post-accident sampling system.

33. Auxiliary boiler house (Section 10.4.10).

34. Chilled water system (Section 9.2.2.2).

35. Condensate pump seal water backup (Section 10.4.7).

NOTE: The demineralized water system is isolated from the primary grade water system via two normally closed isolation valves with tell-tale leakoff protection provided. This arrangement prevents possible contamination of demineralized water from the primary grade water system. The water treatment systems are primarily enclosed within

temperature-controlled buildings. Tanks and water treatment equipment located outside the building are provided with a means of temperature control so that the entire BVPS-2 UFSAR Rev. 0 9.2-30a system is capable of operating within the environment to which it is exposed. 9.2.3.3 Safety Evaluation

The demineralized makeup water system is not safety-related and the failure or malfunction of this system will not adversely affect the essential systems or components necessary for safe shutdown. The method of isolating the system and/or major system components is by manual isolation.

A nonsafety grade connection is provided to the primary DWST (Section 10.4.9) to allow gravity drain to that tank if

additional volume is needed for auxiliary feedwater supply to the steam generators. The safety grade pressure boundary of the primary BVPS-2 UFSAR Rev. 0 9.2-31 demineralized water tank is maintained by a portion of Safety Class 2 piping and closed valves as described in Section 10.4.7. 9.2.3.4 Inspection and Testing Requirements

The demineralized water makeup system is inspected during construction to ensure proper installation. All components are inspected prior to installation to ensure that they comply with the applicable design specification. The demineralized water distribution system is hydrostatically tested after construction. System operability tests are performed as described in Section 14.2.12. The water supply and treatment systems are in continual use and, thus, do not require periodic testing beyond the normal observation and inspection during routine operation to ensure operability. Water samples are taken periodically from the demineralized water makeup system to determine pH value and possible contamination or deterioration. Pressure, temperature, and tank level are monitored periodically to verify proper system operation.

9.2.3.5 Demineralized Water Storage System Instrumentation Requirements

Control switches with indicating lights for the demineralized water distribution pumps are provided in the main control room.

Interlocks will stop the pumps upon the loss of discharge header pressure. This is annunciated in the main control room as demineralized water distribution system trouble. This condition

is also monitored by the BVPS-2 computer system. There are two demineralized water distribution pumps rated at 350 gpm each. Under normal operating conditions, one distribution pump will take suction from the storage tank to provide the required demineralized water makeup, and the second

pump will provide system backup. The water storage tank makeup valve will modulate to maintain the required level. The tank high and low level alarm is annunciated in the main control room. These conditions are also monitored by the BVPS-2 computer system.

The level and temperature of the storage tank are continuously monitored in the main control room by indication, annunciation, and the BVPS-2 computer system. Selector switches for the demineralized water storage tank heaters and heater pumps are provided locally. Interlocks will start and stop the heater and heater pumps on demineralized water storage tank temperature and heater pump discharge temperature. Local indicating lights are provided to indicate when the heaters and heater pumps are operating and when power is available to the heater and heater pumps.

BVPS-2 UFSAR Rev. 17 9.2-32 9.2.4 Potable and Sanitary Water Systems 9.2.4.1 Design Bases

The domestic water system is designed to provide sufficient treated potable water from the Borough of Midland water system. This supply replaced the original water supply which was

provided from onsite wells. Potable water is distributed to plumbing fixtures, eye wash units, safety showers, and drinking water coolers throughout the station. In accordance with General Design Criterion 60, the domestic water system is not connected to any system having the potential for containing radioactive material. The system is nonsafety-related and is designated NNS class. The principal components of the system are listed in Table 9.2-9. The sanitary sewerage system is designed to collect sanitary waste from all plumbing fixtures except lavatories, sinks, and drains containing wastes which are potentially chemically or

radioactively contaminated. The collected waste is conveyed to the offsite Shippingport Boro sewage treatment plant. Contaminated or potentially contaminated waste is collected in systems physically separate from the sanitary sewerage system and conveyed directly to the radioactive liquid waste treatment system. 9.2.4.2 System Description

Domestic (potable) water is supplied through a connection to a local municipal water system.

The BVPS-2 domestic water system has two 1,300 gallon capacity electric hot water heaters and one circulating pump to provide hot domestic water to the system. The hot water heaters and the

hot water circulating pump are located in the BVPS-2 turbine building.

The BVPS sanitary sewerage system collects sanitary waste from plumbing fixtures throughout the station. The sewerage is conveyed to the offsite Shippingport Boro sewerage treatment facility that has sufficient capacity to process anticipated flow. BVPS-2 UFSAR Rev. 10 9.2-33 9.2.4.3 Safety Evaluation The domestic water and sanitary sewerage systems are nonsafety-related. Operation of the domestic water supply and treatment system is not necessary for safety. There are no interconnections between the domestic water system and the sanitary sewerage system or any other process system having the potential for containing radioactive materials. There are no interconnections between the sanitary sewerage system and any other process system.

The domestic water system is protected by an air gap at all interfaces with the sanitary sewerage system and any other

process systems. 9.2.4.4 Inspection and Testing Requirements

After installation, with all pipe joints exposed, the domestic water and sanitary sewerage systems are inspected

and tested hydrostatically. Testing requirements are described in detail in Section

14.2.12. 9.2.4.5 Instrumentation Requirements

Two hot water heating tanks are provided, each with a self-contained electric immersion heater and a local pushbutton with indicating lights for the manually-operated hot water circulating pump.

9.2.5 Ultimate

Heat Sink The ultimate heat sink (UHS) for BVPS-2 is the Ohio River (Section 2.4). The Ohio River will supply water to the SWS (Section 9.2.1.1) and the SSWS (Section 9.2.1.2).

BVPS-2 UFSAR Rev. 0 9.2-34 9.2.5.1 Design Bases The UHS meets the applicable requirements of the following criteria:

1. General Design Criterion 2, as it relates to structures housing the system, and the system itself

being capable of withstanding the effects of natural phenomena, such as earthquakes, tornadoes, hurricanes, and floods.

2. General Design Criterion 4, with respect to structures housing the system, and the system itself being capable of withstanding the effects of external missiles and internally-generated missiles, pipe whip, and jet impingement forces associated with pipe

breaks.

3. General Design Criterion 5, as it relates to the capability of shared systems and components important to safety being capable of performing required safety functions.

4. General Design Criterion 44, to assure:

a. The capability to transfer heat loads from safety-related structures, systems, and components to a heat sink during both normal operating and

accident conditions,

b. Component redundancy so that the safety function can be performed assuming a single active failure coincident with LOOP, and

c. The capability to isolate components, subsystems, or piping, if required, so that the system safety

function, will not be compromised.

5. General Design Criterion 45, as it relates to design provisions made to permit inservice inspection of

safety-related components and equipment.

6. General Design Criterion 46, as it relates to design provisions made to permit operational functional testing of safety-related systems and components to assure: a. Structural integrity and system leaktightness,

b. Operability and adequate performance of active system components, and

c. Capability of the integrated system to perform required functions during normal, shutdown, and

accident situations.

BVPS-2 UFSAR Rev. 0 9.2-34a 7. Regulatory Guide 1.27, as it relates to the requirements of the UHS.

8. Regulatory Guide 1.29, as it relates to the seismic design classification of system components.

9. The UHS meets the requirements of Branch Technical Position ASB 9-2, as it relates to the methods for calculating heat release due to fission product and heavy element decay.

10. The system shall provide water during normal operation, accident, and shutdown conditions at the flow rates, BVPS-2 UFSAR Rev. 14 9.2-35 temperatures and NPSH required by the SWS and the SSWS (Sections 9.2.1.1 and 9.2.l.2).

11. The SWS is designed to handle the loads at a maximum river water temperature of 89F at either extremes of low river water level (el 648 ft-7 in) or the probable maximum flood (PMF) (el 730 feet). The design basis accident flows have been analyzed for the technical specification elevation limits, as described in Section 9.2.1.

9.2.5.2 System Description

The Ohio River is the UHS. The UHS, the SWS, and the SSWS have interfaces at the SWS intake structure, outfall structure, emergency outfall structure, and the SSWS intake structure all

of which are shown on the site plan (Figure 1.2-1). The Ohio River provides service water to both BVPS-1 and BVPS-2. The flow requirements for BVPS-2 are described in Section 9.2.1. The flow requirements for BVPS-1 are described in Chapter 9 of the BVPS-1 FSAR (Docket No. 50-334). The ability of the Ohio River to meet these flow requirements is discussed in Section 2.4.11. The inlet water temperature is unaffected by the SWS heat loads, because the outfall structure is located sufficiently downstream of the intake structures to prevent recirculation (Section

2.4.11.6). 9.2.5.3 Safety Evaluation

The flow available for the Ohio River (Section 2.4.11) is large compared to the flow required for safe shutdown of both BVPS-1 and BVPS-2. Since the Ohio River is not man-made, QA and seismic categories are not applicable. The effects of transportation accidents, potential seismically-induced dam

failures, ice formation, and channel diversions are discussed in Sections 2.2.3, 2.4.4, 2.4.7, and 2.4.9, respectively.

Technical Specifications and the Licensing Requirements Manual (Section 2.4.14) describe the procedures required in the event of extreme hydrological conditions.

9.2.5.4 Inspection and Testing Requirements

This section does not apply to the UHS. 9.2.5.5 Instrumentation Requirements

The Ohio River temperature can be determined from temperatur e indicators at several points in the SWS (Section 9.2.1). The river level can be determined by a depth scale mounted on the outside of the intake structure.

BVPS-2 UFSAR Rev. 12 9.2-36 9.2.6 Condensate Storage Facilities The following tanks store demineralized water of condensate quality and comprise the condensate storage facilities: the

DWST, the primary plant demineralized water storage tank (PPDWST), and the secondary plant demineralized water storage tank (SPDWST).

The 600,000 gallon DWST and the 140,000 gallon PPDWST are discussed in Sections 9.2.3 and 10.4.9, respectively.

The 200,000 gallon SPDWST is discussed below. 9.2.6.1 Design Bases The SPDWST design bases are:

1. The SPDWST stores condensate quality water for makeup to the turbine plant condensate system.

2. The SPDWST is nonsafety-related and is designated NNS class.

The tank material is ASTM A 240 Type 304 stainless steel or equivalent, and is designated in accordance with API 650 (modified) with an atmospheric design pressure.

3. Continued function of the SPDWST is not required for safe shutdown, and its failure could not reduce the

function of any safety-related equipment.

4. The concentration of radioactivity in the SPDWST is within the limits for unrestricted liquids given in 10 CFR 20.

5. The SPDWST and its associated piping are designed in accordance with ANSI B31.1 (Summer 1972 Addenda) and are classified nonseismic.

6. All outside piping is heat-traced and the condensate stored in the SPDWST is recirculated through a heater

to avoid freezing. 9.2.6.2 System Description

The 200,000 gallon SPDWST serves as a surge tank for the turbine plant condensate system. On low condenser hotwell level, condensate flows from the SPDWST through the makeup system to the condenser via gravity feed. On high condenser hotwell level, the excess condensate is transferred to the SPDWST by diverting some of the flow from condensate pumps back to the

tank. Freeze protection for the SPDWST consists of a 30 gpm storage

tank heater pump, storage tank heater, and heat-traced lines. The heat BVPS-2 UFSAR Rev. 0 9.2-37 tracing is automatically activated when water in the line goes below 35F. The storage tank heater and heater pump are automatically activated when the temperature in the tank goes below 45 F. The SPDWST is filled from the 600,000 gallon DWST. Level in the SPDWST is automatically maintained by a level indicator in the tank that actuates a level control valve on the discharge side

of the demineralized water distribution pumps. 9.2.6.3 Safety Evaluation

The SPDWST and its associated makeup and transfer piping are designated NNS class.

A failure of the SPDWST or a makeup and transfer system malfunction could not adversely affect essential systems or components necessary for safe shutdown under accident conditions.

Swales and catch basins in the yard area of the tank provide a minimum of 10,000 gpm drainage capacity, thereby providing adequate drainage capacity in the event of a tank rupture.

Overflow from the tank is piped directly to a catch basin. The condensate water may contain a small inventory of radioactive isotopes due to primary to secondary leakage, which enters the condenser as steam and the SPDWST after it is condensed. Radioactive secondary steam concentrations are

presented in Section 11.1. The environmental consequences of radioactive spills caused by

tank failures are analyzed in Section 2.4.13. 9.2.6.4 Inspection and Testing Requirements

The SPDWST is hydrostatically tested after installation. Water samples are taken periodically from the SPDWST to determine oxygen content, pH value, and possible radioactive contamination. Pre-operational tests are performed as described in Section 14.2.12.

9.2.6.5 Instrumentation Requirements

The SPDWST water level is automatically controlled by a level controller. A level indicator is provided in the main control room to indicate SPDWST water level. High or low levels of water in the SPDWST will cause an alarm in the main control room and are monitored by the BVPS-2 computer system.

9.2.7 Turbine

Plant Component Cooling Water System The turbine plant component cooling water (TPCCW) system transfers heat from designated nonsafety-related turbine plant equipment to the station service water system (Section 9.2.1). The system is a

BVPS-2 UFSAR Rev. 20 9.2-38 closed-loop system using treated demineralized water as cooling water; make-up is supplied from the demineralized water system.

9.2.7.1 Design Bases The design basis of the TPCCW system is as follows:

1. The system is nonsafety-related and is designated NNS class. 2. The system supplies cooling water at a maximum temperature of 95 F to the components as listed in Table 9.2-10. 3. The system transfers heat to the SWS, which is at a maximum average inlet temperature of 89 F (Section 9.2.1.1).

4. The TPCCW pumps are designed in accordance with Hydraulic Institute Standards 1969 and ASME VIII dated

1971 including all addenda through Summer, 1972, for

pressure retaining welds.

5. The TPCCW heat exchangers are designed in accordance with ASME Code for Boilers and Pressure Vessels Section VIII, Division 1 and also comply with the

requirements of Tubular Exchange Manufacturers

Association Standards.

6. The TPCCW surge tank is designed in accordance with API 650 dated June 1970, including Supplement No. 3, March 1972.

7. The piping system is designed in accordance with ANSI B31.1 dated 1967 including all addenda through

June 30, 1972.

8. Table 9.2-11 lists design parameters of the subsystem components.

9.2.7.2 System Description

The TPCCW is pumped through shell- and tube-type heat exchangers where it is cooled by service water. The TPCCW passes from the shell side of the heat exchanger to the principal equipment

listed in Table 9.2-10. Two 100-percent capacity 11,400 gpm pumps and two 100-percent capacity heat exchangers are provided. This capacity is based on the maximum heat load which could occur during normal BVPS-2 operation with a service water inlet temperature of 83 F. Normal plant operation requires one pump and one heat exchanger, with the remaining equipment on standby. Should the service water inlet temperature rise above 83F, the addition of a second heat exchanger operating in parallel is adequate to remove system heat loads, up to the design basis maximum service water inlet temperature of 89 F. BVPS-2 UFSAR Rev. 17 9.2-39 The TPCCW system is a closed-loop system. Variations in volume due to temperature changes are accommodated by a surge tank located at the pump suctions. The surge tank is situated such that it provides a net positive suction head for the pumps.

The entire system and the equipment cooled by the system, except as follows, are located in the turbine building: the evaporator

reboiler drain coolers are located in the waste handling building; the condensate polishing air compressor and the condensate polishing sample cooler are located in the condensate

polishing building. The auxiliary boiler sample coolers and auxiliary boiler blowdown vent condenser are in the auxiliary boiler enclosure located in the south office and shop building.

Thermal relief valves are provided on those portions of the system which might be overpressurized by a combination of closed

cooling water valves on the inlet and outlet of equipment and heat input from the isolated equipment.

The surge tank capacity of 3,173 gallons is sufficient to accommodate minor system surges and thermal swell. Makeup is supplied from the demineralized water system (Section 9.2.3).

An automatic, air-operated valve controls makeup flow to the surge tank. A chemical addition tank is connected to the pump discharge piping. To add chemicals to the system, the tank is isolated, drained, and filled with the desired chemicals. The tank isolation valves are then opened and the discharge pressure of the operating pump forces water through the tank, injecting the mixture into the common return line from the equipment served, and to the pumps. The desired water chemistry is obtained by the addition of appropriate chemicals for corrosion

inhibition and pH control. Service water is pumped from the Ohio River through the tube

side of the TPCCW heat exchangers and is returned to the circulating water discharge line from the main condensers.

9.2.7.3 Safety Evaluation A failure of this system will not affect the integrity of any safety-related equipment because it does not perform a safety function and does not provide cooling water to any safety-related equipment.

The station air-compressors are the only equipment requiring cooling water during plant shutdown and/or LOOP. These compressors are required for operation and maintenance reasons. Under TPCCW shutdown conditions, air compressor jacket cooling

water and water for the after coolers is supplied from the

domestic water system. A backup service water supply for the station air compressor is provided through a connection between the service water and TPCCW systems (Section 9.2.1).

BVPS-2 UFSAR Rev. 0 9.2-40 9.2.7.4 Inspection and Testing Requirements During the life of BVPS-2, all portions of the system are either in continuous or intermittent operation and performance tests

are not required. Components are accessible for observation during routine operation, and following installation of spare parts or piping modifications to confirm normal operation of the system. Preoperational tests are performed as described in Section 14.2.12.

9.2.7.5 Instrumentation Requirements The TPCCW pumps are controlled from the main control room via individual control switches with appropriate indicating lights. Automatic starting and stopping of the pumps is annunciated in the main control room and this annunciation is also monitored by

the BVPS-2 computer. A minimum flow protection for the TPCCW pumps is provided by a

flow control valve which opens when the discharge header flow is low and closes when discharge header flow is normal.

The TPCCW pumps low discharge header pressure is annunciated in the main control room by a common annunciator and monitored by the BVPS-2 computer. This low pressure signal automatically

starts the standby pump. A TPCCW temperature control valve will modulate to bypass

cooling water around the heat exchangers. A TPCCW differential pressure control valve will modulate to

maintain a predetermined pressure across the heat exchangers. The TPCCW heat exchanger high discharge temperature is also annunciated in the control room by a common annunciator and monitored by the BVPS-2 computer.

The TPCCW surge tank levels, high-high, and low-low, are annunciated in the control room by a common annunciator and monitored by the BVPS-2 computer.

The cooling water flow through the major equipment coolers, such as the hydrogen and oil coolers, is controlled automatically to maintain the cooled fluid at a constant temperature. Cooling water supply and return piping for each component contain valves and/or restricting orifices for flow control. The valves are either manually-operated (positioned before BVPS-2 start-up), or automatically air-operated (positioned by temperature control signals originating in the cooled system).

BVPS-2 UFSAR Rev. 12 9.2-41 9.2.8 Primary Grade Water System The primary grade water system is shared with BVPS-1. Two full capacity primary water pumps supply water from two BVPS-1 primary grade water storage tanks for both BVPS-1 and BVPS-2. The two tanks have sufficient capacity to meet the requirement of both BVPS-1 and BVPS-2. The tanks and pumps are located at

BVPS-1. The primary grade water system is nonsafety-related. 9.2.8.1 Design Bases

The following constitute the design bases for the primary grade water system:

1. The two BVPS-1 primary grade water storage tanks provide sufficient storage capacity to supply the required makeup water to the reactor coolant system (RCS) via the chemical and volume control system (CVCS) (Section 9.3.4), and to store recovered water from the BVPS-1 boron recovery system (BRS) and the BVPS-1 and BVPS-2 radioactive liquid waste systems (Section 11.2).

2. The two storage tanks (BVPS-1) contain sufficient water to provide the makeup required for plant start-up through 90 percent of equilibrium fuel cycle, and will still be 10 percent full after the start-up operation is complete, with no additional makeup water added to the tanks or system. This requirement is approximately 150,000 gallons.

9.2.8.2 System Description Primary grade water consists principally of processed radioactive liquid waste and reactor coolant letdown which has been stripped of dissolved gases and processed in the BRS of BVPS-1. Primary grade water is used exclusively in the reactor

plant systems; it is not provided to turbine plant systems. The BVPS-2 primary grade water is supplied from BVPS-1, which

has two 75,000-gallon vertical stainless steel tanks for primary grade water storage. Both tanks are equipped with a floating diaphragm roof which rides on the tank water level, thus isolating the water surface from the atmosphere and minimizing the amount of gases dissolved in the water. Each tank is also provided with the following: an atmospheric vent on the gas space above the floating roof, an external thermosiphon heater with an internal horizontal sparger on the hot leg tank entry, pump suction and recycle line connections, level indicators and

alarms, and a temperature controller. The primary grade water storage tanks are supplied with water

from the BRS test tanks. Station demineralized water is used for makeup to the primary grade water storage tanks.

BVPS-2 UFSAR Rev. 12 9.2-42 The BVPS-1 primary grade water supply pumps, each rated at 200 gpm and 310 feet TDH, obtain suction from the primary grade water storage tanks and discharge to the primary grade water supply header. The normal mode of operation is both tanks and one pump aligned to maintain the primary grade system supply

pressure for use on both BVPS-1 and BVPS-2.

The BVPS-2 primary grade water supply header provides primary grade water for the following purposes:

1. Makeup to the RCS via the chemical mixing tank and boric acid blender of the CVCS.

2. Supply to the radioactive solid waste system for spent resin flushing (Section 11.4).

3. Makeup to the spent fuel pool (Section 9.1.2) to compensate for evaporative losses.

4. Supply to the following equipment:

a. Boric acid batching tank,

b. Primary component cooling water surge tank fill,

c. Pressurizer relief tank, d. Steam generator blowdown evaporator flush and evaporator sample flush,

e. Steam generator blowdown evaporator bottoms piping and hold tank flush,

f. Boric acid transfer pump,

g. Chemical and volume control demineralizer flush, cesium removal, and fuel pool ion exchanger flush, and

h. Flush to cleanup ion exchangers.

5. Provide seal injection water for the following pumps:

a. Steam generator blowdown evaporator bottoms pumps, b. Steam generator blowdown evaporator circulation pumps, BVPS-2 UFSAR Rev. 14 9.2-43 c. Steam generator blowdown evaporator bottoms hold tank pump, A connection is provided from the demineralized water header to the primary grade water header such that demineralized water can serve as an alternate supply of water. A sample connection is also provided for periodic sampling and analysis as required.

9.2.8.3 Safety Evaluation

The primary grade water system function is nonsafety-related. However, it is important for normal plant operation to provide a reliable source of water for reactor coolant makeup. The use of two primary grade water storage tanks prevents contamination of the entire primary grade water supply at any time. With test tanks in the BVPS-1 boron recovery and BVPS-1 and BVPS-2 radioactive liquid waste systems, potential for contamination of the contents of either primary grade water storage tank is minimized.

9.2.8.4 Inspection and Testing Requirements

A program of testing and inspection ensures the design basis capability of the primary grade water system throughout its lifetime. Standby pumps are operated periodically, and

equipment is visually examined at appropriate intervals to ensure its availability. Pre-operational tests are performed as described in Section 14.2.12.

9.2.8.5 Instrumentation Requirements

All instrumentation required for the primary grade water tanks, pumps, and supply header is provided at BVPS-1. Local flow indicators are supplied in the pump seal water injection lines to the evaporator circulation pumps, the evaporator bottoms pumps, and the steam generator bottoms hold tank pump.

9.2.9 Reference

for Section 9.2 U.S. Nuclear Regulatory Commission (USNRC) 1980. Clarification

of TMI Action Plan Requirements. NUREG-0737. USNRC February 24, 2003. Safety evaluation by the Office of NRR related to Amendment 132 of the operating license (describes commitment regarding flow rate surveillance of RSS heat exchangers).

BVPS-2 UFSAR Tables for Section 9.2

BVPS-2 UFSAR Rev. 12 1 of 3 TABLE 9.2-1 STATION SERVICE WATER SYSTEMS COMPONENT DESIGN DATA Service Water Pumps

Quantity 3 Type Vertical turbine Motor, (hp) each 900 Seals Packed Rated capacity (gpm) 15,000 Head at rated capacity (ft. of

water) 190 Design pressure (psig) 150 Design temperature ( F) 100 Materials(ASTM numbers) Bowls or diffusers SA216 WCB Shaft A-479 TP 410 CL2 Impellers B148 UNS C95800 Discharge column SA515 GR 70 Head assembly SA515 GR 70

Condenser Water Booster Pumps

Quantity 2 Type Horizontal/centrifugal Motor, (hp) each 75 Seals Mechanical Rated capacity (gpm) 4,500 Head at rated capacity (ft of

water) 55 Design pressure (psig) 250 Design temperature ( F) 250 Materials (ASTM numbers) Casing A48 C1 30 Shaft A576 Gr. 1045 Impeller B143 Alloy Standby Service Water Pumps Quantity 2 Type Vertical turbine Motor, (hp) each 1,250 Seals Stuffing box Rated capacity (gpm) 15,000 Head at rated capacity (ft of

water) 200 Design pressure (psig) 175 Operating temperature range (F) 32-89 BVPS-2 UFSAR Rev. 7 2 of 3 TABLE 9.2-1 (Cont) Component Design Parameters Materials(ASTM numbers) Suction bell A48 C1 30 Shaft A582, Type 416 Impeller B584/932 Discharge column A106, GR. B Bowls and diffuser A48 C1 30 Wash Water Booster Pump Quantity 1 Type Vertical/centrifugal Motor, (hp) 15 Seals Mechanical Rated capacity (gpm) 300 Head at rated capacity (ft of

water) 120 Design temperature ( F) 90 Materials Casing A395 GGO-40-18 Shaft A322 GR.4140 Impeller A296 CF8M Emergency Diesel Generator Chemical Addition Pumps Quantity 2 Type Vertical/centrifugal Motor, (hp) each

1.5 Seals

Packing Rated capacity (gpm) 10 Head at rated capacity (ft of

water) 14 Design temperature ( F) 87 Materials Casing Ductile iron Shaft 316 SS Impeller Ductile iron BVPS-2 UFSAR Rev. 7 3 of 3 TABLE 9.2-1 (Cont) Component Design Parameters Control Room Refrigerant Condenser Recirculation Pumps Quantity 2 Type Horizontal/centrifugal Motor, (hp) each 1 Seals Packing Rated capacity (gpm) 45 Head at rated capacity (ft of

water) 20 Design temperature ( F) 104 Materials (ASTM numbers) Casing SA351 CF8M Shaft A276, Type 316 Impeller A744 CF8M NOTES:

 (1) Materials listed in this table may have been replaced with materials of equivalent design characteristics.

The term equivalent is described in UFSAR Section 1.12, "Equivalent Materials".

BVPS-2 UFSAR Rev. 0 1 of 1 TABLE 9.2-3 OPERATION OF SERVICE WATER VALVES Accident Initial Valve Action Service Water Valves Design basis accident loss-of-coolant coincident

with loss of normal unit power 1. Open valves to recirculation spray coolers

2. Open valves to emergency diesel generator cooling system heat

exchangers

3. Close valves to primary and secondary component cooling water heat exchangers and chillers Loss of offsite power 1. Open valves to emergency diesel generator cooling system heat

exchangers

2. All other valves remain in their normal operating position

BVPS-2 UFSAR Rev. 13 1 of 2 TABLE 9.2-4 PRIMARY COMPONENT COOLING WATER SYSTEM COMPONENT FLOW REQUIREMENTS

Description Quantity Required Flow, each (gpm) Reference

FSAR Section Components in Containment: CRDM shroud cooling coils 3 200 9.4.7.4 Reactor coolant pumps thermal barrier, stator, and bearing

oil coolers 3 436 5.4.1 Excess letdown cooler 1 167 9.3.4 Neutron shield tank cooler 1 32 9.2.2.3 Containment penetration cooling coils 10 3/coil (minimum) 3.8.1.1.3.

1 Primary drains cooler 1 130 9.3.3 RHR pump seal oil coolers 2 5-10 5.4.7 RHR heat exchangers 2 6,457 5.4.7 Components in Fuel Building: Fuel pool heat exchangers 2 1,100 9.1.3 Components in Auxiliary Building: Seal water heat exchanger 1 124** 9.3.4 Nonregenerative heat

exchanger 1 125* 9.3.4 Auxiliary steam degasifier

drain coolers 2 51 10.4.10 Primary sample panel coolers 11 12 9.3.2

Primary sample panel temperature control unit 1 5 Radiation monitors in

auxiliary and waste handling buildings 3 coolers 1 sample 15/cooler 3/sample 11.5 BVPS-2 UFSAR Rev. 0 2 of 2 TABLE 9.2-4 (Cont) Description Quantity Required Flow, each (gpm) Reference

FSAR Section Boron recovery system: Degasifier vent chiller 2 10 9.3.4.6 Degasifier trim cooler 2 142 9.3.4.6 Degasifier vent condenser 2 133 9.3.4.6 Degasifier circulation pump 2 1 9.3.4.6 Gaseous waste system: Overhead gas compressors 2 2 11.3 Components in Waste Handling Building: Steam generator blowdown system: Evaporator bottoms hold tank vent condenser 1 10 10.4.8 Evaporator distillate cooler 2 120 10.4.8 Evaporator overhead condenser 2 1,039 10.4.8 Evaporator bottoms cooler 1 35*** 10.4.8 Components in Main Steam Valve Area: Containment instrument air

compressors 2 35 9.3.1 NOTES:

• Only normal operating flow is shown. Flow for maximum purification and heatup is larger. ** Heatup flow is shown. Normal operating flow is 98 gpm. *** Expected makeup flow to cooler.

BVPS-2 UFSAR Rev. 20 1 of 1 TABLE 9.2-5 PRIMARY COMPONENT COOLING WATER SYSTEM SUBSYSTEM COMPONENT DESIGN DATA

CCW Heat Exchangers (normal

operation) Quantity 3 Duty, each (Btu/hr) 33,000,000 Design pressure (psig) 225 175 Design temperature (F) 200 120 Operating pressure (psig) 110 65 Design Operating temperature, in/out ( F) 114.7/100 83*/95 Materials Carbon steel SA-249** TP304 Fluids Demineralize

d water Service water CCW Surge Tanks Quantity 2 Type Cylindrical, vertical Capacity, each (gal) 1,650 Design pressure (psig) 50 Design temperature (F) 300 Material SA-285 Gr. C CCW Pumps Quantity 3 Type Horizontal centrifugal Motor, each (hp) 400 Seals Mechanical Capacity, each (gpm) 6,000 Head at rated capacity (ft of water) 200 Design pressure (psig) 400

• River water temperature (tube side inlet) varies from 34 - 89 F.
  • SEA-CURE is an acceptable tube material in place of SA-249 TP304.

BVPS-2 UFSAR Rev. 0 1 of 1 TABLE 9.2-6 CHILLED WATER SYSTEM, PRINCIPAL COMPONENT AND DESIGN PARAMETERS

Component Design Parameters

Chiller Unit Quantity 3 Capacity, (tons) each 650 Motor, (hp) each 600 Chilled Water Circulating Pump Quantity 3 Capacity, (gpm) each 1,560 Total head (ft of water) 200 Motor, (hp) each 150 Expansion Tanks Quantity 2 Capacity, (gal) each 202 Air Separator Quantity 1 Capacity (gpm) 3,600 Chemical Feeder Quantity 1 Capacity (gal) 8 BVPS-2 UFSAR Rev. 12 1 of 1 TABLE 9.2-7 NEUTRON SHIELD TANK COOLING WATER SYSTEM COMPONENT DESIGN DATA Neutron Shield Tank Cooler Quantity 1 Duty (Btu/hr) 80,000 Design pressure (psig) 150 150 Design temperature (F) 300 300 Operating pressure (psig) 50 15 Design operating temperature, in/out ( F) 100*/105 125/115 Material Type 316 SS Type 316 SS Fluids Component cooling water Shield tank water Neutron Shield Tank Expansion Tank Quantity 1 Type Cylindrical, vertical Capacity (gal) 1,275 Design pressure (psig) 25 Design temperature (F) 150 Material Stainless steel, Type 304 Corrosion Control Tank Quantity 1 Type Cylindrical, vertical Capacity (gal) 105 Design pressure (psig) 130 Design temperature (F) 150 Material Stainless steel, Type 304L

• Component cooling water inlet temperature may reach 106F during periods of maximum river temperature (89 F).

BVPS-2 UFSAR Rev. 7 1 of 1 TABLE 9.2-8 DEMINERALIZED WATER MAKEUP SYSTEM COMPONENT DESIGN DATA

Component Parameters Demineralized Water Storage Tank Quantity 1 Type Cylindrical vertical

Capacity (gal) 600,000 Design pressure (psig) Atmospheric and full of HO Design temperature ( F) 125 Material ASTM A240 Type 304 Stainless Steel Design code API-650 Demineralized Water Distribution Pump Quantity 2 Type Horizontal centrifugal

Motor, (hp) each 40 Seal Mechanical

Capacity (gpm) 350 Head at rated capacity (ft) 200 Design pressure (psig) 275 Design temperature ( F) 105 Material: Casing ASTM A-744 CF-8M Type 316 Stainless Steel Casting Shaft ASTM A-322 4140 Low Alloy Steel

Impeller ASTM A-744 CF-8M Type 316 Stainless Steel Casting NOTES 1. Materials listed in this table may have been replaced with materials of equivalent design characteristics. The term equivalent is described in UFSAR Section 1.12, "Equivalent Materials". BVPS-2 UFSAR Rev. 8 1 of 1 TABLE 9.2-9 POTABLE AND SANITARY WATER SYSTEM PRINCIPAL COMPONENTS Description Quantity Capacity Centrifugal hot water circulating pump 1 6.5 gpm Hot water storage

tanks 2 1,300 gal BVPS-2 UFSAR Rev. 20 1 of 2 TABLE 9.2-10 TURBINE PLANT COMPONENT COOLING WATER SYSTEM COMPONENT FLOW REQUIREMENTS

Description

Quantity Design Data For Each Component (gpm)

Reference FSAR Section Turbine lubricating oil

coolers 2 2,980 10.2 Electro-hydraulic oil

coolers 2 22 10.2 Hydrogen side seal oil

cooler 1 100 10.2 Air side seal oil cooler 1 260 10.2 Main generator exciter

coolers 2 240 10.2 Main generator hydrogen

coolers 4 1,503 10.2 Vacuum priming equipment

seal coolers 2 150 10.4.5 Blowdown tank drain cooler 1 405 10.4.8

Turbine plant sample

coolers 5 15 9.3.2 Evaporator reboiler drain

coolers 2 121 11.2 Isolated phase bus duct

air coolers 2 93

8.1.3 Station

air compressors 2 34.5 9.3.1 Condensate polishing air

compressor 1 25 10.4.6 Heater drain pumps 2 8 10.4.7 Separator drain pumps 2 5 10.4.7 Condensate pumps 3 10 10.4.7 Main feed pumps 2 65 10.4.7 Condensate polishing

sample sink cooler 1 7 10.4.6 BVPS-2 UFSAR Rev. 12 2 of 2 TABLE 9.2-10 (Cont)

Auxiliary boiler sample coolers 2 0.5 10.4.10 Auxiliary boiler

blowdown vent condenser 1 138 10.4.10 Startup feedwater

pump 1 38 10.4.7 Auxiliary boiler

conductivity cooler 1 0.5 10.4.10 Steam generator

Blowdown demineralizer Heat exchanger 2BDG-E23 1 1000 10.4.8 Main generator

hydrogen dryer cooler 2GMH-E23 1 1 ----

BVPS-2 UFSAR Rev. 12 1 of 1 TABLE 9.2-11 TURBINE PLANT COMPONENT COOLING WATER SYSTEM SUBSYSTEM COMPONENT DESIGN DATA Quantity 2 Duty (MBH) 64.4 Fluids Treated deminer-alized water Service water Design temperature, ( F) 300 300 Design pressure (psig) 150 150 Design operating temperature (inch F) 106.7 86 Materials Carbon steel CU-NI B-111 Design code ASME Section VIII ASME Section VIII Quantity 2 Type Dual volume

horizontal pump Fluid Treated deminer-alized water Capacity (gpm) 11,000 Total dynamic head (ft) 160 Design temperature (F) 150 Design pressure (psig) 212 Material Cast Iron Quantity 1 Type Cylindrical, vertical Capacity (gal) 3,173 Design pressure (psig) Atmosphere Design temperature (F) 125 Material A 285 Grade C Design code API 650 NOTES 1. Materials listed in this table may have been replaced with materials of equivalent design characteristics. The term equivalent is described in UFSAR Section 1.12, "Equivalent Materials".

2. Technical specifications permit plant operation up to 89 F river water temperature.

AUX BAY AUX BAY c BAY STANDBY SERVICE WATER PUMPS 2SWE-P21B SERVICE WATER PUMPS P21 A P21B UN IT 1 AUX RW PUMPS 22 102C2 1028 TO/FROM UN IT 1 RW TO/FROM UNIT 1 RW AND DIESEL DRIVEN FIRE PROTECTION WATER PUMP 116A 1168 TCV106 LEGEND RW RIVER WATER SYSTEM AUX AUXILIARY MOTOR CONTROL CENTER CONTROL AUXILIARY FEEDWATER CIRCULATING SAFEGUARDS AREA COOLING ROD CON AREA COOLING MCC E-3 ROOM CODLING POST ACCIDENT SAMPLE SYS MCC E-4 ROOM COOLING CONTROL ROOM COOLING CHILLED WATER UN lT COOLERS A HEADER DCV116 FUEL POOL EMERGENCY MAKEUP 31 2CCS-E21A SECONDARY COMPONENT COOLING WATER 2CCS-E21B HEAT EXCHANGERS 34 108"A CIRC WATER REV. 1 2 CNMT CONTAINMENT DIG EMERGENCY DIESEL GENERATOR DCV BACKPRESSURE CONTROL VALVE EOS EMERGENCY OUTFALL STRUCTURE RECJRC RECIRCULATION CHLOR INJ CHLORINATED WATER INJECTION EOS PRIMARY COMPONENT ALL VALVE AND EQUIPMENT IDENTIFICATION NUMBERS ON THIS FIGURE ARE PRECEDED BY THE SYSTEM DESIGNATOR "2SWS" UNLESS OTHERWISE INDICATED. FIGURE 9.2-1 SERVICE WATER SYSTEM

REFERENCE:

STATION DRAWINGS OM 29-4. 30-1, 30-1A, 30-2. 30-3. AND 30-4 BEAVER VALLEY POWER STATION UNIT NO. 2 UPDATED FINAL SAFETY ANALYSIS REPORT 0:: 0:: w w 0 0 <l: <l: w w I I z z 0:: 0:: ::J ::J l-l-w w 0:: 0:: ' []J I A' RHS HEAT EXCHANGER PUMP SEAL COOLER RHS HEAT EXCHANGER PUMP SEAL COOLER THERMAL BARRIER RCP 21A UPPER BRG OIL COOLER STATOR AIR COOLERS LOWER BRG COOLER I THERMAL BARRIER RCP 21C UPPER BRG OIL COOLER STATOR AIR COOLERS

• 305 LOWER BRG COOLER THERMAL BARRIER I UPPER SRG OIL COOLER RCP 218 STATOR AIR COOLERS 304 LOWER BRG COOLER CRDM SHROUD COOLING COILS PRIMARY DRAINS COOLER NEUTRON SHIELD TANK COOLING --KI291 --KI290 INSTRUMENT AIR COMPRESSORS PRIMARY COMPONENT REV. 112B 103A ... 103C ... 103B 114 151-2 d 151-1 0:: w 0 <( PRIMARY COMPONENT COOLING WATER w I HEAT EXCHANGERS COOLING WATER SURGE 100A TANKS I I PRIMARY DEMINERALIZED GRADE WATER WATER NON REGENERATIVE HEAT WATER HEAT EXCHANGER 462 BORON RECOVERY DEGASIFIERS

'A' & 'B' GASEOUS WASTE OVERHEAD COMPRESSORS 'A' & 'B' PRIMARY SAMPLE PANEL COOLERS REFRIGERATION UNIT <SEE NOTE! >-__. a... 0... ::J Vl FUEL POOL HEAT ' co EXCHANGER I A' A FUEL POOL HEAT EXCHANGER 'B' NOTE: REFRIGERATION UNIT IS 2SSR-ACU22 LEGEND BRG BEARING SW SERVICE WATER ALL VALVE AND EQUIPMENT IDENTIFICATION NUMBERS ON THIS FIGURE ARE PRECEDED BY THE SYSTEM DESIGNATOR "2CCPN UNLESS OTHERWISE INDICATED. FIGURE 9.2-10 PRIMARY COMPONENT COOLING WATER SYSTEM

REFERENCE:

STATION DRAWINGS OM 15-1.2, 3, 4. 5, AND 6 BEAVER VALLEY POWER STATION UNIT NO. 2 UPDATED FINAL SAFETY ANALYSIS REPORT 1 2 BVPS-2 UFSAR Rev. 17 9.3-1 9.3 PROCESS AUXILIARIES

9.3.1 Compressed

Air Systems

Three air systems comprise the compressed air systems: the station air system, the condensate polishing air system, and the containment instrument air system. The station air system is

divided into two subsystems: the station service air system and the station instrument air system. Figure 9.3-1 illustrates the components and air lines associated with these systems. 9.3.1.1 Station Air System

The station air system is composed of the following air systems: station service air system and the station instrument air

system. Both of these air systems are designed to provide sufficient compressed air of suitable quality and pressure to meet individual system requirements.

The station service air system provides air throughout the plant for air-operated maintenance and repair equipment operation. The station service air system can also supply air to the

containment instrument air system via a filtering arrangement. The station instrument air system provides air for air-operated instrumentation and controls outside of the containment. The station instrument air system also provides a backup supply to the containment instrument air system.

9.3.1.1.1 Design Bases

The station air system is designed in accordance with the following criteria:

1. Provides normal station instrumentation air and plant service air.

2. Two identical electric motor-driven station air compressors supply air to the station instrument and

station service air systems. To ensure reliability, each air compressor has the capacity to supply 100-percent of station instrument and station service air requirements.

3. To improve plant operability, a nonsafety, onsite diesel generator is available to supply electric power to the station air compressors. This diesel generator will supply power only after a loss of normal power.

Additionally, a 100-percent capacity diesel-driven air compressor is provided to supply the instrument air system as a backup to the electric motor-driven compressors.

BVPS-2 UFSAR Rev. 17 9.3-2 4. Design temperatures for station air piping are those resulting from extreme ambient conditions. The aftercooler is designed to cool the discharge air to 115F. The station instrument air design dewpoint is adequate for the entire system. The system is located in heated areas of Beaver Valley Power Station-Unit 2 (BVPS-2).

5. The station instrument and station service air systems are nonsafety-related systems, are classified as non-nuclear safety (NNS) class, and are designed in accordance with ANSI B31.1, dated 1967, including all

addenda through June 30, 1972. 9.3.1.1.2 System Description Two dry-screw electric motor-driven station air compressors provide instrument and service air throughout the plant. Each compressor is rated at 100-percent capacity for the air requirements of the station instrument air and station service air systems collectively. A 100-percent capacity diesel-driven compressor is provided to supply the instrument air system as a backup to the electric motor-driven compressors. (Refer to Figure 9.3-1).

Both electric motor-driven compressors are arranged with discharge piping from individual receivers to individual air dryers. A branch line from the cross-tie line between the discharge piping from the station air receivers supplies air for the station service air system through an air-operated valve (AOV). Station instrument air requirements external to the containment building are normally supplied from one of the two station air receivers through connections upstream of the service air isolation AOV, air passes through one of the two drying units located downstream of the station air receivers, and is supplied to the instrument air receivers. If air pressure in the station instrument air system drops to a

predetermined point, the station service air header AOV will automatically close and divert all station air to station instrument air. The station service air header isolation valve must be manually reset after an automatic closure. The diesel-driven air compressor is aligned through check valves to only supply the instrument air system and will auto start at a predetermined point following closure of the AOV.

One electric motor-driven station air compressor operates on a load/unload mode while the other compressor is on a standby

automatic mode. The compressor on the automatic mode will start if the instrument air receiver pressure falls to a predetermined point. The diesel-driven instrument air compressor will start automatically when the instrument air header reaches a lower predetermined point.

The electric motor-driven station air compressors operating modes are alternated periodically to maintain uniform wear and to verify proper component operability. The diesel-driven compressor is normally kept in a standby condition.

BVPS-2 UFSAR Rev. 17 9.3-3 The air system compressors are equipped with integral relief valves located on the high and low pressure stages for prevention of mechanical damage should there be overpressurization. Relief protection is also provided on the

station air receivers to protect them from overpressurization.

For the electric motor-driven compressors, cooling water is provided to the inter- and after-coolers and compressor water jackets from the turbine plant component cooling water (TPCCW) system (Section 9.2.7) during normal plant operation, and from

the domestic water system during periods of plant shutdown. The diesel-driven compressor is air cooled.

Because the station instrument air and station service air systems components are located in the turbine building, missile generation from a rupture-type failure of any of these components will not cause damage to any safety-related

equipment.

The main components of the station instrument air system are as

follows: one diesel-driven air compressor, three heatless regenerative desiccant type air dryers, the required prefilters and afterfilters, and regeneration controls. The dryers and instrumentation are designed for complete, automatic, and continuous operation, providing dry air at 100 psi gage pressure and 100 F. The air passes through one of two adsorber columns for a set period of time. The air flow is then switched automatically to the second tower while the first adsorber is reactivated by a purging air flow to release adsorbed water, enabling the unit to go back on line when required. Compressed dry air is discharged to the station instrument air receiver. A bypass filtering arrangement (FLT37 and FLT39 on Figure 9.3-1) is provided around the normal air dryers to allow the system to stay in operation when providing maintenance and repair to the

air dryers.

Sufficient air receiver capacity is provided to meet all instrument air requirements external to the containment for a

period of approximately 10 minutes, permitting continuous control during any temporary reduction in supply pressure. This allows sufficient time for the operators to restore supply

pressure with such emergency procedures as manually starting the standby compressor in the event that automatic start controls

have failed, or closing valves to isolate the service air header

in the event of system leakage.

The electric motor-driven station air system compressors have the capability of operating from the nonsafety, onsite diesel generator power supply. The diesel-driven instrument air compressor is capable of starting and supplying the instrument air system regardless of the availability of offsite power.

Table 9.3-1 contains the design data for system components of

the station instrument air and station service air systems.

BVPS-2 UFSAR Rev. 17 9.3-4 9.3.1.1.3 Safety Evaluation The two systems which comprise the station air system (station instrument air system and station service air system) are designated NNS class and are designed to ANSI B31.1 standards. The station air system is not required for safe shutdown of BVPS-2. Portions of the system piping which are in Category I buildings are seismically supported.

Consequences of station air system component failures are presented in Table 9.3-2. 9.3.1.1.4 Inspection and Testing Requirements

Preliminary tests are performed as described in Section 14.2.12. During normal operation, periodic tests are performed on the standby electric motor-driven compressor of the station air system and the diesel-driven instrument air compressor to ensure proper starting when required. Other testing of the station air system is not required as it is normally in operation.

9.3.1.1.5 Instrumentation Requirements

The electric motor-driven station air compressors are controlled manually from the main control room via individual control switches with appropriate indicating lights. These two compressors can also be controlled locally by means of a transfer switch with indicating lights and pushbuttons. The diesel-driven instrument air compressor is controlled only at the local control panel. The local control panels for the diesel-driven air compressor and associated air dryer contain the necessary indication and alarms to locally assess the operation of the units.

The station air header isolation trip valve is monitored in the main control room by indicating lights. This valve trips closed on low station instrument air header pressure and must be

manually reset at the isolation valve. The domestic water to station air compressors valve is controlled manually from the main control room by a control switch with appropriate indicating lights.

The station and instrument air compressors unloading valves load the compressors on low air receiver pressure and unload the

compressors on high air receiver pressure.

The station air compressors supply breakers are controlled locally via individual pushbuttons with appropriate indicating

lights. These supply breakers trip open on a motor electrical protection trip.

BVPS-2 UFSAR Rev. 17 9.3-5 A common annunciation is provided in the main control room for station and condensate polishing air systems trouble with the following inputs from the station and instrument air systems: station instrument air compressors trouble, (with its following inputs: local control configuration, compressor motor overload, high pressure inlet air temperature high, bleedoff air pressure

high, oil temperature high, and oil pressure failure), station instrument air compressors supply breakers motor electrical protection trip, normal station instrument air dryer trouble (failure to shift, high dewpoint), station air receivers pressure low, and station air header pressure low. The preceding inputs are also monitored by the BVPS-2 plant computer.

Annunciation is also provided in the main control room for the station instrument air receiver tank trouble with station instrument air receiver pressure low and station instrument air header pressure low inputs. These inputs are monitored by the BVPS-2 computer.

Local indicating lights are provided. Indicators are provided in the main control room for: station

air receiver pressure, station air header pressure, normal station instrument air receiver pressure, and station instrument air header pressure. 9.3.1.2 Condensate Polishing Air System

The condensate polishing air system provides all compressed air requirements within the condensate polishing building. The

system diagram is shown on Figure 9.3-1. 9.3.1.2.1 Design Bases

The condensate polishing air system is designed in accordance with the following criteria:

1. Provides compressed air for the following uses within the condensate polishing building: powdered resin dewatering system, chemistry lab, and various service hose connections throughout the building.

2. One dry-screw condensate polishing compressor has the capacity to supply 100-percent of the air requirements

for the condensate polishing building.

3. Design temperatures for condensate polishing air piping are those resulting from extreme ambient conditions.

BVPS-2 UFSAR Rev. 17 9.3-6 4. No air drying is required for the condensate polishing air system.

5. The condensate polishing air compressor is nonsafety-related and is classified as NNS class.

6. All air piping is designed in accordance with ANSI B31.1, dated 1967, including all addenda through June 30, 1972.

9.3.1.2.2 System Description The condensate polishing air system is depicted on Figure 9.3-1.

A single dry-screw air compressor provides compressed air for condensate polishing building uses. The compressor is rated at

100-percent capacity based on the building's air requirements. In the event that the condensate polishing air compressor is not functioning, a backup supply of compressed air will be provided through a crossover line from the station service air system. The condensate polishing air compressor also acts as a backup

air supply for the station air system via the same crossover. An automatic start feature was added to the condensate polishing compressor. Upon decreasing station air header pressure, the condensate polishing compressor will automatically start.

Design data for the condensate polishing air system are given in Table 9.3-1. 9.3.1.2.3 Safety Evaluation The condensate polishing air system is NNS class and is designed

to ANSI B31.1 piping requirements. Consequences of condensate polishing air system component

failures are presented in Table 9.3-2. 9.3.1.2.4 Inspection and Testing Requirements

Preliminary tests are performed as described in Section 14.2.12. The condensate polishing air system does no t require in-service testing as the system will be operating on a regular basis. 9.3.1.2.5 Instrumentation Requirements

The condensate polishing air compressor is controlled from the main control room by a control switch with appropriate indicating lights. The compressor can also be controlled locally by means of a transfer switch with indicating lights and pushbuttons.

BVPS-2 UFSAR Rev. 17 9.3-7 The condensate polishing air compressor unloading valve loads the compressor on low air receiver pressure and unloads the compressor on high air receiver pressure.

The condensate polishing air compressor supply breaker is controlled locally by a pushbutton with appropriate indicating lights. This supply breaker trips open on a motor electrical

protection trip. A common annunciation is provided in the main control room for

station and condensate polishing air system trouble with the following inputs from the condensate polishing air system: condensate polishing air receiver header pressure low, condensate polishing air compressor trouble (with its following inputs: compressor motor overload, high pressure inlet air temperature high, bleedoff air pressure high, oil temperature

high, and oil pressure failure) and condensate polishing air compressor supply breakers motor electrical protection trip. The preceding inputs are monitored by the BVPS-2 plant computer.

Local indicating lights are provided. 9.3.1.3 Containment Instrument Air System The containment instrument air system provides sufficient compressed air of suitable quality and pressure to instrumentation located within the containment boundary.

9.3.1.3.1 Design Basis The containment instrument air system is designed to meet the

following requirements:

1. To provide air of suitable quality and pressure for the reactor containment building instrumentation.

2. To ensure reliability, two identical 100-percent capacity air compressors are provided.

3. The containment instrument air system compressors and dryer components are Seismic Category II and are located in the main steam valve house.

BVPS-2 UFSAR Rev. 12 9.3-8 4. The containment instrument air system supplies air to safety-related valves; however, the system is nonsafety-related because these valves are designed to fail in a safe position upon system loss of compressed

air. 5. The operation of the containment instrument air system is required for normal station operation.

6. To improve plant operability following a loss of normal power, a nonsafety, onsite diesel generator is available to supply electric power to the containment instrument air system. This diesel generator will

supply power only after a loss of normal station power. 9.3.1.3.2 System Description Figure 9.3-1 includes the system diagram for the containment instrument air system. The containment instrument air system supplies air to instrumentation and controls, and valves inside the containment. The system draws air from the containment atmosphere and discharges compressed dry air to the control and instrumentation header (inside containment). This design eliminates pressurization of the containment atmosphere from this source.

The containment instrument air system is a separate, independent compressed air system. Two motor-driven, 100-percent capacity, oil-free (nonlubricated) air compressors are provided for the containment instrument air system. These compressors are located inside the main steam valve house, but draw air from the containment atmosphere. During normal operation, one of the two containment instrument air compressors operates on a load/unload mode while the other operates on an automatic standby mode. The compressor on automatic standby mode starts when the containment instrument air system pressure falls below a predetermined set-point (95 psig). The containment instrument air compressor operating modes are alternated periodically to maintain uniform

wear and verify proper component operability. Both containment instrument air compressors have the capability to be operated from the nonsafety, onsite generator power system. A 100-percent capacity refrigerant type air dryer is provided in the discharge line from the compressors. The design dewpoint on the discharge of the dryer is +35F at 95 psig. This is adequate for the instrument air used within the containment. A desiccant-type cartridge filter (FLT23 on Figure 9.3-1) is provided in the bypass around the dryer to facilitate a level of air drying during dryer failure or maintenance. All liquid

drains from the dryer are piped

BVPS-2 UFSAR Rev. 15 9.3-8a to the liquid waste system (Section 11.2). The dryer is not seismically qualified, but is seismically mounted to meet Seismic Category II requirements. Two air receivers are provided: a 31.8 ft capacity receiver located in the main steam valve house and an approximately 57

ftcapacity receiver located in the containment. The 31.8 ft receiver acts as a general receiver for the system while the approximately 57 ft receiver acts as a reserve supply in the event of a containment

BVPS-2 UFSAR Rev. 13 9.3-9 isolation Phase A (CIA) signal. This system supplies air to instruments and AOVs whose total combined requirements are 30 scfm. Containment isolation valves are safety-related and will close when a CIA signal exists. Containment isolation valves will not close on loss of onsite power, thereby maintaining system

operability under this condition. A backup supply of compressed air is provided from these two

sources: 1. A cross-connect from the station service air system within the containment. This cross-connect is provided with (normally closed) isolation valves and a coalescing-type cartridge filter (FLT24 on Figure 9.3-1) to remove moisture from the service air.

2. A cross-connect from the station instrument air system within the main steam valve house. A motor-operated valve (MOV) is provided in this cross-connection. This MOV is remotely operable from the main control room when needed. The compressed air provided is filtered and dried station instrument air.

Cooling water for the containment instrument air compressors is supplied by the primary component cooling water (CCP) system (Section 9.2.2.1). Table 9.3-3 contains design data for

components of the containment instrument air system. 9.3.1.3.3 Safety Evaluation

The containment instrument air system is nonsafety-related, and is not required for safe shutdown. Instrumentation and controls

served by the system are designed such that the equipment will fail in the safe mode upon loss of air.

The containment instrument air system is a QA Category II system. Since the components and piping are located in Category I buildings, they are protected from earthquakes, flooding, and

tornadoes. Consequences of containment instrument air system component

failures are presented in Table 9.3-4. 9.3.1.3.4 Inspection and Testing Requirements

Preliminary tests are performed as described in Section 14.2.12. During normal operation, periodic tests are performed on the

standby compressor of the containment instrument air system to ensure its

BVPS-2 UFSAR Rev. 15 9.3-10 proper starting when required. Other testing of the containment instrument air system is not required as it is normally in operation.

9.3.1.3.5 Instrumentation Requirements The containment instrument air compressors are controlled from

the main control room via individual control switches with appropriate indicating lights. The containment instrument air compressors can also be controlled locally by means of local

selector switches. The containment instrument air compressors are furnished with a

local panel which contains indicating lights for each protective trip device.

A containment instrument air compressor annunciator display is actuated in the main control room whenever any of the protective devices trip a compressor.

Containment instrument air compressor annunciator displays with the associated BVPS-2 computer inputs are actuated in the main

control room for feeder circuit breaker auto/manual trip conditions.

The containment instrument air dryer is furnished with locally-mounted pressure and temperature indicators necessary to monitor dryer performance. An alarm is furnished to the control room should a dryer malfunction occur.

An indicator for containment instrument air system air pressure is located in the main control room. An annunciator is actuated on low pressure.

Local pressure indicators are provided for monitoring of containment instrument air compressor operation.

Containment instrument air isolation valves, powered from Class 1E buses, are controlled from the main control room via individual control switches with indicating lights. These

containment isolation valves will automatically close when a CIA signal exists.

The containment instrument air receiver backup supply valve is controlled from the main control room with a control switch and appropriate indicating lights.

BVPS-2 UFSAR Rev. 13 9.3-11 9.3.2 Process Sampling System 9.3.2.1 Reactor Plant and Process Sampling System

The reactor plant and process sampling (RPPS) system routes liquid and gaseous samples from the various fluid systems to a common sample station where samples are conditioned as required for collection and/or continuous monitoring. The system is used during normal plant operation. 9.3.2.1.1 Design Bases The RPPS system is designed in accordance with the following

criteria:

1. To provide a means of obtaining representative liquid and gaseous samples, as required by Regulatory Guide

1.21, for on-line and grab sample analysis.

2. All RPPS is performed within the primary plant sample cubicle, which is located in the auxiliary building to

minimize the potential spread of contamination.

3. The RPPS system is designed to isolate at the containment boundary on a CIA signal (Section 6.2.4) and is in accordance with Appendix A of 10 CFR 50 and General Design Criterion (GDC) 55. The exception is the steam generator blowdown (SGB) sample system, which is in accordance with GDC 57, and the SGB sample isolation valves will close upon the initiation of the auxiliary feedwater system (Section 10.4.9).

4. The sampling system is designed to limit effluents to unrestricted areas, under normal and anticipated malfunctions or failure, in accordance with the guidelines of 10 CFR 20, Section 20.1(c).

5. The system is designed to obtain reactor coolant samples during reactor operation from either the hot or the cold legs of the reactor coolant system (RCS).

Reactor coolant samples may also be obtained during cooldown, when the system pressure is low, through the use of sample points in the residual heat removal (RHR) system.

6. The RPPS system is capable of providing samples for laboratory or on-line analysis. High temperature samples are reduced in temperature by sample coolers prior to sample acquisition or on-line analysis. The

system is also capable of reducing pressure to a suitable level before sampling.

BVPS-2 UFSAR Rev. 16 9.3-12 7. The RPPS system has no engineered safety function and is designated NNS class, QA Category II, with the sample piping being designed in accordance with ANSI B31.1, dated 1967, including all addenda

through June 30, 1972. An exception to this is the containment isolation portion of the sample system piping which is designed in accordance with ASME Section III, Code Class 2 and Seismic category I and various process sample tubing lines which are designated Quality Assurance Category I, Seismic

Category I, Safety Class 2.

8. General Design Criterion 1, as it relates to quality standards and records.

9. General Design Criterion 2, as it relates to design bases for protection against natural phenomena.

10. General Design Criterion 13, as it relates to instrumentation and control.

11. General Design Criterion 14, as it relates to the reactor coolant pressure boundary.

12. General Design Criterion 26, as it relates to reliably controlling the rate of reactivity changes.

13. General Design Criterion 60, as it relates to control of releases of radioactive materials to the environment.

14. General Design Criterion 63, as it relates to the monitoring of fuel and waste storage.

15. General Design Criterion 64, as it relates to monitoring radioactivity releases.

16. ANSI N13.1-1969, as it relates to the sampling of airborne radioactive material from gaseous process

streams and tanks. 9.3.2.1.2 System Description The RPPS system provides for the remote sampling of process or radioactive systems throughout BVPS-2. All samples are piped to a common sample acquisition and analysis panel.

Sample lines coming from within the containment normally have two remotely-controlled, air-operated containment isolation valves (Section 6.2.4), one inside containment and one outside containment. The SGB system sample lines have one remotely-controlled, air-operated containment isolation valve located outside containment. Sample lines for post-accident sampling, as well as for normal reactor plant sampling, are provided with remotely-operable, solenoid-operated containment isolation

valves in lieu of the air-operated type. All sampling system

BVPS-2 UFSAR Rev. 13 9.3-13 valves, except the containment isolation valves, are controlled from the primary sampling system panel. The remote sample valves are provided with multi-position switches (Section 9.3.2.1.5). The manually-operated sample valves, located behind the sample panel and the 2-foot concrete shielding, are operated by the use of reach rods.

The primary coolant, RHR system, and safety injection accumulator sample lines join their respective common headers downstream of the selection valve, prior to penetrating the

containment. The reactor coolant samples flow through delay coils permitting sufficient decay of nitrogen-16 to allow safe handling of the samples. Sample lines are routed to the sampling station located in the auxiliary building at el 718 ft-6 in. Part of the sampling station consists of a conditioning rack which reduces the pressure and temperature of the SGB samples prior to their admittance to the sample panels, to insure safe sample handling. Sample lines from systems that normally operate at high temperatures (Table 9.3-5) or high pressures are routed through the sample system coolers or pressure reducers, as required, before sampling. These coolers use the primary CCW system (section 9.2.2.1) for the removal of heat. The sample panel also has the capability for grab sample acquisition through the sample cylinders or at the sample sink. To insure that representative samples are obtained, sufficient sample purging is done before sample acquisition or analysis. The sample sink collects any spillage during the sampling procedures. An overhead hood exhausts the potentially radioactive gases to the supplementary leak collection and release system (SLCRS) (Section 6.5.3).

The RPPS sampling system is designed to be operated manually during conditions ranging from full power operation to cold shutdown. The SGB system is continuously monitored while other samples are acquired on an intermittent basis.

The SGB samples provide for continuous monitoring for Na (sodium), pH, cation conductivity, and radioactivity. A radiation monitor located on the common header into which the

blowdown sample lines discharge, is used to detect excessive radioactivity from the steam generators. Isolation of a faulty steam generator is done by selectively permitting a sample flow

to the radiation monitor, from one steam generator at a time. The SGB sample line isolation is discussed in Section 11.5.2.5.10. A constant temperature bath, located in the conditioning racks is provided for SGB samples. These samples are continuously measured for conductivity in order to minimize errors in conductivity measurement due to temperature differences. The bath temperature is maintained by a closed loop subsystem containing a circulating pump and a mechanical

refrigeration unit.

BVPS-2 UFSAR Rev. 13 9.3-14 Demineralized water is supplied to clean the sampling sinks and radiation monitoring equipment.

Under normal system operation, the purge flow of reactor plant samples are normally discharged via the volume control purge header to the volume control tank (VCT) or routed to the nuclear

vents and drains system (Section 9.3.3). The SGB purge is routed to a condensate receiver of the auxiliary steam system (Section 10.4.10), where it is returned to the condensate cycle via the main surface condenser. Radioactive SGB samples, as indicated by the SGB sample monitor, are diverted to the nuclear vents and drains system. Reactor plant and process gaseous samples are purged to the sweep gas system (Section 11.3), prior to sampling to insure

representative samples. All samples may be purged to the sample sink for flushing before sample acquisition. The sample sink discharges to the nuclear vents and drains system.

Local instrumentation is provided to permit manual control of sampling operations and to ensure that samples are at suitable temperatures and pressures prior to sample acquisition or analysis. Each purge line header contains a flow indicator/controller to regulate the purge flow rate.

Typical analyses performed on grab samples are: boron concentration, fission product, gross and isotopic radioactivity

level, dissolved gas content, and corrosion product concentration. Analytical results are used in regulating boron concentration, evaluating fuel element integrity, evaluating mixed bed demineralizer performance, determining releases to the environment, and in regulating concentrations of corrosion-controlling chemicals in the unit fluid systems.

Table 9.3-5 lists the sample points served by the RPPS system, as well as examples of some points for which local sample

acquisition capability is provided. 9.3.2.1.3 Safety Evaluation

Except for the containment isolation piping and valves, the RPPS system is not required to function during an emergency nor is it required to prevent an emergency condition. All remotely-operated valves will fail in the safe position. The RPPS system is designed to limit potential reactor coolant losses. The sample tubing containing reactor coolant is 3/8-inch in diameter, thereby minimizing the magnitude of any postulated

leak. BVPS-2 UFSAR Rev. 12 9.3-15 Remote-manual sample isolation valves are provided as close to the sampling source as possible and can be used to isolate a potential leak. These sample isolation valves will fail closed and meet Seismic Category I design requirements.

The design of the RPPS system ensures that by sufficient purging of the grab samples, a representative sample is available at the sample panel. Sample point locations are specified to ensure that samples will reflect the bulk property of the system fluid. Reactor coolant samples are taken during normal reactor operation from sample taps inserted into the coolant main stream. Because the coolant is well mixed during operation and loop isolation valves are normally open, representative samples of reactor coolant may be obtained from any coolant loop. A reactor coolant sample may be taken during cooldown and during cold shutdown by using sampling points in the RHR system (Section 5.4.7). Radiological protection of personnel from the RPPS system lines is provided by the use of shielding. Potentially radioactive sample lines are run to the sample station in the auxiliary building through pipe chases. This pipe chase area is normally

not subject to personnel entry. Personnel access areas in the proximity of the pipe chase area are protected by a minimum of 2-feet thick concrete shielding.

In the sample room, all sample lines are run to the back of the sample panel after passing through 2-feet thick concrete shielding. Manual sampling system valves, located behind the shield, are operated by means of reach rods. The sample panel also provides a certain degree of personnel shielding for the personnel drawing samples, or working in the area, by minimizing direct exposure to potentially radioactive sample lines.

The sample panel and sink are fitted with enclosed, ventilated hoods. The SLCRS (Section 6.5.3) provides a sweep gas effect for the sample area.

All high temperature samples are cooled sufficiently (to approximately 115 F) to guard against personnel handling samples that are at excessive temperatures. The high pressure in some of the sample lines is reduced to 35 psig for safe acquisition of samples. 9.3.2.1.4 Inspection and Testing Requirements

The RPPS system is used continuously (SGB only) and intermittently during normal power operation, thus ensuring the

availability and performance of the system. System pressure testing will be performed in accordance with ASME Section III for Category I piping and ANSI B31.1 for NNS piping. Preliminary tests are performed as described in Section 14.2.12.

BVPS-2 UFSAR Rev. 13 9.3-16 9.3.2.1.5 Instrumentation Requirements Control switches with indicating lights are provided in the main control room for the following containment isolation valves: primary coolant hot leg sample line, pressurizer relief tank gas sample isolation valves, and RHR sample isolation valves. These valves close automatically whenever a CIA signal is initiated, or manually by means of their control switches. These valves can be opened by means of their control switches, provided a CIA signal is not present. After initiation of a CIA signal, the valves must be reset from the main control room before they can be manually opened by means of their control switches (refer to Section 9.3.2.3.5 for additional control functions).

Control switches with indicating lights, are provided in the main control room for the primary coolant cold leg sample isolation valves, pressurizer vapor sample isolation valves, and safety injection accumulator sample isolation valves. These valves are opened by means of their control switches, provided

no CIA signal is present. These valves are closed automatically when a CIA signal exists or manually by means of their control switches.

Multi-position selector switches with indicating lights are provided at the RPPS panel for the following sample valves:

1. Primary sampling system panel for the primary coolant hot and cold legs sample valves, 2. Pressurizer liquid space sample valve,

3. Pressurizer vapor space sample valve, 4. Residual heat removal inlet and outlet sample valves,

5. Safety injection accumulator sample valves,

6. Charging pump discharge sample valves, 7. Letdown flow sample valve,

8. Volume control tank liquid sample valve,

9. Reactor coolant filter sample valve, 10. Fuel pool ion exchanger effluent sample valve,

11. Fuel pool ion exchanger influent sample valve,

12. Pressurizer relief tank gas space sample valve, 13. Volume control tank gas sample valve,

BVPS-2 UFSAR Rev. 0 9.3-16a 14. Waste gas surge tank sample valve, 15. Gaseous waste storage tank sample valves,

16. Primary drains transfer tank (inside containment) gas space sample valve,

17. Primary drains transfer tank (outside containment) gas space sample valve, and

BVPS-2 UFSAR Rev. 13 9.3-17 18. Nitrogen purge isolation valves for the PRT gas sample line and primary drains transfer tank (inside containment) gas sample line. These sample valves are operated manually and are not energized

until the respective selector switch handle is pulled out. A common control switch with individual indicating lights is provided in the main control room for the steam generators sample isolation valves. These valves can be opened by means of the control switch provided none of the auxiliary feedwater pumps is running. The valves will close on any auxiliary feedwater pump start or steam generator sample radiation high. The valves can be opened by means of the control switch to take a sample even if high radiation is present as long as no auxiliary feedwater pump is running. Releasing of the control switch from the open position in this case automatically closes the valve. The valve can be closed at any time by placing its control switch in close. A selector switch with indicating

lights is provided in the main control room for each steam generator's pair of steam generator steam sample valve and SGB sample valve. Selection of one sample valve for testing automatically closes the other sample valves. Both sample valves can be closed manually by placing the selector switch in close or automatically by any auxiliary feedwater pump start or

steam generator sample temperature high. The sample temperature high signal is locked in and must be reset, when the temperature returns to normal, by placing the valve selector switch in the

close position. Annunciation is provided in the main control room for primary plant sample panel trouble. This alarm is also monitored by the BVPS-2 computer system.

Annunciation is provided on the primary sampling system panel for cation conductivity-steam generator A, B, or C high, pH-steam generator A, B, or C high, pH steam generator A, B, or C low sodium-steam generator A, B, or C high, and refrigeration system trouble.

A multi-point recorder/datalogger is provided at the RPPS sample panel for steam generators A, B, and C cation conductivity, steam generators A, B, and C pH, steam generators A, B, and C sodium content, and steam generators A, B, and C total conductivity. The recorder/datalogger also transmits all sample data received to a computer in the chemistry lab dedicated to

the collection of water chemistry data. 9.3.2.2 Turbine Plant Sampling System

The turbine plant sampling system routes secondary plant steam and liquid samples at varying pressures and temperatures to the turbine plant sample panel. Samples are conditioned to modify pressure, temperature, and flow before analysis. Selected in-line sample analyses are provided with local panel indication, in addition to BVPS-2 UFSAR Rev. 15 9.3-18 grab sample capability for laboratory analysis, which is provided for all samples. The condenser hotwell sample system is a subsystem of the turbine plant sampling system. This system draws liquid samples from the main condenser hotwells and provides on-line analysis as well as grab sample capability for laboratory analysis.

9.3.2.2.1 Design Bases

The turbine plant sample system is designed in accordance with the following criteria:

1. To provide a means of acquiring representative selected turbine plant samples for on-line and

laboratory grab sample analysis.

2. To provide accurate sample pressure flow and temperature conditioning to satisfy the requirements for in-line analyzers, and to ensure personnel safety during grab sample acquisition.

3. To provide sampling capability for the following turbine plant functions: main steam from the individual main steam lines downstream of the main steam isolation valves, steam generator feed pump suction and discharge, condensate pump discharge, heater drain pump discharge, and condenser hotwell.

4. The condenser hotwell sampling system is designed to continuously monitor condensate conductivity levels at various points in the main condenser hotwells. The system is designed so as to minimize the delay time associated with detection of high conductivity in hotwell condensate. The system is also designed to monitor a selected sample stream for sodium.

5. Sample system piping is designed in accordance with ANSI B31.1, dated 1967, including all addenda through June 30, 1972, and is designated NNS class, and QA

Category II.

6. In addition, there are three (3) capped sample line connections from the SGBD demineralizers for a future ion chromatograph, and high pressure sample taps for use with the corrosion products monitor.

BVPS-2 UFSAR Rev. 10 9.3-18a 9.3.2.2.2 System Description Process liquid and steam samples from individual main steam lines downstream of the main steam isolation valves, steam generator feed- water pump suction and discharge, heater drain pump discharge and condensate pump discharge samples are conveyed to the turbine plant sample panel. Samples are routed

via carbon steel piping and stainless steel tubing. Line sizes are designed to meet analyzer and grab sample flow requirements.

The conditioning panel contains the sample coolers, flow regulators, pressure regulating valves, isothermal bath, and local pressure, flow and temperature indicators.

Samples are passed through primary coolers, when required, to reduce sample temperatures to approximately 110°F. Cooling

water to the primary coolers is supplied from the TPCCW system (Section 9.2.7). All samples are th en passed through a chilled water isothermal bath in which the sample temperature is lowered to approximately 77°F. Cooling water for the bath is supplied by the chilled water system (Section 9.2.2.2). A temperature controller controls the bath temperature by varying the flow of

chilled water through the bath cooling coils. Each sample point is provided with a grab sample valve, located in the conditioning panel, to provide adequate sample flushing prior to BVPS-2 UFSAR Rev. 15 9.3-19 and for grab sample acquisition or admittance to in-line analysis equipment. The conditioning panel is equipped with a common blowdown header

located upstream of the main sample isolation valve for each sample point except the heater drain pump discharge. The blowdown header is provided to flush the incoming sample lines

during BVPS-2 start-up. The blowdown header, pressure relief valve, and the sample sink

all discharge to a common waste header, which in turn discharges to the turbine building floor drainage system (Section 9.3.3).

Conditioned samples are routed to the sample analyzer panel that is adjacent to the following in-line sample analyzers:

1. Main steam samples are continuously monitored for conductivity.

2. The feedwater pump discharge sample is continuously monitored for conductivity, pH, hydrazine, sodium, and

dissolved oxygen.

3. The feedwater pump suction sample is continuously monitored for conductivity.

4. The condensate pump discharge is continuously monitored for dissolved oxygen, conductivity, and sodium.

5. The condenser hotwell is continuously monitored for conductivity and has the capability to monitor a selected stream for sodium.

6. The heater drain pump discharge sample is continuously monitored for conductivity and sodium.

After passage through analytical equipment, hydrazine-, oxygen-, pH- and sodium-analyzed samples are routed to the turbine building floor drainage system (Section 9.3.3). All other samples are returned to the auxiliary steam system condensate receiver (Section 10.4.10).

The condenser hotwell sampling system, a separate subsystem of the turbine plant sampling system, draws and analyzes condensate samples from various points in the condenser hotwells.

Condenser hotwell

BVPS-2 UFSAR Rev. 4 9.3-20 samples are analyzed for conductivity content. High conductivity in hotwell condensate indicates condenser tube, circulating water, in leakage.

The hotwell sampling system utilizes six metering type sample pumps which continuously draw condensate samples from the condensate hotwells and discharge to a common hotwell sample

panel. The hotwell sample panel is provided with an individual in-line conductivity measuring loop for each of the six sample inputs. Conductivity levels are remotely indicated and alarmed at the hotwell sample monitoring panel. Hotwell sample lines upstream of the sample panel have been sized so as to minimize the delay time associated with high condensate conductivity

detection. The hotwell sample panel also maintains the capability to take grab samples for laboratory analysis.

Upon actuation of a high conductivity alarm, the hotwell sampling conductivity indication will indicate the origin of the high, conductivity problem, a specified hotwell sample point, which can be related to a specific condenser tube bundle area. This specific leak detection ability will enable operators to locate the affected leakage area and isolate that area depending on the severity of in-leakage.

Condensate discharged from the hotwell sample panel is routed back to the main condenser through a strainer, which is designed to trap any resin that may be released from a conductivity

column at the hotwell sample panel. 9.3.2.2.3 Safety Evaluation

The turbine plant sampling system performs no safety-related function. The failure of this equipment will not affect the

safety functions of other equipment. The activity levels of the turbine plant systems being sampled

are monitored by radiation monitors (Section 11.5) at various points. These points include the SGB lines, air ejector after condenser vent lines, degasifier condensate pump discharge, and

evaporator reboiler condensate pump discharge. 9.3.2.2.4 Inspection and Testing Requirements

The turbine plant sampling system is used continuously during normal operation, thus ensuring the availability and performance

of the system. System pressure testing will be performed in accordance with ANSI B31.1. Preliminary tests are performed as described in Section 14.2.12.

9.3.2.2.5 Instrumentation Requirements

A common control switch with indicating lights is provided at the hotwell sample panel for the condenser hotwell sample pumps. These

BVPS-2 UFSAR Rev. 4 9.3-20a pumps are provided to draw continuous condensate samples from the condenser hotwell, discharging these samples through inline conductivity measuring equipment and then back to the condenser hotwell. A chilled water bath level control valve is provided to admit TPCCW to the chilled water bath when the level drops to the low

level set-point, and to close when the proper level is reached. Sample pressure reducing valves and flow regulating valves

modulate to maintain a set sample pressure and flow prior to entry to the chilled water bath and analytical equipment.

A chilled water bath temperature control valve modulates to admit chilled water to the bath cooling coils to maintain a set bath temperature.

Each sample cooler effluent, except the heater drain pump discharge, has a normally open temperature solenoid valve that

closes on high temperature. A sodium analyzer is provided on the turbine plant panel for the

condensate pump discharge, steam generator feedwater pump discharge, and heater drain pump discharge.

BVPS-2 UFSAR Rev. 4 9.3-21 An oxygen indicator is provided on the turbine plant sample panel for the condensate pump discharge and steam generator feedwater pump discharge.

Conductivity analyzer/indicators are provided on the turbine plant sample panel for the condensate pump discharge, steam generator feedwater pump discharge, steam generator feedwater

pump suction, three (3) main steam lines, and the heater drain pump discharge.

A hydrazine analyzer is provided on the turbine plant sample panel for the steam generator feedwater pump discharge.

A pH analyzer/indicator is provided on the turbine plant sample panel for the steam generator feedwater pump discharge.

A multi-pen recorder is provided on the turbine plant sample panel with the following inputs:

1. Conductivity inputs: main steam line loop I sample to cation exchanger, main steam line loop I sample from cation

exchanger, main steam line loop II sample to cation exchanger, main steam line loop II sample from cation exchanger, main steam line loop III sample to cation exchanger, main steam line loop III sample from cation exchanger, condensate pump discharge sample to cation exchanger, condensate pump discharge sample from cation exchanger, steam generator feedwater pump discharge sample to cation exchanger, steam generator feedwater pump discharge from cation exchanger, heater drain pump discharge sample to cation exchanger, heater drain pump discharge sample from cation exchanger, and steam generator feedwater pump suction.

2. pH inputs: steam generator feedwater pump discharge sample.

3. Sodium inputs: condensate pump discharge sample, steam generator feedwater pump discharge sample, heater drain pump discharge sample.

4. Oxygen inputs: steam generator feedwater pump discharge sample, condensate pump discharge sample.

5. Hydrazine inputs: steam generator feedwater pump discharge sample.

Annunciation is provided in the main control room for turbine plant sample panel trouble, which consists of main steam line conductivity high, steam generator feedwater pump discharge conductivity high, steam generator feedwater pump discharge hydrazine low, steam generator feedwater pump discharge pH high-low, steam generator feedwater pump discharge sodium high, steam generator feedwater pump discharge oxygen high, condensate pump discharge oxygen high, condensate pump discharge sodium high, condensate pump discharge conductivity high, condenser

BVPS-2 UFSAR Rev. 13 9.3-22 hotwell conductivity high, condenser hotwell sodium high, heater drain pump discharge conductivity high, heater drain pump discharge sodium high, and chilled water bath temperatures high-low. These conditions are also monitored by the BVPS-2 computer

system. Annunciation is provided at the turbine plant sample panel main

steam high conductivity, hotwell/condensate pump discharge high sodium, steam generator feedwater pump discharge/condensate pump discharge high/low pH, steam generator feedwater pump discharge hydrazine high/low, condensate pump discharge high oxygen, pumps/hotwell high conductivity, and isobath temperature high/low.

9.3.2.3 Deleted

9.3.3 Equipment

and Floor Drainage System

9.3.3.1 Design Bases The design bases of the reactor plant vent and drain system are:

1. Sumps and sump pumps are sized to handle the expected leakage in the areas served by each sump. Each sump

is provided with two pumps for redundancy and to handle surges in flow, except the in-core instrument tunnel sump, gaseous waste storage vault sump, and

fuel pool telltale drains catch tank, which all have one pump per sump due to small anticipated leak collection requirements.

2. The majority of the vent and drain system is nonsafety-related and designated NNS. However, there are two portions of the vent and drain system that are considered safety-related. First, containment penetration piping and valves in aerated, gaseous, and hydrogenated portions of the vent and drain system are designated Safety Class 2, Seismic Category I, and designed in accordance with Regulatory Guide 1.29 and QA Category I (Section 6.2.4). Secondly, the portion of the hydrogenated drain system where the RCS spray line scoop drain, RCS excess letdown, and RCS loops drain into a common header is designated Safety Class 1, Seismic Category I, and designed in accordance with Regulatory Guide 1.29 and QA Category I.

3. Each sump has a stainless steel liner to prevent possible diffusion of radioactive fluids through the

concrete and to aid in surface decontamination.

4. Sweep gas ventilation is provided on the sumps in the auxiliary building and waste handling area to prevent radioactive gases from venting to the building atmosphere.

BVPS-2 UFSAR Rev. 13 9.3-23 5. Valve stem leakoff piping is primarily of welded design to limit leakage of hydrogen and radioactive gases to the building atmosphere, except where flanges

are considered necessary for isolation of the system.

6. All vents, aerated and gaseous, are collected and piped via headers to the gaseous waste disposal (GWD) system for discharge to avoid the spread of contaminated gases throughout the building.

9.3.3.2 System Description

The reactor plant vent and drain system collects potentially radioactive fluids and gases from various systems and discharges either to the GWD system (Section 11.3), the liquid waste disposal (LWD) system (Section 11.2), or the boron recovery system (BRS) (Section 9.3.4.6).

The drains are separated into those which contain air (aerated drains) and those which contain hydrogenated reactor coolant fluid. Aerated drains are sent to the LWD system. Hydrogenated

drains are sent to the BRS for processing and recovery. The vents are separated into those which contain air (aerated vents) and those in which hydrogen and radioactive gases are predominant (gaseous vents). Both aerated and gaseous vents are directed separately to the BVPS-1 process vent via the BVPS-1

and BVPS-2 GWD systems. The vent and drain system component design parameters are given

in Table 9.3-6. Sumps are located in the reactor containment, incore instrumentation tunnel, safeguards areas, tunnel between the reactor containment and auxiliary building, auxiliary building, fuel pool tell-tale drains catch tank, decontamination building, fuel building, condensate polishing building, gaseous waste tank area, and waste handling area. The collected aerated drainage is transferred by sump pumps to the liquid waste drain tanks in

the LWD system (Section 11.2). In the event of high radioactivity, turbine building drains are also transferred to the steam generator blowdown hold tanks instead of discharging via the storm drain system to the Ohio River. The containment sump collects open drains from the containment and post-accident sample returns from the post-accident sampling system (PASS). The water accumulation in the containment sump is monitored to determine unidentified leakage from the reactor coolant pressure boundary described in Section 5.2.5. The

auxiliary building sumps collect floor drains, drains from equipment, ion exchanger drains, and filter drains. The other sumps collect floor drains in their respective areas.

BVPS-2 UFSAR Rev. 13 9.3-24 The sumps located in the reactor containment, auxiliary building, safeguards areas, and tunnel between the reactor containment and auxiliary building may be sampled and analyzed during normal plant operation and after an accident using the

PASS. The respective sump pumps (with the exception of the containment sump) have isolation valves that switch the normal pump discharge to a bypass which discharges to the PASS panel.

The containment sump uses a separate PASS sump pump to transfer liquid to the PASS panel.

Drainage from systems containing reactor coolant or from systems into which reactor coolant might leak (hydrogenated drains) are collected in the PDTT. The PDTT, 2DGS-TK21, located in the containment, receives drains directly from the reactor coolant pump (RCP) numbers two and three seal leakoffs, and also receives drains via the primary drains cooler from the reactor flange leak detection line, the safety injection accumulators, and valve stem leakoffs within the containment. The PRT (Section 5.4) collects reactor coolant from the major relief

valve discharges in the RCS, RHR system, the chemical and volume control system (CVCS) (Section 9.3.4), and PASS sample returns. The primary drains transfer pumps, 2DGS-P21A & B, pump the PDTT

contents to the degasifiers of the BRS. The primary drains transfer pumps are also used to manually drain the PRT.

The reactor coolant loops can be drained directly or via the excess letdown heat exchanger (Section 9.3.4.2) and primary drains cooler to the PDTT, 2DGS-TK21, inside the containment. All or part of the RCS, with the exception of the reactor vessel, can also be drained to this PDTT.

The PDTT, 2DGS-TK22, located in the auxiliary building, receives drains and relief valve discharge from the VCT, valve stem leakoffs, the sample system liquid header, non-accident sample returns from the PASS, degasifier vent chiller drains, gaseous waste steam trap drains, and charging pump drains. The contents

of the PDTT are pumped to the BRS degasifiers.

Two recirculation drain pumps are provided in the safeguards area. They are used in the cans of the recirculation spray

pumps (deep-well, vertical pumps). Section 6.2.2.2.2 describes the recirculation spray pumps. The recirculation drain pumps can either discharge to a catch basin in the yard or to the sump

in the safeguards building. Radioactive gases and hydrogen that are vented during normal

operation from the PRT, the VCT, the PDTT, and the sampling system gas sample purge line go directly to the gaseous waste disposal system (GWD).

The safety-related sections of piping for the vent and drain system are designed in accordance with ASME Section III. Austenitic stainless steel piping or tubing is used for the transfer of liquids and radioactive gaseous waste, while carbon steel piping is used for non-radioactive gases. Containment

isolation valves are provided in all vent and drain lines from the containment. For details, refer to Section 6.2.4.

BVPS-2 UFSAR Rev. 13 9.3-25 9.3.3.3 Safety Evaluation The vent and drain system is sized to handle the maximum amount of liquids and gases expected during normal station operation.

All sumps, except incore instrumentation, gaseous waste storage vault sump, and fuel pool telltale drains catch tank are

provided with a double pump arrangement. Operation of the pumps is alternated in service. One pump is on automatic service while the other is on standby. Each pump is full-sized and independently controlled. When the water level in the sump reaches a specified height, one of the pumps will start. If the water level reaches a specified higher level, the second pump starts. The pump(s) will stop automatically upon emptying the sump. Each sump is also provided with a high level alarm. A CIA signal closes the associated containment isolation valves, which also have limit switches that stop the reactor containment sump pumps.

The primary drains transfer pumps are full-sized and independently controlled. Two pumps are provided for each tank. One pump is on automatic service and the other is on standby. When the water level in the tank reaches a specified high level, one of the pumps is started. If the water level reaches a specified higher level, the other pump also starts. The pumps(s) stops automatically upon emptying the tank. Each tank is also provided with a high level alarm. A CIA signal closes the associated containment isolation valves, which have limit switches that stop the primary drains transfer pumps 2DGS-P21A & B. During normal unit operation, proper operation of the vent and drain system precludes radiological hazard to the public or operating personnel from the drainage or venting of nuclear plant equipment or system components. All drainage liquid which is potentially radioactive is collected, pumped to the BRS degasifiers, and either returned to the RCS or processed for

disposal. All vent gas goes to the GWD system. All liquid drains originating inside containment are collected in either the PRT, the PDTT, 2DGS-TK21, or the containment sump. this arrangement initially retains in the containment all leakage originating from components within the containment, thereby segregating any radiation hazard to operating personnel or to the public that could result from the leakage. Subsequent to collection, the leakage is either returned via the boron

recovery degasifiers to the RCS or the LWD system. Gaseous buildup in the PRT will be vented to the GWD system.

Sweep gas ventilation affords a positive means of preventing gaseous outleakage from tanks or confined areas. Application of exhaust ventilation to a tank or confined area draws out any gases contained therein and replaces them with outside air drawn in through a vent. This clean air sweeps through the ventilated area and out again to the GWD system. The sweep gas prevents

any gases entrained in the liquid from diffusing into the

BVPS-2 UFSAR Rev. 13 9.3-26 auxiliary building atmosphere. Leakage from certain components in the auxiliary building is treated in this same fashion. Leakage or drainage from other components in the auxiliary building which are known to pose a radiation hazard is directed

to the PDTT, 2DGS-TK22, and is subsequently returned to the RCS via the BRS. If unit tankage that is normally vented to the atmosphere should contain potentially radioactive water, it is subject to sweep gas ventilation, thus preventing any build up of hydrogen in the tanks and escape of entrained gases to the atmosphere. The sweep gas is routed to the GWD system.

Other areas within BVPS-2 in which radioactive leakage or drainage may be generated are designed with a drainage system

with collection sumps. Any drainage collected is pumped to the LWD system.

Because leakage and drainage to the auxiliary building and waste area sumps from the RCA and its subsystems have the potential of carrying entrained radioactive gases and hydrogen, these sumps

are covered and ventilated with sweep gas which exhausts to the GWD system. In this manner, any entrained gases, which may be released from the liquid in the sumps, will enter the GWD system and not the building atmosphere. Other area sumps do not have this provision since drainage to these sumps originates from systems which are not anticipated to contain entrained

radioactive gases or hydrogen. 9.3.3.4 Inspection and Testing

Preliminary tests are performed as described in Section 14.2.12. ASME Section XI in-service inspection is performed, as

necessary, in accordance with Chapter 16. Testing of this system is in accordance with the BVPS-2 Technical Specifications. Continued routine observations and preventive maintenance are performed in accordance with normal station maintenance procedures.

9.3.3.5 Instrumentation Requirements

Selector switches with indicating lights are provided in the main control room for the incore instrument sump pump. This sump pump is used to pump out the incore sump into the reactor

containment sump. Operation of this pump may be manual or automatic when the incore instrument sump level is high.

Selector switches with indicating lights are provided in the main control room for the reactor containment sump pumps. These pumps discharge to the liquid waste drain tanks. These pumps may be operated manually or automatically. Pumps alternate in service as a normal operation. The pumps are started and stopped automatically upon high and low levels, respectively, and a high-high containment sump level will cause both pumps to operate at the same time. BVPS-2 UFSAR Rev. 13 9.3-27 A flow recorder is provided in the main control room for containment sump pump flow. Level indication is provided in the main control room for incore

instrument sump level and reactor containment sump level. A level recorder is provided in the main control room for

reactor containment sump level. A selector switch with indicating lights is provided in the main

control room for the reactor containment sump pump discharge (inside containment) isolation valve. A control switch with indicating lights is provided in the main control room for the reactor containment sump pump discharge (outside containment) isolation valve. These valves are piped in series at the containment penetration for the combined discharge line of the

pumps and are interlocked with the containment isolation system. These containment sump pump discharge isolation valves automatically close when a CIA signal exists. If either discharge isolation valve is closed, in conjunction with either containment sump pump running for a predetermined time, it will

automatically stop the respective containment sump pump. Control switches with indicating lights are provided in the main

control room for the primary drains transfer pumps (inside containment). These pumps discharge the tank contents to the degasifier system supply header. The pumps may be started manually or automatically. The lead pump starts on a high tank level, while the backup pump starts on a high-high tank level.

Control switches with indicating lights are provided in the main control room for the primary drains transfer pumps (outside containment). These pumps may be started manually or automatically. The lead pump starts on a high tank level while the backup starts on a high-high tank level.

A selector switch with indicating lights is provided in the main control room for the primary drains transfer discharge header (inside containment) isolation valve. A control switch with

indicating lights is provided in the main control room for the primary drains transfer discharge header (outside containment) isolation valve. These valves are piped in series to isolate the system during a CIA, and will automatically close when a CIA signal exists. Either discharge header isolation valve being closed, in conjunction with either primary drains transfer pump running for a predetermined time, will automatically stop the respective primary drains transfer pump.

Selector switches with indicating lights are provided in the main control room for each isolation valve on the vent headers from the PDTTs (inside and outside containment). The valves are closed automatically on a high-high level in its respective PDTT. BVPS-2 UFSAR Rev. 13 9.3-28 Hand/auto control stations are provided in the main control room for the PDTTs (inside and outside containment) nitrogen pressure control valves. These valves ensure that a minimum pressure is maintained within the respective transfer tank to prevent in-leakage of oxygen into the primary drains transfer system provided its respective PDTT vent header isolation valve is closed. The nitrogen pressure control valves will close when

its respective PDTT vent header isolation valve is opened. Control switches with indicating lights are provided in the main control room for the primary drains cooler cooling water supply and return valves. The cooling water valves will open provided there is no CIA signal and will close when the CIA signal is

present or the CCW surge tank level is low-low. Selector switches with indicating lights are provided locally

for the north and south safeguards area sump pumps, tunnel sump pumps, fuel building sump pumps, auxiliary building sump pumps, decontamination building sump pumps, and the waste area sump pumps. All these pumps may be started manually or automatically. A level recorder is provided in the main control room for the PDTT level (inside containment).

Level indication is provided in the main control room for the PDTTs (inside and outside containment) levels. Level indicators in the main control room also monitor the safeguards area sump levels, rod control area pipe tunnel sump level, and the auxiliary building sumps levels.

Pressure indication is provided in the main control room for the primary drains transfer pumps (inside and outside containment) discharge pressure. Pressure indication is also provided in the main control room for the PDTT (inside and outside containment) transfer tank pressure.

Temperature indication is provided in the main control room for the PDTT (inside containment) inlet temperature. Annunciator displays, with associated BVPS-2 computer inputs, are provided in the main control room for incore instrument sump or containment sump level high, and the reactor containment sump pump isolation valve not reset. Annunciation is also provided for the unidentified leakage monitor system, which consists of unidentified leakage system trouble, unidentified leakage flow greater than 60 gal/hr, and unidentified leakage controller failure. Alarms are provided for the primary drains transfer pump (inside and outside containment) or PDTT trouble, which consists of transfer pumps motor thermal overload, transfer

tanks level low-low and high-high, transfer tanks pressure low and high, and transfer pumps (inside containment) discharge valves trouble. Annunciators with computer inputs are also provided for the north/south safeguards areas sump level high, rod control area pipe tunnel sump level high, fuel building sump level high, auxiliary building sump level high, decontamination

building sump level high, condensate polishing building sump

BVPS-2 UFSAR Rev. 13 9.3-29 level high, waste handling area sump level high, fuel pool telltale drains catch tank level high, waste instrument sump level high, containment sump level, unidentified leakage pumps after start, and the unidentified leakage monitor system cycle time (Section 5.2.5). Computer inputs are also provided for the PDTT (inside and outside containment) level and pressure, and for the PDTT (inside containment) inlet temperature.

9.3.4 Chemical

and Volume Control System

The CVCS, shown on Figure 9.3-21 , provides the following services to the RCS:

1. Maintenance of programmed water level in the pressurizer (maintains required water inventory in the

RCS), 2. Maintenance of seal water injection flow to the RCPs,

3. Control of reactor coolant water chemistry conditions (for corrosion control), activity level, soluble

chemical neutron absorber concentration (for

reactivity control), and makeup,

4. Emergency core cooling. Part of the system is shared with the emergency core cooling system (ECCS),

5. Provide means for filling and draining the RCS, and

6. Cold shutdown. Part of the CVCS functions in conjunction with the other systems of the cold shutdown design (Sections 5.4.7 and 6.3).

9.3.4.1 Design Bases

System design parameters are given in Table 9.3-7, with qualitative descriptions given as follows.

9.3.4.1.1 Reactivity Control

The CVCS regulates the concentration of chemical neutron absorber (boron) in the reactor coolant to control reactivity changes resulting from the change in reactor coolant temperature between cold shutdown and hot full power operation, burnup of fuel and burnable poisons, buildup of fission products in the fuel, and xenon transients.

1. The CVCS is capable of borating the RCS through one of several flow paths and from either one of two boric acid sources.

BVPS-2 UFSAR Rev. 13 9.3-30 2. The amount of boric acid stored in the CVCS always exceeds that amount required to borate the RCS to cold shutdown concentration, assuming that the rod cluster control assembly with the highest reactivity worth is stuck in its fully withdrawn position. This amount of boric acid also exceeds the amount required to bring the reactor to hot standby and to compensate for

subsequent xenon decay.

3. The CVCS is capable of borating the RCS to cold shutdown concentration using only safety grade equipment to provide a continuous flow of 4 weight percent boric acid solution.

9.3.4.1.2 Regulation of Reactor Coolant Inventory

The CVCS maintains the coolant inventory in the RCS within the allowable pressurizer level range for all normal modes of operation, including startup from cold shutdown, full power operation, and plant cooldown. This system also has sufficient makeup capacity to maintain the minimum required inventory in the event of minor RCS leaks. (Chapter 16 discusses maximum

allowable RCS leakage.) 9.3.4.1.3 Reactor Coolant Purification

The CVCS is capable of removing fission, activation products, and corrosion products, in ionic form or as particulates, from the RCS in order to control radiation levels to allow access to process lines carrying reactor coolant during operation and to minimize radioactive releases due to leaks.

9.3.4.1.4 Chemical Additions to the Reactor Coolant System

The CVCS provides a means for adding chemicals to the RCS, which controls the pH of the reactor coolant during initial start-up and subsequent operation, scavenges oxygen from the reactor

coolant during start-up, and counteracts the production of oxygen in the reactor coolant due to the radiolysis of water in the core region. Hydrogen peroxide may be added during plant

shutdown as part of RCS activity reduction efforts. The CVCS is capable of maintaining the oxygen content and pH of

the reactor coolant within limits specified in Table 5.2-5. 9.3.4.1.5 Seal Water Injection

The CVCS is able to continuously supply filtered borated water to each RCP seal, as required by the RCP design specified in Table 9.3-7. BVPS-2 UFSAR Rev. 13 9.3-31 9.3.4.1.6 Emergency Core Cooling The centrifugal charging pumps in the CVCS also serve as the high head safety injection (HHSI) pumps in the ECCS. Other than

the centrifugal charging pumps and associated piping and valves, the CVCS is not required to function during a loss-of-coolant accident (LOCA). During a LOCA, the CVCS is isolated except for the centrifugal charging pumps and the piping in the safety injection path.

Section 6.3 provides further information on the function of the charging pumps during a LOCA.

9.3.4.1.7 Safe Shutdown The CVCS provides a safety grade means of boration of the RCS to

achieve the required cold shutdown concentration. The boric acid tanks, boric acid pumps, charging pumps, portions of the HHSI headers, and throttling valves are provided for boration (Section 6.3). The CVCS also provides for safety grade means of RCS inventory control, utilizing the aforementioned components in conjunction with the reactor vessel head letdown system described in Section 5.4.15. For a complete description of safety grade cold shutdown capability, see Appendix 5A. A nonsafety grade means of storing RCS letdown at the BVPS-1

reactor coolant recovery tanks during abnormal conditions, when the normal letdown path and/or the boron recovery system are

inoperable, is also provided (Section 9.3.4.2.1).

9.3.4.2 System Description

The CVCS is shown on Figure 9.3-21, with system design parameters listed in Table 9.3-7. The codes and classifications to which the individual components of the CVCS are designed are listed in Section 3.2. The CVCS consists of three subsystems: the charging, letdown, and seal water system; the reactor coolant purification and chemistry control system; and the

reactor makeup control system. 9.3.4.2.1 Charging, Letdown, and Seal Water System

The charging and letdown functions of the CVCS maintain a programmed water level in the RCS pressurizer, thus maintaining proper reactor coolant inventory during all phases of plant operation. This is achieved by means of a continuous feed and bleed process during which the feed rate is automatically

controlled based on pressurizer water level. The bleed rate can be chosen to suit various plant operational requirements by selecting the proper combination of letdown orifices in the

letdown flow path. Additionally, a part of the charging system is used in the cold shutdown system design (Section 5.4.7).

BVPS-2 UFSAR Rev. 13 9.3-32 Reactor coolant is discharged to the CVCS from a reactor coolant loop cold leg, then flows through the shell side of the regenerative heat exchanger, where its temperature is reduced by heat transfer to the charging flow passing through the tubes. The coolant then experiences a large pressure reduction as it passes through the letdown orifice(s) and flows through the tube side of the letdown heat exchanger where it is further cooled by CCW. Downstream of the letdown heat exchanger, a second pressure reduction occurs. This pressure reduction is performed by the low pressure letdown pressure control valve, which

maintains upstream pressure and thus prevents flashing downstream of the letdown orifices.

Using either the demineralizer flow path or the direct bypass to the VCT, the coolant flows through the reactor coolant filter, through a sparger for hydrogen dispersing and then into the VCT through a spray nozzle in the top of the tank. Hydrogen, from either the GWD system (Section 11.3) or the generator hydrogen control system (Section 10.2.2.5), may be continuously supplied to the VCT via an in-line bayonet sparger located approximately 80 feet upstream of the VCT in the letdown pipe and also via a connection directly to the top of the VCT. There the hydrogen mixes with fission gasses which are stripped from the reactor coolant into the VCT gas space. The contaminated hydrogen may be vented back to the degasifiers in the BRS, (Section 9.3.4.6), or the hydrogen and fission gasses from the letdown are processed by the BRS. The partial pressure of hydrogen in the VCT determines the concentration of hydrogen dissolved in the

reactor coolant for control of oxygen produced primarily by radiolysis of water in the core.

Three centrifugal charging pumps take suction from the VCT and return the cooled, purified reactor coolant to the RCS. Normal charging flow is handled by one of the three charging pumps. This charging flow splits into two paths. The bulk of the charging flow is pumped back to the RCS through the tube side of the regenerative heat exchanger. The letdown flow in the shell side of the regenerative heat exchanger raises the charging flow to a temperature approaching the reactor coolant temperature. The flow is then injected into a cold leg of the RCS. A second flow path is also provided from the regenerative heat exchanger outlet to the pressurizer spray line. An MOV in the spray line provides auxiliary spray to the vapor space of the pressurizer

during plant cooldown. This provides a means of cooling the pressurizer when the RCPs, which normally provide the driving head for the pressurizer spray, are not operating.

A portion of the charging flow is directed to the RCPs (nominally 8 gpm per pump) through a seal water injection

filter. It is directed down to a point between the pump radial bearing and the thermal barrier heat exchanger cooling coils. Here the flow splits and a portion (nominally 5 gpm per pump) enters the RCS through the labyrinth seals and thermal barrier.

BVPS-2 UFSAR Rev. 13 9.3-33 The remainder of the flow is directed up the pump shaft, cooling the radial bearing, and to the number 1 seal leakoff. The number 1 seal leakoff flow discharges to a common manifold, exits from the containment, and then passes through the seal

water return filter and the seal water heat exchanger to the suction side of the charging pumps. A very small portion of the seal flow leaks through to the number 2 seal. A number 3 seal

provides a final barrier to leakage of reactor coolant to the containment atmosphere. The number 2 leakoff flow is discharged to a standpipe which maintains a back pressure head between the number 2 and number 3 seals. Overflow from the standpipe, as well as the number 3 seal leakoff flow, is discharged to the PDTT (inside containment). When RCS pressure is below 1,000 psig, bypass flow is provided to normal injection flow to cool the RCP.

The excess letdown path is provided as an alternate letdown path from the RCS in the event that the normal letdown path is inoperable. The reactor head vent system also provides this function (Sections 5.4.7 and 5.4.15). Reactor coolant can be discharged from each or all of the RCS cold legs. The coolant then flows through the tube side of the excess letdown heat exchanger where it is cooled by component cooling water. Normally closed MOVs are provided in each excess letdown line from the RCS. Downstream of the heat exchanger a remote-manual control valve controls the letdown flow. The flow normally joins the number 1 seal discharge manifold and passes through the seal water return filter and heat exchanger to the suction side of the charging pumps. The excess letdown flow can also be directed to the PDTT (inside containment) so that it bypasses the number 1 seal return manifold. When the normal letdown line

is not available, the normal purification path is also not in operation. Therefore, this alternate condition would allow continued power operation for a limited period of time, dependent on RCS chemistry and activity. The excess letdown flow path also provides additional letdown capability during the final stages of plant heatup. This path removes some of the

excess reactor coolant due to coolant expansion as a result of the RCS temperature increase.

Surges in RCS inventory due to load changes are accommodated for the most part in the pressurizer. The VCT provides surge capacity for reactor coolant expansion not accommodated by the pressurizer. If the water level in the VCT exceeds the normal operating range, a proportional controller modulates a three-way valve downstream of the reactor coolant filter to divert a portion of the letdown to the BRS. If the high level limit in the VCT is reached, an alarm is actuated in the main control room and the letdown flow is completely diverted to the BRS. As previously discussed, letdown flow can also be diverted to the BVPS-1 coolant recovery tanks for storage in the event that the path to the BRS is inoperable.

BVPS-2 UFSAR Rev. 13 9.3-34 Low level in the VCT initiates makeup from the reactor makeup control system. If the reactor makeup control system does not supply sufficient makeup water to keep the VCT level from falling to a lower level, a low level alarm is actuated. Manual

action may correct the situation or, if the level continues to decrease, an emergency low level signal from either level channel causes the suction of the charging pumps to be

transferred to the refueling water storage tank (RWST). 9.3.4.2.2 Reactor Coolant Purification and Chemistry Control

System Reactor coolant water chemistry specifications are given in

Table 5.2-5. pH Control The pH control chemical employed is lithium hydroxide. This chemical is chosen for its compatibility with the materials and

water chemistry of borated water/stainless steel/zirconium inconel systems. In addition, lithium-7 is produced in the core region due to irradiation of the dissolved boron in the coolant.

The concentration of lithium-7 in the RCS is maintained in the range specified for pH control (Table 5.2-5). If the concentration exceeds this range, as it may during the early stages of a core cycle, the cation bed demineralizer is employed in the letdown line in series operation with a mixed bed

demineralizer. Since the amount of lithium to be removed is small and its buildup can be readily calculated, the flow through the cation bed demineralizer is not required to be full

letdown flow. If the concentration of lithium-7 is below the specified limits, lithium hydroxide can be introduced into the RCS via the charging flow. The solution is prepared in the laboratory and poured into the chemical mixing tank. Reactor makeup water is then used to flush the solution to the suction manifold of the charging pumps.

Oxygen Control During reactor startup from the cold condition, hydrazine is employed as an oxygen scavenging agent. The hydrazine solution is introduced into the RCS in the same manner as described

previously for the pH control agent. Hydrogen is employed to control and scavenge oxygen produced due

to radiolysis of water in the core region. Sufficient partial pressure of hydrogen is maintained in the VCT such that the specified equilibrium concentration of hydrogen is maintained in the reactor coolant. A pressure control valve maintains a minimum pressure in the vapor space of the VCT. This valve can be adjusted to provide the correct equilibrium hydrogen concentration (25 to 50 cc hydrogen at standard temperature and pressure (STP) per kilogram of water). Hydrogen is supplied from the GWD system or from the generator hydrogen control

system. BVPS-2 UFSAR Rev. 13 9.3-35 Reactor Coolant Purification The letdown stream flows through a mixed bed demineralizer. Two mixed bed demineralizers are provided in the letdown line to provide cleanup of the letdown flow. The demineralizers remove ionic corrosion products and certain fission products. One demineralizer is normally in continuous service and can be supplemented intermittently by the cation bed demineralizer, if necessary, for additional purification. The cation resin removes principally cesium and lithium isotopes from the purification flow. The second mixed bed demineralizer serves principally as a standby unit for use if the operating demineralizer becomes exhausted during operation.

A cleanup feature is provided for use during cold shutdown and RHR operation. A remote operated valve admits a bypass flow from the RHR system into the letdown line upstream of the

letdown heat exchanger. The flow passes through the heat exchanger, through a mixed bed demineralizer, and the reactor coolant filter to the VCT. The fluid is then returned to the

RCS via the normal charging route. Filters are provided at various locations to ensure filtration of particulate and resin fines and to protect the seals on the RCPs. Degasification is performed by diverting a selected amount of the letdown flow to the degasifiers in the BRS. The degassed letdown is then returned either to the VCT or diverted to the

SGB hold tanks, or the BVPS-1 coolant recovery tanks, for storage. 9.3.4.2.3 Reactor Makeup Control System The soluble neutron absorber (boric acid) concentration is controlled by the reactor makeup control system. The reactor makeup control system is also used to maintain proper reactor coolant inventory. In addition, redundant emergency boration flow paths are provided from the boric acid tanks or makeup from the RWST directly to the suction of the charging pumps. Borated water from the charging pumps can be provided to the RCS via the normal charging line or via the HHSI headers which serve as the redundant, safety grade method of boration during abnormal conditions. Sections 5.4.7 and 6.3 provide details on the cold

shutdown design. The reactor makeup control system provides a manually pre-selected makeup composition to the charging pump suction header or to the VCT. The makeup control system functions are those of maintaining desired operating fluid inventory in the VCT and

adjusting reactor coolant boron concentration for reactivity control. Primary grade water and boric acid solution (nominal 4 weight percent) are blended together to obtain the reactor coolant boron concentration for use as makeup to maintain VCT inventory, or they can be used separately to change the reactor coolant boron concentration.

BVPS-2 UFSAR Rev. 13 9.3-36 The boric acid is stored in two boric acid tanks. Two boric acid transfer pumps are provided, with one pump normally aligned to provide boric acid to the suction header of the charging pumps and the second pump in reserve. On a demand signal by the reactor makeup controller, the valve opens and delivers a preset mix of primary grade boric acid to the suction header of the charging pumps. The boric acid transfer pump can also be used to recirculate the boric acid tank fluid.

All portions of the CVCS which normally contain concentrated boric acid solution (nominal 4 weight percent) are required to be located within a heated area in order to maintain solution

temperature at 65F. If a portion of the system which normally contains concentrated boric acid solution is not located in a heated area, it is provided with some other means (such as heat

tracing) to maintain the solution temperature at 65F. The primary grade water pumps, taking suction from the primary grade water storage tanks, are employed for various makeup and flushing operations throughout the systems. These tanks and pumps are shared equipment and are located at BVPS-1. One of these pumps runs continuously on recirculation. On demand from the reactor makeup controller, the CVCS control valve opens and provides flow to the suction header of the charging pumps or to

the VCT through the letdown line and spray nozzle. During reactor operation, changes are made in the reactor

coolant boron concentration for the following conditions:

1. Reactor startup - boron concentration must be decreased from shutdown concentration to achieve

criticality, 2. Load following - boron concentration must be either increased or decreased to compensate for the xenon transient following a change in load, 3. Fuel burnup - boron concentration must be decreased to compensate for fuel burnup and the buildup of fission

products in the fuel, or

4. Cold shutdown - boron concentration must be increased to the cold shutdown concentration.

The reactor makeup control system can be set up for the following modes of operation:

1. Automatic Makeup The automatic makeup mode of operation of the reactor makeup control system provides blended boric acid solution to match the boron concentration in the RCS. Automatic makeup compensates for minor leakage of reactor coolant without causing significant changes in

the reactor coolant boron concentration.

BVPS-2 UFSAR Rev. 13 9.3-37 Under normal plant operating conditions, the mode selector switch is set in the automatic makeup position for initiating system start. This switch position establishes a preset control signal to the

total makeup flow controller and establishes positions for the makeup stop valves for automatic makeup. The boric acid flow controller is set to blend the same concentration of borated water as contained in the RCS. A preset low level signal from the VCT level controller causes the automatic makeup control action to start a boric acid transfer pump, open the makeup stop valve to the charging pump suction, and position the boric acid flow control valve and the primary grade water flow control valve. The flow controllers then blend the makeup stream according to the preset concentration. Makeup addition to the charging pump suction header causes the water level in the VCT to rise. At a preset high level point, the makeup is stopped. This operation may be terminated manually at

any time.

If the automatic makeup fails, or is not aligned for operation, and the tank level continues to decrease, a low level alarm is actuated. Manual action may correct the situation or, if the level continues to decrease, an emergency low level signal opens the stop valves in the RWST supply line to the charging pumps, and closes the stop valves in the VCT outlet line.

2. Dilution

The dilute mode of operation permits the addition of a pre-selected quantity of primary grade water at a pre-selected flow rate to the RCS. The operator sets the mode selector switch to dilute, the total makeup flow controller set point to the desired flow rate, the total makeup batch integrator to the desired quantity, and initiates system start. This opens the primary grade water flow control valve and opens the makeup

stop valve to the VCT inlet. Excessive rise of the VCT water level is prevented by automatic actuation (by the tank level controller) of a three-way

diversion valve which routes the reactor coolant letdown flow to the BRS. When the preset quantity of water has been added, the batch integrator causes makeup to stop. Also, the operation may be terminated manually at any time.

BVPS-2 UFSAR Rev. 13 9.3-38 3. Alternate Dilution The alternate dilute mode of operation, as designated on the switch, is similar to the dilute mode except that a portion of the dilution water flows directly to the charging pump suction, while a portion flows into the VCT via the spray nozzle and then flows to the charging pump suction. This decreases the delay in diluting the RCS caused by directing dilution water to the VCT. 4. Boration

The borate mode of operation permits the addition of a pre-selected quantity of concentrate boric acid

solution at a pre-selected flow rate to the RCS. The operator sets the mode selection switch to borate, the concentrated boric acid flow controller set point to the desired flow rate, the concentrated boric acid

batch integrator to the desired quantity, and initiates system start. This opens the makeup stop valve to the charging pumps suction, positions the boric acid flow control valve, and starts the selected boric acid transfer pump, which delivers a nominal 4 weight percent boric acid solution to the charging pumps suction header. The total quantity added in most cases is so small that it has only a minor effect on the VCT level. When the preset quantity of

concentrated boric acid solution is added, the batch integrator causes makeup to stop. Also, the operation may be terminated manually at any time.

5. Manual

The manual mode of operation permits the addition of a pre-selected quantity and blend of boric acid solution

to the RWST, or to some other location via a temporary connection. While in the manual mode of operation, automatic makeup to the RCS is precluded. The discharge flow path must be aligned by opening manual

valves in the desired path. The manual mode can also be used to provide makeup to the VCT when the auto mode is malfunctioning. The operator sets the mode selector switch to manual, the boric acid and total makeup flow controllers to the desired flow rates, the boric acid and total makeup batch integrators to the desired quantities, and actuates the makeup start switch. The start switch actuates the boric acid flow control valve and the primary grade water flow control valve and starts the pre-selected boric acid transfer pump. When the preset quantities of boric acid and primary grade water have been added, the batch integrators cause makeup to stop. This operation may be stopped manually by actuating the makeup stop switch. BVPS-2 UFSAR Rev. 13 9.3-39 If either batch integrator is satisfied before the other has recorded its required total, the pump and valve associated with the integrator that has been satisfied will terminate flow. The flow controlled by the other integrator will continue until that integrator is satisfied. In the manual mode, the operator normally sets the controls such that the boric acid flow is terminated first to prevent the piping systems from remaining

filled with a nominal 4 weight percent boric acid solution. The quantities of boric acid and primary grade water injected

are totalized by the batch counters, and the flow rates are recorded on strip recorders. Deviation alarms sound for both boric acid and primary grade water flow rates when they deviate

from their set points. 9.3.4.2.4 Component Description

A summary of principal component design parameters is given in Table 9.3-8, and safety classifications and design codes are

given in Section 3.2. All CVCS piping that handles radioactive liquid is austenitic stainless steel. All piping joints and connections are welded, except where flanged connections are required to facilitate equipment removal for hydrostatic testing and maintenance.

Three charging pumps are supplied to inject coolant into the RCS. One of these is an installed spare. The pumps are of the single speed, horizontal, centrifugal type. All parts in contact with the reactor coolant are fabricated of austenitic stainless steel or other material of adequate corrosion resistance. The charging pump seals are provided with leakoffs to collect the leakage before it can leak out to the atmosphere. A minimum flow recirculation line to protect the centrifugal charging pumps from a closed discharge valve condition is provided. See Section 6.3 for a description of the charging pump miniflow provisions.

Charging flow rate is determined from a pressurizer level signal. Charging flow control is accomplished by a modulating

valve on the discharge side of the centrifugal pumps. The centrifugal charging pumps also serve as HHSI pumps in the ECCS. A description of the charging pump function upon receipt of a safety injection signal is given in Section 6.3.2.2. Power supplies to the charging pumps are provided separately. One pump is powered from the orange Class 1E bus, one is powered from the purple Class 1E bus, and the third pump, which is normally de-energized, can be manually transferred to either Class 1E bus to replace one of the other two pumps.

BVPS-2 UFSAR Rev. 13 9.3-40 Two boric acid transfer pumps are supplied. One pump is

normally aligned to supply boric acid to the blender while the second serves as a standby. Manual or automatic initiation of the reactor makeup control system will start the one pump to provide a normal makeup of boric acid solution to the blender. Miniflow from this pump flows back to the associated boric acid tank and helps maintain thermal equilibrium. The standby pump can be used intermittently to circulate boric acid solution through the other tank to maintain thermal equilibrium in this part of the system. A redundant emergency boration flow path, which will supply nominal 4 weight percent boric acid solution directly to the suction of the charging pumps, can be provided by opening either a MOV or solenoid-operated valve (at the charging pump suction). These two valves are powered from different Class 1E sources. The transfer pumps also function to transfer solution from the batching tank to the boric acid

tanks. The boric acid transfer pumps are located in the auxiliary

building, and the boric acid lines are heat traced as necessary to prevent crystalization of the boric acid solution. All parts in contact with the solution are of austenitic stainless steel.

Regenerative Heat Exchanger The regenerative heat exchanger is designed to recover heat from the letdown flow by reheating the charging flow, which reduces thermal effects on the charging penetrations into the reactor

coolant loop piping. The letdown stream flows through the shell of the regenerative heat exchanger while the charging stream flows through the tubes. The letdown coolant then experiences a large pressure reduction passing through a restricting orifice upstream of the letdown heat exchanger. The unit is constructed of austenitic stainless steel and is of an all welded construction.

The temperatures of both the letdown and charging outlet streams from the heat exchanger are monitored, with indication given in the main control room. A high temperature alarm is actuated on

the main control board if the temperature of the letdown stream exceeds desired limits (Table 9.3-8). Letdown Heat Exchanger

The letdown heat exchanger cools the letdown stream to the operating temperature of the mixed bed demineralizers. Reactor coolant flows through the tube side of the exchanger while CCW flows through the shell side. All surfaces in contact with the reactor coolant are austenitic stainless steel and the shell is of carbon steel.

BVPS-2 UFSAR Rev. 13 9.3-41 The low pressure letdown valve, located downstream of the heat exchanger, maintains the pressure of the letdown flow upstream of the heat exchanger in a range sufficiently high to prevent two-phase flow. Pressure indication and high pressure alarm are

provided on the main control board. The letdown temperature control indicates and controls the temperature of the letdown flow exiting from the letdown heat exchanger. A temperature sensor, which is part of the CVCS, provides input to the controller in the primary CCW system. The exit temperature of the letdown stream is thus controlled by regulating the CCW flow through the letdown heat exchanger. Letdown temperature indication is provided on the main control

board. If the outlet temperature from the heat exchanger is excessive, a high temperature alarm is actuated and a temperature control valve diverts the letdown directly to the

VCT, bypassing the demineralizers. The outlet temperature from the shell side of the heat exchanger

is allowed to vary over an acceptable range compatible with the equipment design parameters and required performance of the heat exchanger in reducing letdown stream temperature.

Excess Letdown Heat Exchanger The excess letdown heat exchanger cools excess reactor coolant letdown flow at the flow rate which is equivalent to the portion of the nominal seal injection flow which flows into the RCS

through the RCP labyrinth seals. The excess letdown heat exchanger can be employed either when normal letdown is temporarily out of service, to maintain the reactor in operation, or it can be used to supplement maximum letdown during the final stages of heatup. The letdown flows through the tube side of the unit and CCW is circulated through the shell. All surfaces in contact with reactor coolant are austenitic stainless steel and the shell is of carbon steel.

All tube joints are welded. A temperature detector measures the temperature of the excess letdown flow downstream of the excess letdown heat exchanger. Temperature indication and high temperature alarm are provided on the main control board. A pressure sensor indicates the pressure of the excess letdown flow downstream of the excess letdown heat exchanger and excess letdown control valve. Pressure indication is provided on the main control board.

BVPS-2 UFSAR Rev. 20 9.3-42 Seal Water Heat Exchanger The seal water heat exchanger is designed to cool fluid from three sources: RCP number 1 seal leakage, reactor coolant discharged from the excess letdown heat exchanger, and miniflow from a centrifugal charging pump. Reactor coolant flows through

the tube side of the heat exchanger, and CCW is circulated through the shell. The design flow rate through the tube side is equal to the sum of the nominal excess letdown flow, maximum design RCP seal leakage which originally assumed operation of the floating ring seals, and miniflow from one centrifugal charging pump. The unit is designed to cool the above flow to

the temperature normally maintained in the VCT. All surfaces in contact with reactor coolant are austenitic stainless steel and

the shell is of carbon steel.

Volume Control Tank

The VCT provides surge capacity for part of the reactor coolant expansion volume not accommodated by the pressurizer. When the

level in the tank reaches the high level set point, the remainder of the expansion volume is accommodated by diversion of the letdown stream to the BRS. The tank also provides one of the means for introducing hydrogen into the coolant to maintain the required equilibrium concentration of 25 to 50 cc hydrogen (at STP per kilogram of water) and may be used for degassing the reactor coolant. It also serves as a head tank for the charging

pumps.

Hydrogen is introduced into the letdown stream via an in-line

bayonet sparger located upstream of the VCT, and via a direct

connection on the VCT from the hydrogen supply system. In

addition, a spray nozzle located inside the tank on the letdown line provides additional liquid to gas contact between the

incoming fluid and the hydrogen atmosphere in the tank. The

hydrogen required is provided by the GWD system or the generator

hydrogen control system.

A remotely-operated vent valve, discharging to the GWD system, permits the venting method to be used during normal operation

for removal of gaseous fission products. For the normal method of degassification, refer to the BRS Section 9.3.4.6. Relief protection, gas space sampling, and nitrogen purge connections

are also provided.

The VCT pressure is monitored, with indication given in the main control room. An alarm is actuated in the main control room for

high and low pressure conditions.

BVPS-2 UFSAR Rev. 13 9.3-43 Two level channels govern the water inventory in the VCT. Level indication with high and low alarms is provided on the main control board for one controller and local level indication is provided for the other controller. If the VCT level rises above the normal operating range, one level channel provides an analog signal to the proportional controller, which modulates the three-way valve downstream of the reactor coolant filter to

maintain the VCT level within the normal operating band. The three-way valve can split letdown flow so that a portion goes to the BRS and a portion to the VCT. The controller would operate in this fashion during a dilution operation when primary grade water is being fed to the VCT from the reactor makeup control system. If the modulating function of the channel fails and the VCT level continues to rise, the high level alarm will alert the operator to the malfunction and the full letdown flow will be automatically diverted by the backup level channel.

During normal power operation, a low level in the VCT initiates auto makeup which injects a pre-selected blend of boric acid solution and primary grade water into the charging pump suction header. When the VCT level is restored to normal, auto makeup stops. If the automatic makeup fails or is not aligned for operation and the tank level continues to decrease, a low level alarm is

actuated. Manual action may correct the situation or, if the level continues to decrease, a low-low signal from either level channel opens the stop valves in the RWST supply line to the

charging pump suctions, and closes the stop valves in the VCT outlet line.

Boric Acid Tanks

The combined capacity of the two boric acid tanks is sized to store sufficient boric acid solution for refueling, plus enough for cold shutdown from full power operation immediately following refueling with the most reactive control rod not

inserted. The concentration of boric acid solution in storage is maintained between 4 and 4.4 weight percent. Periodic manual sampling and corrective action, if necessary, assure that these limits are maintained. Therefore, measured amounts of boric

acid solution can be delivered to the reactor coolant to control the boron concentration.

A temperature sensor provides temperature measurement of each tank's contents. Local temperature indication, as well as high and low temperature alarms, are provided on the main control board. Strip heaters are provided to maintain each tank's contents within the required temperature to prevent boric acid crystallization.

BVPS-2 UFSAR Rev. 13 9.3-44 Two level detectors indicate the level in each boric acid tank. Level indication, with high, low, and low-low level alarms, is provided on the main control board. The high alarm indicates that the tank may soon overflow. The low alarm warns the operator to start makeup to the tank. The low-low alarm is set to indicate the minimum level of boric acid in the tank to

ensure that sufficient boric acid is available for a cold shutdown with one stuck rod.

The batching tank is used to provide makeup to the boric acid tanks. A local sampling point is provided for verifying the solution concentration prior to transferring it out of the tank.

The tank is provided with an agitator to improve mixing during batching operations and a steam jacket for heating the boric acid solution. A temperature sensor provides temperature

measurement of the tank's contents, with local temperature indication. A level sensor provides level measurement of the tank's contents, with local indication.

The primary use of the chemical mixing tank is in the preparation of caustic solutions for pH control, hydrazine solution for oxygen scavenging, and hydrogen peroxide for oxygenation during plant shutdowns as necessary.

Two flushable mixed bed demineralizers assist in maintaining reactor coolant purity. A lithium-form cation resin and hydroxyl-form anion resin are charged into one of the

demineralizers. The anion resin is converted to the borate form in operation. Both types of resin remove fission and corrosion products. The resin bed is designed to reduce the concentration of ionic isotopes in the purification stream, except for cesium, yttrium, and molybdenum, by a minimum factor of 10. Each demineralizer has more than sufficient capacity for one core

cycle with 1 percent of the rated core thermal power being generated by defective fuel rods. One demineralizer is normally in service with the other in standby.

The other demineralizer is normally charged with mixed bed resin. This demineralizer may be charged with cation, anion, or

Li-7 cation resin with hydroxyl form anion resin in order to provide flexibility in the support of normal plant operation, shutdown cleanup operations following an activity release, or

for reactor coolant deboration purposes.

BVPS-2 UFSAR Rev. 13 9.3-45 A temperature sensor monitors the temperature of the letdown flow downstream of the letdown heat exchanger. If the letdown temperature exceeds the maximum allowable resin operating temperature (approximately 140F), a three-way valve is automatically actuated such that the flow bypasses the demineralizers. Temperature indication and high temperature alarm are provided on the main control board. The air-operated

three-way valve in the failure mode will direct flow to the VCT.

A flushable demineralizer normally charged with cation resin in the hydrogen form is located downstream of the mixed bed demineralizers and is used intermittently to control the concentration of Li which builds up in the coolant from the B (n, ) Li reaction. The demineralizer also has sufficient capacity to maintain the Cesium-137 concentration in the coolant

below 1.0 Ci/cc with 1 percent defective fuel. The resin bed is designed to reduce the concentration of ionic isotopes, particularly cesium, yttrium, and molybdenum by a minimum factor of 10. The demineralizer has more than sufficient capacity for one core cycle with 1 percent of the rated core thermal power

being generated by defective fuel rods. If this demineralizer is not available, other CVCS demineralizers can be used to maintain the Cesium-137 concentration in the coolant below 1.0 Ci per cc with 1 percent defective fuel. Alternately, the demineralizer may be charged with mixed bed, anion, or Li-7 cation resin with hydroxyl form anion resin in order to provide flexibility in the support of normal plant operation, shutdown cleanup operations following an activity release, or for reactor coolant deboration purposes.

Two deborating demineralizers are provided. One of the demineralizer's resin is normally a hydroxyl form anion resin. The capacity is consistent with removing boron to compensate for core burnup beyond about 90 percent of the core cycle. Flow can be diverted to the deborating demineralizers from a point upstream of the mixed bed demineralizers or downstream of the

mixed bed and/or the cation bed demineralizer. Alternately, the demineralizers may be charged with mixed bed, cation, anion, or Li-7 cation resin with hydroxyl form anion resin in order to provide flexibility in the support of normal plant operation, shutdown cleanup operations following an

activity release, or for reactor coolant deboration purposes.

BVPS-2 UFSAR Rev. 13 9.3-46 The reactor coolant filter is located in the letdown line upstream of the VCT. The filter collects resin fines and particulates from the letdown stream. The nominal flow capacity of the filter is greater than the maximum purification flow rate. Two local pressure indicators are provided to show the pressures upstream and downstream of the reactor coolant filter and thus provide filter differential pressure.

Two seal water injection filters are located in parallel in a common line to the RCP seals where they collect particulate matter that could be harmful to the seal faces. Each filter is sized to accept flow in excess of the normal seal water flow

requirements. Normally, one filter is in service with the other in standby. A differential pressure indicator monitors the pressure drop across each seal water injection filter and gives local indication, with high differential pressure alarm on the main control board.

This filter collects particulates from the RCP seal water return and from the excess letdown flow. The filter is designed to pass the sum of the excess letdown flow and the maximum design leakage from three RCPs. Two local pressure indicators are provided to show the pressures upstream and downstream of the filter and thus provide differential pressure across the filter.

The boric acid filter collects particulates from the boric acid

solution being pumped from the boric acid tanks by the boric acid transfer pumps. The filter is designed to pass the design flow of two boric acid transfer pumps operating simultaneously. Local pressure indicators indicate the pressure upstream and downstream of the boric acid filter and thus provide filter differential pressure.

Three letdown orifices are provided to reduce the letdown pressure from reactor conditions and to control the flow of reactor coolant leaving the RCS. The orifices are placed into

or taken out of service by remote operation of their respective isolation valves. Two of the orifices are designed for normal letdown flow, with one normally on line and the other two serving as standby. One or both of the standby orifices may be used in parallel with the normally operating orifice for either flow control, when the RCS pressure is less than normal, or greater letdown flow during maximum purification or heatup. Each orifice consists of an assembly which provides for permanent pressure loss without recovery, and is made of

austenitic stainless steel. A flow monitor provides indication in the main control room of

the letdown flow rate and a high alarm to indicate unusually high flow.

A low pressure letdown controller located downstream of the letdown heat exchanger controls the pressure upstream of the letdown heat exchanger to prevent flashing of the letdown

liquid. Pressure indication and high pressure alarm are provided on the main control board. BVPS-2 UFSAR Rev. 20 9.3-47 Where pressure and temperature conditions permit, diaphragm type valves are used to essentially eliminate leakage to the

atmosphere. All packed valves which are larger than 2 inches and which are designated for radioactive services are provided

with a stuffing box and lantern leakoff connections. All original plant control (modulating) and three-way valves are either provided with stuffing box and leakoff connections or are

totally enclosed. New or replacement control valves contain stuffing box designs that provide an equivalent level of leak

protection to the original valves. Leakage to the atmosphere is

essentially zero for these valves. The basic material of construction for all valves that handle radioactive liquids or

boric acid solutions is austenitic stainless steel.

Relief valves are provided for these lines and components that

might be pressurized above design pressure by improper operation

or component malfunction: 1. Charging Line Upstream of Regenerative Heat Exchanger If the charging side of the regenerative heat exchanger is isolated while the hot letdown flow continues at its maximum rate, the volumetric expansion of coolant on the charging side of the heat exchanger is relieved to the PRT through the pressure

relief valve (PRV) upstream of the regenerative heat

exchanger. 2. Letdown Line Downstream of Letdown Orifices The PRV downstream of the letdown orifices protects the low pressure piping and the letdown heat exchanger from overpressure when the low pressure piping is

isolated. The capacity of the PRV is equal to the

maximum flow rate through all letdown orifices. The valve set pressure is equal to the design pressure of

the letdown heat exchanger tube side. 3. Letdown Line Downstream of Low Pressure Letdown Valve The PRV downstream of the low pressure letdown valve protects the low pressure piping and equipment from overpressure when this section of the system is isolated. The overpressure may result from leakage through the low pressure letdown valve. The capacity of the PRV exceeds the maximum flow rate through all letdown orifices. The valve set pressure is equal to

the design pressure of the demineralizers. 4. Volume Control Tank The PRV on the VCT permits the tank to be designed for a lower pressure than the upstream equipment. This valve capacity was sized to include the RCP floating ring seal return flow, plus excess letdown flow, plus charging pump miniflow for two pumps, and nominal flow from the primary grade water system. With the floating ring seals removed the expected RCP seal leakage is reduced. The valve set pressure equals the design pressure of the VCT. BVPS-2 UFSAR Rev. 13 9.3-48 5. Seal Water Return Line (Inside Containment) This PRV relieves overpressurization in the seal water return piping inside containment if the MOV for isolation is closed. The PRV is designed to relieve the maximum leakoff flow from the number 1 seals of the three RCPs plus the design excess letdown flow.

The valve is set to relieve at the design pressure of the piping.

6. Seal Water Return Line (Charging Pumps Bypass Flow)

This PRV protects the seal water heat exchanger and its associated piping from overpressurization. If either of the isolation valves for the heat exchanger are closed and if the bypass line is closed, the

piping would be overpressurized by the miniflow from the centrifugal charging pumps. The valve is sized to handle the miniflow from the three centrifugal

charging pumps. The PRV is set to relieve at the design pressure of the heat exchanger.

7. Steam Line to Batching Tank This PRV protects the low pressure piping and batching tank heating jacket from overpressure when the condensate return line is isolated. The valve is sized to relieve the maximum expected steam inlet

flow. Piping All CVCS piping that handles radioactive liquids is austenitic stainless steel. All piping joints and connections are welded, except where flanged connections are required to facilitate equipment removal for maintenance and hydrostatic testing.

9.3.4.2.5 System Operation Reactor Start-up Reactor start-up is defined as the operations which bring the reactor from cold conditions to normal operating temperature and

pressure. It is assumed that:

1. Normal RHR is in progress,

2. Reactor coolant system boron concentration is at the cold shutdown concentration,

3. The reactor makeup control system is set to provide makeup at the cold shutdown concentration, BVPS-2 UFSAR Rev. 13 9.3-49 4. The reactor coolant system is either filled with a pressurizer steam or nitrogen bubble or is drained to minimum level for the purpose of refueling or maintenance. System pressure is maintained by the operation of one charging pump and by the VCT gas overpressure. The RHR/CVCS cross-connect valve is aligned for the letdown flow to bypass the normal

letdown via the RHR system, and

5. The charging and letdown lines of the CVCS are filled with coolant at the cold shutdown boron concentration and the letdown orifice isolation valves are closed.

If the RCS requires filling and venting, the following is a representative sequence of events:

1. One charging pump is started, which provides blended flow from the reactor makeup control system at the

cold shutdown boron concentration, 2. The vents on the head of the reactor vessel and pressurizer are opened, and

3. The RCS is filled and the vents closed.

Nitrogen gas is placed on the pressurizer and RCS pressure is raised to permit reactor coolant pump operation. A charging pump is in operation, seal water to the RCPs is established, RHRS is in service and letdown is by way of the RHRS to the VCT. The RCPs are intermittently operated and the reactor head is vented in sequence until all air is swept from the loops. RCS pressure is lowered and the head is vented. The primary plant tanks are purged with nitrogen to reduce the oxygen to within chemistry specifications. The pressurizer is filled to a water

solid condition and the pressurizer heaters are energized to heat the pressurizer. When the pressurizer is heated to a prescribed temperature, the steam bubble is formed in the

pressurizer by manual control of letdown. RCPs can be started and used to heat the RCS. When the pressurizer water level reaches the no-load programmed set point, the pressurizer level control is shifted to control the charging flow to maintain programmed level. The RHRS is then isolated from the RCS and the normal letdown path is established. The pressurizer heaters

are now used to increase RCS pressure. The reactor coolant boron concentration is now reduced by operating the reactor makeup control system in the dilute mode. The reactor coolant boron concentration is corrected to the point where the control rods may be withdrawn and criticality

achieved. During heatup, the appropriate combination of letdown orifices is used to provide necessary letdown flow.

BVPS-2 UFSAR Rev. 13 9.3-50 Prior to or during the heating process, the CVCS is employed to obtain the current water chemistry in the RCS. The reactor makeup control system is operated on a continuing basis to ensure a desired critical boron concentration. Chemicals are added through the chemical mixing tank to control reactor coolant chemistry such as pH and dissolved oxygen content. Hydrogen overpressure is established in the VCT to assure the

appropriate hydrogen concentration in the reactor coolant. Power Generation and Hot Standby Operation

1. Base Load

At a constant power level, the rates of charging and letdown are dictated by the requirements for seal water to the RCPs and the normal purification of the RCS. One charging pump is employed and charging flow is controlled automatically by a pressurizer liquid level transmitter signal to the discharge header flow control valve. Occasional adjustments in boron concentration are necessary to compensate for core burnup. As variations in power level occur, some adjustment in boron concentration as well as rod height may be necessary. During normal operation, normal letdown flow is maintained and one mixed bed demineralizer is in service. Reactor coolant samples are taken

periodically to check boron concentration, water quality, pH, and activity level. The charging flow to the RCS is controlled automatically by the pressurizer level control signal through the discharge header flow control valve.

2. Load Following A power reduction will initially cause a xenon buildup followed by xenon decay to a new, lower equilibrium value. The reverse occurs if the power level increases. Initially, the xenon level decreases, then it increases to a new and higher equilibrium value associated with the amount of power level change.

The reactor makeup control system, or the makeup system and control rod positioning, is normally used to compensate for xenon transients occurring when the reactor power level is changed. The operator may borate or dilute the RCS to compensate for xenon generation or decay.

BVPS-2 UFSAR Rev. 16 9.3-51 During periods of plant loading, the reactor coolant expands as its temperature rises. The pressurizer absorbs this expansion as the level controller raises the level set point to the increased level associated

with the new power level. The excess coolant due to RCS expansion is letdown and is stored in the VCT. During this period, the flow through the letdown orifice remains constant and the charging flow is reduced by the pressurizer level control signal. This results in an increased temperature at the regenerative heat exchanger outlet. The temperature controller downstream from the letdown heat exchanger increases the CCW flow to maintain the desired letdown

temperature.

During periods of plant load reduction, the charging flow is increased to make up for the coolant contraction not accommodated by the programmed reduction in pressurizer level.

3. Hot Standby

For periods of maintenance, or following reactor trips, the reactor can be held subcritical, but with the capability to return to full power within the period of time it takes to withdraw control rods. During this standby period, temperature can be maintained at no-load T by initially dumping steam to remove core residual heat, or at later stages, by running RCPs to maintain system temperature. Following shutdown, xenon buildup occurs and increases the degree of shutdown, that is, with initial xenon concentration and all control rods inserted, the core is maintained at a minimum of 1-percent k/k subcritical. The effect of xenon buildup is to increase this value to a maximum of about 4-percent k/k at about 8 hours following shutdown from equilibrium full power conditions. If hot standby is

maintained past this point, xenon decay results in a decrease in degree of shutdown. Since the value of the initial xenon concentration is about 3-percent k/k (assuming that an equilibrium concentration had been reached during operation), boration of the

reactor coolant is necessary to counteract the xenon decay and maintain shutdown. If a rapid recovery is required, dilution of the system may be performed to counteract this xenon

buildup. However, after the xenon concentration reaches a peak, boration must be performed to maintain the reactor subcritical as the xenon decays out.

BVPS-2 UFSAR Rev. 13 9.3-52 Cold Shutdown Cold shutdown is the operation which takes the reactor from hot standby conditions to cold shutdown conditions (reactor is subcritical by at least 1-percent k/k and T 200F). Before initiating a cold shutdown, the RCS hydrogen concentration is lowered by reducing the VCT overpressure, by replacing the VCT hydrogen atmosphere with nitrogen, and by purging to the GWD system.

Before cooldown and depressurization of the reactor plant is initiated, the reactor coolant boron concentration is increased to the cold shutdown value. After the boration is completed and reactor coolant samples verify that the concentration is correct, the operator resets the reactor makeup control system for leakage makeup and system contraction at the shutdown reactor coolant boron concentration.

Contraction of the coolant during cooldown of the RCS causes the pressurizer level to decrease. This causes charging flow to increase which results in a decreasing VCT level. The VCT level

controller automatically initiates makeup to maintain the inventory.

After the RHR system is placed in service and the RCPs are shutdown, further cooling of the pressurizer liquid can be accomplished by charging through the auxiliary spray line. Coincident with plant cooldown, a portion of the reactor coolant flow is diverted from the RHR system to the CVCS for cleanup. Demineralization of ionic radioactive impurities and stripping of fission gases via the degasifier (Section 9.3.4.6) reduce the reactor coolant activity level sufficiently to permit personnel access for refueling or maintenance operations. Refer to Section 5.4.7 for additional cold shutdown information. 9.3.4.3 Safety Evaluation

The classification of structures, components and systems is presented in Section 3.2. A further discussion on seismic design categories is given in Section 3.7. Conformance with U.S. Nuclear Regulatory Commission GDC for the plant systems, components, and structures important to safety is presented in Section 3.1. Also, Section 1.8 provides a discussion on Regulatory Guide compliance.

9.3.4.3.1 Reactivity Control Any time that the unit is at power, the quantity of boric acid retained and ready for injection always exceeds that quantity required for the normal cold shutdown, assuming that the control rod assembly of greatest worth is in its fully withdrawn position. This quantity always exceeds the quantity of boric acid required to bring the reactor to hot standby and to compensate for subsequent xenon decay. An adequate quantity of

boric acid is also available in the RWST to achieve cold shutdown.

BVPS-2 UFSAR Rev. 13 9.3-53 Two separate and independent flow paths are available for reactor coolant boration: the charging line and the RCP seal injection line. A single failure does not result in the inability to borate the RCS.

If the normal charging line is not available, charging to the RCS is continued via RCP seal injection at the rate of approximately 5 gpm per pump. At the charging rate of 15 gpm (5 gpm per RCP), approximately 6 hours are required to add enough boric acid solution to counteract xenon decay, although xenon decay below the full power equilibrium operating level will not begin until approximately 25 hours after the reactor is shut down. As backup to the normal boric acid supply, the operator can align the RWST outlet to the suction of the charging pumps.

Since inoperability of a single component does not impair ability to meet boron injection requirements, plant operating procedures allow components to be temporarily out of service for repairs. However, with an inoperable component, the ability to tolerate additional component failure is limited. Therefore, operating procedures generally require immediate action to effect repairs of an inoperable component, restrict permissible repair time, and require demonstration of the operability of the

redundant component. Section 5.4.7 provides a discussion of cold shutdown design.

9.3.4.3.2 Reactor Coolant Purification

The CVCS is capable of reducing the concentration of ionic isotopes in the purification stream as required in the design basis. This is accomplished by passing the letdown flow through one of the mixed bed demineralizers which removes ionic isotopes, except those of cesium, molybdenum and yttrium, with a minimum decontamination factor of 10. Through occasional use of the cation bed demineralizer, the concentration of cesium can be maintained below 1.0 c/cc, assuming 1 percent of the rated core thermal power is being produced by fuel with defective cladding. The cation bed demineralizer is capable of passing the design letdown flow, though only a portion of this capacity is normally utilized. Each mixed bed demineralizer is capable of processing the maximum purification letdown flow rate. If the normally operating mixed bed demineralizer resin has become exhausted, the second demineralizer can be placed in service. Each demineralizer is designed, however, to operate for one core cycle with 1-percent defective fuel.

A cleanup feature is provided for use during RHR operations. A remote-operated valve admits a bypass flow from the RHR system into the letdown line at a point upstream of the letdown heat exchanger. The flow passes through the heat exchanger, then passes through one of the mixed bed demineralizers, and through the reactor coolant filter to the VCT. The fluid is then

returned to the RCS via the normal charging route.

BVPS-2 UFSAR Rev. 13 9.3-54 The maximum temperature that will be allowed for the mixed bed and cation bed demineralizers is approximately 140F. If the temperature of the letdown stream approaches this level, the flow will be automatically diverted so as to bypass the demineralizers. If the letdown is not diverted, the only consequence would be a decrease in ion removal capability. Ion removal capability starts to decrease when the temperature of the resin goes above approximately 160F for anion resin, or above approximately 250F for cation resin. The resins do not lose their exchange capability immediately. Ion exchange still takes place (at a faster rate) when temperature is increased. However, with increasing temperature, the resin loses some of its ion exchange sites along with the ions that are held at the lost sites. The ions lost from the sites may be re-exchanged farther down the bed. The number of sites lost is a function of the temperature reached in the bed and of the time the bed remains at the high temperature. Capability for ion exchange

will not be lost until a significant portion of the exchange sites are lost from the resin.

An effect on reactor operating conditions is the possibility of an increase in the reactor coolant activity level. If the activity level in the reactor coolant were to exceed the limit given in the Technical Specifications, reactor operation would be restricted, as required by the Technical Specifications (Chapter 16). Overheat of resin can lead to corrosive deposits on nuclear fuel as well as formation of deleterious species, which are easily detected by chemical analysis.

9.3.4.3.3 Seal Water Injection Flow to the RCP seals is assured since there are three charging

pumps, any one of which is capable of supplying the normal charging flow plus the nominal seal water flow.

9.3.4.3.4 Hydrostatic Testing of the Reactor Coolant System Section 5.2.4.7 provides details.

9.3.4.3.5 Leakage Provisions

Components, valves, and piping which are exposed to radioactive service are designed to limit leakage to the atmosphere. The following are preventive means which limit radioactive leakage

to the environment:

1. Where pressure and temperature conditions permit, diaphragm type valves are used to essentially

eliminate leakage to the atmosphere, 2. All packed valves which are larger than 2 inches and designated for radioactive service at an operating fluid temperature of 212F or greater and/or pressure 275 psig are provided with a stuffing box and lantern leakoff connections, BVPS-2 UFSAR Rev. 13 9.3-55 3. Welding of all piping joints and connections except where flanged connections are provided to facilitate maintenance and hydrostatic testing, is performed. The VCT provides an inferential measurement of leakage from the CVCS as well as the RCS. The amount of leakage can be inferred from the amount of makeup added by the reactor makeup control

system. The hydrogen and fission gases in the VCT can be purged to the GWD system via the degasifier, to limit the release of radioactive gases through leakage, by maintaining the radioactive gas level in the reactor coolant several times lower

than the equilibrium level. The BVPS-2 is of a continuous degassification design (Section 9.3.4.6). Also provided are two mixed bed demineralizers which maintain reactor coolant purity, thus reducing the radioactivity level of the RCS water. 9.3.4.3.6 Ability to Meet the Safeguards Function

A failure modes and effects analysis (FMEA) of the portion of the CVCS which is safety related (used as part of the ECCS) is included as part of the ECCS FMEA presented in Tables 6.3-5 and 6.3-6.

9.3.4.3.7 Heat Tracing Heat tracing requirements for boric acid solutions depend mainly

on the solution concentration. Fo r this system the concentration of boric acid ranges from 10 ppm to nominal 4

weight percent boric acid. Electrical heat tracing is provided for all CVCS piping and components which contain boric acid of 4 weight percent and are not located in an area where the temperature is at least 65F. Section 9.3.4.2 provides more information.

9.3.4.3.8 Abnormal Operation The CVCS is capable of making up for a small RCS leak of approximately 130 gpm, using one centrifugal charging pump, and still maintain seal injection flow to the RCPs. This also allows for minimum RCS cooldown contractions and is accomplished

with the letdown isolated. 9.3.4.3.9 Failure Modes and Effects Analysis

The FMEA, summarized in Table 9.3-9, demonstrates that single active component failures do not compromise the CVCS safe

shutdown functions of boration and makeup. The FMEA also shows that single failures occurring during CVCS operation do not compromise the ability to prevent or mitigate accidents. These

capabilities are accomplished by a combination of suitable redundancy, instrumentation for indication and/or alarm of abnormal conditions, and relief valves to protect piping and components against malfunctions. In addition, the CVCS shares components with ECCS and containment isolation functions. These safeguard functions of the CVCS are addressed in Section 6.3.

BVPS-2 UFSAR Rev. 13 9.3-56 9.3.4.4 Inspection and Testing Requirements As part of plant operation, periodic tests, surveillance inspections, and instrument calibrations are made to monitor equipment condition and performance. Most components are in use regularly and therefore, assurance of the availability and performance of the systems and equipment is provided by main

control room and/or local indication. Technical Specifications and Licensing Requirements Manual requirements have been established concerning calibration, checking, and sampling of the CVCS, and, is addressed in Chapter 16. Preliminary tests are performed as described in

Section 14.2. 9.3.4.5 Instrumentation Requirements

Process control instrumentation is provided to acquire data concerning key parameters about the CVCS.

The instrumentation furnishes input signals for monitoring and/or alarming purposes. Indications and/or alarms are provided for the following parameters: temperature, pressure, flow, and water level.

The instrumentation also supplies input signals for control purposes. Some specific control functions are: letdown flow is diverted to the VCT upon high temperature indication upstream of the mixed bed demineralizers, pressure upstream of the letdown heat exchanger is controlled to prevent flashing of the letdown liquid, charging flow rate is controlled during charging pump operation, water level is controlled in the VCT, temperature of the boric acid solution in the batching tank is maintained, and reactor makeup is controlled.

9.3.4.6 Boron Recovery System

The BRS processes reactor coolant letdown and liquid collected in the PDTTs to reduce the concentration of dissolved and entrained gases. The separated gases (hydrogen, nitrogen, argon, krypton, and xenon) are discharged to the GWD system (Section 11.3) for handling and processing. The degassed liquid is either returned to the CVCS (Section 9.3.4) or discharged to either the BVPS-1 coolant recovery tanks or the BVPS-2 SGB tanks, via the cesium removal ion exchangers and coolant recovery filters, to recover both concentrated boric acid

solution and evaporator distillate for future use or disposal. 9.3.4.6.1 Design Bases

The BRS is designed to meet the following criteria:

1. General Design Criterion 1, as it relates to system components being assigned quality group

classifications and application of quality standards.

BVPS-2 UFSAR Rev. 13 9.3-57 2. General Design Criterion 2, as it relates to structures housing the facility and the system itself being capable of withstanding the effects of earthquakes.

3. General Design Criterion 5, as it relates to shared systems and components important to safety being capable of performing required safety functions.

4. The portion of the BRS containing undegassed liquid has a Safety Class 3 classification. The remainder of the system, which includes the degasifier and downstream piping and components, is classified as NNS class. Determination of the safety classification is in accordance with the guidelines as discussed in Regulatory Guide 1.26.

5. The undegassed portion of the BRS is seismically designed to Seismic Category I. The BRS is located in the auxiliary building, a Seismic Category I structure. The safety-related portions of the BRS are in accordance with the guidelines as discussed in

Regulatory Guide 1.29.

6. Although this unit is expected to be operating as a base load unit, the facilities are designed to provide unit capability for a flexible weekly load schedule, acceptance of unscheduled load demands, and back-to-

back cold shutdowns.

7. As a basis of design, a weekly load schedule has been postulated as follows: 2 days at 30-percent power, followed by 5 days each with 6 hours at 30-percent power, an increase to 100-percent power in 1 hour, 12 hours at full power, a decrease to 30-percent power in 1 hour, and 4 hours at 30-percent power.

8. The total system is designed to enable the unit, in the event of an unscheduled load demand, to increase to the required power level with a ramp change in reactor power of 5-percent of full power per minute through most of each fuel cycle.

9. The coolant storage facilities available in BVPS-1 provide sufficient storage for the stripped liquid produced by 30 days of maximum reactor coolant letdown to the degasifier system, when operating on the postulated weekly load schedule, plus borated water effluent from a back-to-back cold shutdown of one

reactor at the end of the 30-day period at 75 percent of the combined design capacity of BVPS-1 boron recovery evaporators and the evaporator available on

BVPS-2 (Section 11.2).

BVPS-2 UFSAR Rev. 13 9.3-58 The available storage at BVPS-1 is based on the combined BVPS-1 and BVPS-2 evaporator capability to process coolant at the design rate, which is 75 percent of the maximum rate, and the existence of a 13-week differential in the fuel cycle between the two reactors with the resultant variance in the coolant letdown rates. Consequently, the necessary storage requirements for the coolant from both reactors can be accommodated in the BVPS-1 storage facilities. The BVPS-1 coolant recovery tanks are located indoors. The total coolant storage capacity in BVPS-1 of 380,000 gallons is necessary to meet the design criteria.

10. The BRS is not required to operate to achieve cold shutdown; however, degasification of reactor coolant may be an operational consideration in anticipation of refueling or maintenance. The CVCS system has the capability to bypass the BRS and send letdown directly to the BVPS-1 coolant recovery tank for storage as discussed in Section 9.3.4.

9.3.4.6.2 System Description

The BRS, as shown on Figure 9.3-26, includes two degasifiers that remove gases (hydrogen, nitrogen, argon, krypton, and xenon) from reactor coolant letdown or from liquid collected in the PDTT. The two degasifier subsystems are identical to each other in construction and controls except for the minor differences in their inlet and outlet piping arrangement. Although their uses are different under normal circumstances, either subsystem may be used for processing fluid from either potential source and therefore, are considered to be redundant systems. Flow of reactor coolant to the degasifier equipment is continuous, with the majority of the stripped gases recycled through the GWD system and back to the VCT in the CVCS. The reactor coolant letdown flow is normally directed to degasifier A, but can be directed to either or both degasifiers whenever necessary to facilitate the postulated load schedule. The flow from the PDTTs is intermittently sent to degasifier B. Degassed liquid from degasifier A is directed to the CVCS and/or the cesium removal ion exchangers. All the degassed liquid from degasifier B goes directly to the cesium removal ion exchanger when processing liquid from the PDTTs. The inlet and outlet piping of the degasifiers is arranged such that, under normal conditions, degasifier A processes reactor coolant letdown from the CVCS. Degasifier A receives reactor coolant letdown at a variable rate of up to 75 gpm, as selected by the operator, and operates in the normal mode as part of the continuous degasification capability. Degasifier B processes liquid from

the PDTTs (inside and outside containment) via two different sets of primary drains transfer pumps (Section 9.3.3), intermittently at a rate of 25 gpm (50 gpm for short periods if

the pumps associated with both tanks cycle on at about the same BVPS-2 UFSAR Rev. 13 9.3-59 time). The fluid from degasifier A is directed to either the coolant recovery tanks in BVPS-1 or the VCT. Degasifier B directs the liquid to the coolant recovery tanks. The discharge liquid from the degasifiers can also be directed to the SGB

tanks and then on to the LWD system. The degasifier systems separate noncondensable gases from the inlet feed. This is accomplished by spraying water containing dissolved gases into the upper portion of the degasifier vessel. The operating conditions maintained in the vessel are 2 psig and 219F, which are saturation conditions. The feed to the spray nozzles is passed through the degasifier steam heaters and

heated to 245 F. Part of this flow flashes to steam, dispersing the remaining water to small droplets and providing a large amount of liquid surface area for the transfer of dissolved gases from the liquid to the vapor phase in the vessel. Since the flashing process results in liquid and vapor at saturation conditions (2 psig and 219 F) and the solubility of a gas in liquid under saturation conditions approaches zero, essentially all dissolved gases are released. The liquid droplets fall to the lower part of the vessel while the gases and some steam flow to the degasifier vent condenser. The vent condenser is supplied with CCW (Section 9.2.2.1) regulated to maintain the degasifier at a pressure of 2 psig. Most of the steam flowing to the vent condenser is condensed and returned to the degasifier vessel via a loop seal. The loop seal is provided

for water return to the degasifier vessel so that steam and gases from the vessel can flow only into the top of the condenser, this being required for proper condenser operation.

The noncondensable gases, and a small amount of steam, flow to the degasifier vent chiller through a restricting orifice sized to produce a pressure drop of approximately 1 psi. The vent chiller is cooled by an unregulated supply of CCW. The steam is condensed and directed to the PDTTs while the noncondensable

gases are drawn into the GWD system (Section 11.3). The vent condenser is located above the degasifier vessel. The

condenser is connected to the vessel by an 8-inch (nominal size) pipe to allow unrestricted flow from the degasifier vessel to the vent condenser. Flow from the vent condenser to the vent chiller is restricted to limit the flow of steam to the vent chiller and to maintain a low temperature in the vent chiller. This ensures that the noncondensable gases, which are withdrawn to the GWD system contain as little water vapor as possible. Water carried over into the GWD system is removed by water traps and returned to the PDTT outside containment.

When a degasifier is not operating, the system is maintained hot in a recirculation mode. The recirculation mode is accomplished by running the degasifier recirculation pump which draws liquid from the degasifier bottom and pumps it through the pressure control valve, the degasifier steam heater, and back to the degasifier. The forced circulation of the liquid through the steam heaters maintains a steam environment at 2 psig within the vapor space of the degasifier and the unit is ready for instant

operation. BVPS-2 UFSAR Rev. 13 9.3-60 The degasifier trim cooler is designed to cool the degassed liquid leaving the degasifier. The CCW, regulated as required, cools the liquid to 120 F. The degasifier recovery exchangers are designed to recover heat from the degassed liquid leaving the degasifier system by transferring it to the degassed feed liquid entering the system. This reduces the load on the steam heater and the trim cooler during normal operation.

The degasifier circulation pump draws water from the degasifier vessel. Part of the discharge from the pump is mixed with the inlet to maintain a flow rate of 75 gpm through the spray nozzles. The rest is discharged through the recovery exchangers and trim cooler. The pump is designed to transport liquid from the degasifier system to BVPS-1 coolant recovery tanks, the VCT, or the SGB tanks, and then on to the LWD system. The pumps are located below the degasifier vessel to provide sufficient net

positive suction head (NPSH). The cesium removal ion exchangers purify the degasified degassed liquid prior to its reaching either the BVPS-1 coolant recovery tanks or BVPS-2 SGB tanks (normal flow path is to a BVPS-1 coolant recovery tank). The ion exchanger resin is normally of the mixed bed type. The effluent is borated water. The purpose of these ion exchangers is to remove impurities in the degasifier system discharge (primarily cesium). Each of the two

cesium removal ion exchangers and each of the two coolant recovery filters is designed for a flow rate of 150 gpm, equal to the combined capacity of the two degasifiers. There is complete redundancy in this portion of the system. Normally, the discharge of the coolant recovery filters is sent to a BVPS-1 coolant recovery tank for storage and processing. There is

also the capability to send the discharge to the BVPS-2 SGB tanks and process the liquid in the steam generator evaporators (Section 11.2).

Alternately, the demineralizers may be charged with mixed bed, cation, anion, or Li-7 cation resin with hydroxyl form anion

resin in order to provide flexibility in the support of normal plant operation, shutdown cleanup operations following an activity release, or for reactor coolant deboration purposes.

The coolant recovery filters remove resin fines and other particulate matter from the liquid prior to its reaching the

BVPS-1 coolant recovery tanks or BVPS-2 SGB tanks.

BVPS-2 UFSAR Rev. 13 9.3-61 9.3.4.6.3 Safety Evaluation Two separate degasifier subsystems are provided and are considered redundant. The inlet piping associated with each degasifier is arranged so that normally degasifier A receives only liquid from the CVCS and degasifier B only from the PDTTs. The outlet piping in the BRS and CVCS is arranged so that normally degasifier A discharges to the VCT, the BVPS-1 coolant recovery tanks and/or the SGB tanks, and then on to the LWD system. Degasifier B discharges to the BVPS-1 coolant recovery tanks or to the SGB tanks, and then on to the LWD system. Degasifier A has sufficient capacity to degasify the normal letdown flow rate of 60 gpm. If the letdown rate to the

degasifiers is increased to more than 75 gpm, degasifier B must also be used. This precludes returning all the degasified liquid to the VCT since degasifier B flow is directed to the

BVPS-1 coolant recovery tanks via the cesium removal ion exchangers and associated coolant recovery filters. The basis of this flow path is that degasifier B potentially contains

liquid of a different boron concentration from the RCS and may be contaminated with foreign material from the PDTTs. This is not an operational restriction because letdown at a rate greater than 60 gpm will only be required when heating up or during dilution of the RCS (Section 9.3.4).

The degasifiers have a combined capacity of 150 gpm, which is sufficient to degasify letdown at the maximum rate plus degasify the liquid pumped by one primary drains transfer pump. Operation of two primary drains transfer pumps simultaneously will result in a slight overload of the two degasifiers (10 gpm each). This is an infrequent and inconsequential occurrence.

In the event of failure of one degasifier, the other degasifier provides a 50-percent degasification capability subject to the

following limitations:

1. If degasifier A fails, effluent from degasifier B should not be returned to the CVCS until degasifier B is thoroughly flushed by letdown from the CVCS or sampled to verify boron concentration is the same as the RCS boron concentration and the contents meet the specifications for RCS makeup water.

2. If degasifier B fails, the PDTTs should not be pumped while the BRS is returning effluent to the CVCS.

After pumping the PDTTs, degasifier A should be

thoroughly flushed with water from the CVCS prior to returning effluent to the CVCS. Certain active failures can be accepted without loss of the complete capability of the degasifier. These are limited to failures which can be counteracted by manual operation of MOVs and by hand control of the various temperature, pressure, or level control valves. Failure of any control valve, trip valve, or the circulation pump will require shutdown of the degasifier

for repair. BVPS-2 UFSAR Rev. 13 9.3-62 The Safety Class 3 portion of the BRS (Figure 9.3-26) includes an AOV on each line connecting to the NNS class portion. A second MOV is provided upstream in the Safety Class 3 portion of each line to ensure isolation when required. These AOVs are designed to the same requirements as the safety portion and are provided with Class 1E electrical power and remote control from the main control room.

9.3.4.6.4 Inspection and Testing Requirements

A program of tests and inspections facilitates maintaining the design basis capability of the BRS throughout the lifetime of BVPS-2. For both initial and post-operational hydrostatic testing, each degasifier system is tested as a complete unit after being isolated from the rest of the BRS and other systems. The remainder of the BRS is tested in a similar manner. The ion exchangers, filters, and associated piping and valves may be

tested individually, or as a group as desired, since there are separate inlet and outlet isolation valves for each component.

Prior to initial unit start-up, each piece of equipment or subsystem that may be independently operated is made to perform at design flow rates, temperatures, and pressures so as to

establish control set points. These control set points are used to verify the subsequent proper operation of the subsystems and to ensure that the overall system capability is not reduced by

any component of the system. Preliminary tests are performed as described in Section 14.2.

Temperature and/or pressure sensors on the inlets and outlets of the various heat exchangers allow evaluation of the heat exchangers performance. Indications of pump and valve performance can be gained by observing the various pressure and level instrumentation. There are no specific provisions for

testing the pump and valves in service. 9.3.4.6.5 Instrumentation Requirements

Selector switches with indicating lights are provided in the main control room for the degasifier recirculation pumps. These

pumps may be started manually or automatically. While in the automatic mode, the pumps are started provided the degasifier level is not low-low, cooling water flow to degasifier recovery

exchangers is high, and degasifier feed flow is high. The degasifier recirculation pump will be stopped provided the cooling water flow to the degasifier recovery exchangers is not high or the degasifier level is low-low. The degasifier recirculation pump will not restart in the auto mode, if stopped by a low-low degasifier level, until the level rises above low

or low-low level is cleared and the degasifier feed is high.

BVPS-2 UFSAR Rev. 13 9.3-63 Manual auto control stations are provided in the main control room for the inlet to trim cooler level control valves. In the auto mode, these valves are modulated to control the degasifier level. Control switches with indicating lights are provided in the main control room for the degasifier isolation valves. The valves

are operated manually. Standby recirculation trip valves are provided for the degasifier system. These valves have indicating lights in the main control room. These valves are operated automatically when a respective degasifier circulating pump is not in the

automatic mode or the pump is not running. Manual-auto control stations are provided in the main control

room for the steam to degasifier heaters temperature control valves. These valves are provided with feed forward control to reduce sudden pressure rises in the degasifier during the transfer to normal operation from the standby mode. These valves are supplied with indicating lights on the main control board. Manual-auto control stations are provided in the main control room for the cooling water to vent condenser pressure control

valves. These valves are used for automatic regulation of the cooling water flow through the vent condenser. These valves are supplied with indicating lights on the main board.

Selector switches with indicating lights are provided in the main control room for the degasifier recovery exchange inlet

valves, degasifier trim cooler outlet valves, cesium removal ion exchangers inlet valves and bypass valve, and cesium removal ion exchangers outlet valves. These valves are operated manually.

Manual-auto control stations are provided in the main control room for the feed inlet pressure control valves. These valves

maintain the spray nozzle flow rate at a constant value for proper operation of the spray nozzles in the recirculation pump loop. Manual-auto control stations are provided in the main control room for the cooling water to trim the coolers temperature

control valves. These valves are modulated automatically to control the cooling water to the trim coolers.

Control switches with indicating lights are provided in the main control room for the pressure control valves located on the hydrogen supply lines. The hydrogen is provided for purging the degasifier. These valves are operated manually from the main control board or automatically to maintain hydrogen purge pressure.

BVPS-2 UFSAR Rev. 13 9.3-64 Control switches with indicating lights are provided in the main control room for the primary CCW supply and return isolation valves. These valves are operated manually. When a CIA signal is not present, these valves may be opened manually. A CIA

signal being present and a respective surge tank level low will close these valves automatically.

Control switches with indicating lights are provided in the main control room for the degasifier recovery exchangers isolation valves. These isolation valves are operated manually.

A differential pressure indicator is provided in the main control room for the coolant recovery filters.

Pressure recorders are provided in the main control room for the degasifiers vapor pressures and the degasifiers feed inlet

pressures. Flow indicators are provided in the main control room for the

feed flow to the degasifiers. A level recorder is provided in the main control room for the

levels in the degasifiers. Temperature indicators are provided in the main control room for

the outlet temperatures of the trim coolers. Temperature recorders are provided in the main control room for feed inlet temperatures of the degasifiers, recovery exchangers inlet and outlet temperatures, liquid temperatures of the degasifiers, recirculation pumps discharge temperatures, recovery exchangers bottoms to the trim coolers outlet temperatures, and the vent condensers outlet temperatures.

Annunciation with associated computer inputs is provided in the main control room for the BRS trouble alarm. The trouble alarm consists of high level in the degasifiers, high or low vapor pressures in the degasifiers, boron coolant recovery filter differential pressure high, and the trim coolers for degasifiers high temperature.

Inputs needed but not associated with the annunciation system are provided in the computer for the feed flow of the

degasifiers, pressure of the degasifiers, and trim cooler outlet temperature.

9.3.5 Reference

for Section 9.3

U.S. Nuclear Regulatory Commission, 1980. Clarification of TMI Action Plan Requirements. NUREG-0737.

BVPS-2 UFSAR Tables for Section 9.3

BVPS-2 UFSAR Rev. 17 1 of 2 TABLE 9.3-1 STATION AIR AND CONDENSATE POLISHING AIR SYSTEMS PRINCIPAL COMPONENTS AND DESIGN PARAMETERS Components Design Parameters

Station Instrument Condensate Air Air Polishing Compressor System System Air System Quantity 2 1 1 Discharge pressure (psig) 120 110 120 Discharge temperature (F) 115 120 115 Capacity, (scfm) each 728 1500 407 Motor, (hp) each 200 460 (diesel 125 engine) Station Station Condensate Instrument Service Polishing Air Receiver Air System Air System Air System

Quantity 2 2 1 Capacity, (ft) each 307.5 & 336.9 160.5 55.4 Pressure, design/ operating (psig) 125/110 & 125/110 125/110 each 150/110 Code ASME VIII ASME VIII ASME VIII

Station Instrument Air

Normal Diesel Standby Dryer Number 2 1 Capacity, @ 100 psig scfm 650 1500 Pressure Dew point @ 100 psig, F 40 Type Heatless Heatless Regenerative, Regenerative Dual Tower Desiccant Desiccant Prefilter

Number 1 per dryer 1 & 1 in bypass line Capacity, @ 100 psig scfm 800 1500 Retention size, microns 0.3 0.3 (solids) Type Coalescing Coalescing

BVPS-2 UFSAR Rev. 17 2 of 2 TABLE 9.3-1 (Cont) Station Instrument Air

Normal Diesel Standby Afterfilter

Number 1 per dryer 1 & 1 in bypass line Capacity, @ 100 psig scfm 750 1500 Retention size, microns 3 3 (solids) Type Particulate Particulate

BVPS-2 UFSAR Rev. 17 1 of 2 TABLE 9.3-2 STATION AIR AND CONDENSATE POLISHING AIR SYSTEMS CONSEQUENCES OF COMPONENT FAILURES Station Air System

Component Failure Mode Consequence

Station air

compressors A compressor

casting ruptures, or general compressor failure

Redundant air compressor

can be used to achieve full system capability. Station air system

receivers An air receiver

ruptures Redundant air compressor

and other receiver can

be used to achieve system capability or receiver bypass can be

utilized. Station instrument air prefilters and afterfilters Prefilter and/or afterfilter clogs Appropriate filter

bypass may be utilized during maintenance. Cartridge type bypass

filters isolating dryer, a pre-filter and afterfilter may be

utilized to accomplish partial drying. Station instrument air dryer Air dryer ruptures

or malfunctions Desiccant-type cartridge

removal filter bypass system would be utilized

to supply dry air to instrument air system. Bypass filters supplied by condensate polishing air system can be used. Electrically-powered station air system

compressors Electrical failure of one electrical bus Sufficient electrical system redundancy is provided to ensure full

system capability (Section 8.3). Service air portion of station air system Rupture of service air portion Service air portion is

automatically isolated on low discharge header

pressure by an AOV. Must be manually reset to restore pressure to

service system. BVPS-2 UFSAR Rev. 0 2 of 2 TABLE 9.3-2 (Cont) Condensate Polishing Air System

Component Failure Mode Consequence Condensate polishing air compressor Compressor casting ruptures, or general compressor

failure No compressor redundancy provided. Crossover to station air system will

provide required air for system. Condensate polishing air compressor

aftercooler Aftercooler tube ruptures No compressor redundancy

provided. Crossover to station air system will

provide required air for system. Condensate polishing air receiver Air receiver ruptures No compressor redundancy

provided. Crossover to station air system will

provide required air for system. Electrically-powered condensate polishing air

compressor Electrical failure of electrical bus No electrical redundancy

provided. Crossover to station air system will

provide required air for system. BVPS-2 UFSAR Rev. 14 1 of 2 TABLE 9.3-3 CONTAINMENT INSTRUMENT AIR SYSTEM PRINCIPAL COMPONENTS AND DESIGN PARAMETERS Compressors Quantity 2 Suction pressure (psia)

9.5 Suction

temperature ( F) 60 Discharge pressure (psia) 109.7 Discharge temperature ( F) 66 Capacity, (scfm) each 30 Motor, (hp) each 40 Air Receiver

Quantity 2 Capacity (ft) 1 at approx. 57 & 1 at 31.8 Pressure design/operating, (psig) each 150/110

Code ASME VIII

Dryer Quantity 1 Capacity (scfm) 30 Dew point at 100 psig ( F) +35* Type Refrigerant Inlet Filter

Quantity 1 Capacity (scfm) 100 Retention size (microns)

• • Filter element Dry cartridge Outlet Filter Quantity 1 Capacity (scfm) 30 Retention size (microns) 5 Filter element Ceramic BVPS-2 UFSAR Rev. 13 2 of 2 TABLE 9.3-3 (Cont)

Components Design Parameters Bypass Filters Quantity 2 Capacity, (scfm) each 2IAC-FLT24 100 2IAC-FLT23 72 Retention size (microns) 1 Filter element Wool felt, silica gel, Borosilicate glass (FLT 24) NOTES:

• Temperature limitation due to freezing of refrigerant coil at lower temperatures.

** Filters will remove all particles greater than 10 microns, and 98 weight percent of all particles greater than 3 microns. 

BVPS-2 UFSAR Rev. 0 1 of 1 TABLE 9.3-4 CONTAINMENT INSTRUMENT AIR SYSTEM CONSEQUENCES OF COMPONENT FAILURES Component Failure Mode Consequence Containment instrument air

heat exchangers Heat exchanger

tube ruptures Redundant air compressor

can be used to achieve

full system capability. Containment instrument air receiver outside the containment

Air receiver

ruptures Air receiver has bypass

to ensure full system capability. Containment instrument air

dryer Air dryer ruptures Bypass around air dryer through standby dehy-

drating filter ensures system capability. Electrically-powered containment

instrument air compressors Electrical failure

of one electrical bus Sufficient electrical system redundancy is provided to ensure full

system capability (Section 8.3).

BVPS-2 UFSAR Rev. 0 1 of 1 TABLE 9.3-5 REACTOR PLANT AND PROCESS SAMPLING SYSTEM SAMPLING CAPABILITIES High Temperature Samples Pressurizer vapor Pressurizer liquid Residual heat removal liquid - downstream of the residual heat removal pumps Residual heat removal liquid - downsteam of the residual heat removal heat exchangers Primary coolant from each of the reactor coolant loops Steam generator blowdown taken from each of the blowdown lines Low Temperature Samples Safety injection system accumulators (three) Supply header to chemical and volume control system demineralizers Discharge header to chemical and volume control system demineralizers - reactor coolant filter influent Chemical and volume control system deborating demineralizer effluent (two) Chemical and volume control system mixed bed demineralizer effluent (two) Chemical and volume control system cation demineralizer effluent Volume control tank liquid Volume control tank vapor space Pressurizer relief tank gas space Component cooling water Degasifier liquid effluent (two) Charging pump discharge from each of the charging pump discharge headers Gaseous waste storage tanks Primary drain transfer tanks Waste gas surge tank Primary grade water Letdown flow Fuel pool Cesium removal influent and effluent Test tanks

Examples of Lines With Local Sample Acquisition Capability

Refueling water storage tank Boric acid batch tank Chemical addition tank

BVPS-2 UFSAR Rev. 0 1 of 1 TABLE 9.3-6 NUCLEAR VENTS AND DRAINS SYSTEM PRINCIPAL COMPONENTS AND DESIGN PARAMETERS Components Design Parameters Primary Drains Transfer Tanks Quantity 2 Capacity, (gal) each 900 Operating pressure (psig) 7 Design pressure (psig) 50 Operating temperature ( F) 100 Design temperature ( F) 300 Material Type 304 stainless steel Primary Drains Transfer Pumps Quantity 2(P21A & B) 2(P22A & B) Capacity, (gpm) each 25 25 TDH, (ft) each 200 160 Design temperature (F) 150 150 Motor, (hp) each 5 5 NPSH, required (ft) each 3 3 Primary Drains Cooler Quantity 1 Duty (Btu/hr) 1.5x10 Tube side, nuclear vents drains 3,683 (lb/hr) Operating pressure (psig) 12 Design pressure (psig) 150 Operating temperature, in/out ( F) 212/170 Design temperature ( F) 300 Material Type 304 stainless steel Shell side, component cooling water 65,000 (lb/hr) Operating pressure (psig) 135 Design pressure (psig) 175 Operating temperature, in/out ( F) 100/127 Design temperature ( F) 240 Material of construction Carbon steel

BVPS-2 UFSAR Rev. 20 1 of 1 TABLE 9.3-7 CHEMICAL AND VOLUME CONTROL SYSTEM DESIGN BASES AND DESIGN PARAMETERS

Design Bases Design Parameters

Seal water supply flow rate for

three RCPs, nominal (gpm) 24 Seal water return flow rate for

three RCPs, nominal (gpm) 9 Letdown flow Normal (gpm) 60 Maximum (gpm) 120* Charging flow (excludes seal water) Normal (gpm) 45 Maximum (gpm) 105* Temperature of letdown reactor coolant entering system ( F) 528.5 to 543.1 Temperature of charging flow directed to RCS ( F) (approximately) 497 Temperature of effluent directed to BRS ( F) 115 Centrifugal charging pumps bypass flow, each (gpm) 60 Maximum pressurization required for

hydrostatic testing of RCS (psig) 3,107

• Maximum letdown and charging flows may be increased to 180 gpm in Mode 5 to assist in RCS cleanup.

BVPS-2 UFSAR Rev. 16 1 of 8 TABLE 9.3-8 CHEMICAL AND VOLUME CONTROL SYSTEM PRINCIPAL COMPONENTS AND DESIGN PARAMETERS Components Design Parameters Centrifugal Charging Pumps Quantity 3 Design pressure (psig) 2,800 Design temperature ( F) 300 Design flow, (gpm) each 150 Design head (ft) 5,800 (mini- mum) Motor, (hp) each 600 Material Austenitic stainless steel NPSH, required (ft @ max design flow) 40 Boric Acid Transfer Pumps Quantity 2 Design pressure (psig) 150 Design temperature ( F) 200 Design flow, (gpm) each 75 Design head (ft) 235 Motor, (hp) each 15 Material Austenitic stainless steel Regenerative Heat Exchanger General Quantity 1 Heat transfer rate at normal conditions (Btu/hr) 8.34 x 10 Heat transfer rate at maximum conditions (But/hr) 17.0 x 10 Shell side

Design pressure (psig) 2,485 Design temperature ( F) 650 Material Austenitic stainless steel

BVPS-2 UFSAR Rev. 1 2 of 8 TABLE 9.3-8 (Cont) Tube side

Design pressure (psig) 2,735 Design temperature ( F) 650 Material Austenitic stainless steel Operating parameters Maximum Normal Purification Shell side

Flow (lb/hr) 29,826 59,700 Inlet temperature (F) 542.5 542.5 Outlet temperature (F) 283.3 281.2 Tube side Flow (lb/hr) 22,370 52,250 Inlet temperature ( F) 130 130 Outlet temperature ( F) 489 448.2 Letdown Orifices General Design pressure (psig) 2,485 Design temperature (F) 650 Normal operating inlet pressure (psig) 2195 Normal operating temperature (F) 290 Material of construction Austenitic stainless steel 60 gpm Orifice

Quantity 2 Design flow (lb/hr) 29,826 Differential pressure at design flow (psig) 1,900 Diameter (inches) 0.242 45 gpm Orifice Quantity 1 Design flow (lb/hr) 22,370 Differential pressure at design flow (psi) 1,900 Diameter (inches) 0.215 BVPS-2 UFSAR Rev. 12 3 of 8 TABLE 9.3-8 (Cont) General Quantity 1 Heat transfer rate at design conditions (Btu/hr) 15.8 x 10 Heat transfer rate at normal conditions (Btu/hr) 5.1 x 10 Shell side

Design pressure (psig) 150 Design temperature ( F) 250 Fluid CCW Material Carbon Steel Tube side

Design pressure (psig) 600 Design temperature ( F) 400 Fluid Borated reactor coolant Material Austenitic stainless steel Operating parameters

Shell side Flow (lb/hr) 62,700 Design Inlet temperature ( F) 100* Design Outlet temperature ( F) 181 Tube side Flow (lb/hr) 28,820 Inlet temperature ( F) 287 Outlet temperature ( F) 115

• Temperature range is approximately 80 - 106F depending on river (service water) temperature and plant operation.

BVPS-2 UFSAR Rev. 12 4 of 8 TABLE 9.3-8 (Cont) General Quantity 1 Heat transfer rate at design conditions (Btu/hr) 3.23 x 10 Design fouling factors (hr/ft - F/Btu) Shell 0.0005 Tube 0.0003 Shell side Design pressure (psig) 150 Design temperature ( F) 250 Design flow rate (lb/hr) 83,500 Design operating inlet temperature ( F) 100* Design operating outlet temperature ( F) 138.7 Fluid CCW Material Carbon steel Tube side Design pressure (psig) 2,485 Design temperature ( F) 650 Design flow rate (lb/hr) 7,500 Normal operating inlet temperature ( F) 547 Normal operating outlet temperature ( F) 139 Fluid Borated reactor coolant Material Austenitic stainless steel

• Temperature range is approximately 80-106 F depending on river (service water) temperature and plant operation.

BVPS-2 UFSAR Rev. 12 5 of 8 TABLE 9.3-8 (Cont) General Quantity 1 Heat transfer rate at design conditions (Btu/hr) 1.45 x 10 Shell side Design pressure (psig) 150 Design Temperature ( F) 250 Pressure loss at design conditions 8.3 (psi) Nozzle size (in) 4 Fluid CCW Material Carbon steel Tube side Design pressure (psig) 200 Design temperature ( F) 250 Fluid Borated reactor coolant Material Austenitic stainless steel Design operating parameters

Shell side Flow (lb/hr) 49,400 Inlet temperature ( F) 100* Outlet temperature ( F) 122.1 Tube side Flow (lb/hr) 42,000 Inlet temperature ( F) 141 Outlet temperature ( F) 115 Quantity 1 Design pressure (psig) 200 Design temperature ( F) 250 Normal flow rate (gpm) 9 Maximum flow rate (gpm) 320 Retention for 25-micron 98 particles (%)

• Temperature range is approximately 80-106 F depending on river (service water) temperature and plant operation.

BVPS-2 UFSAR Rev. 12 6 of 8 TABLE 9.3-8 (Cont) Material Austenitic stainless steel Quantity 2 Design pressure (psig) 2,735 Design temperature (F) 200 Flow rate, (gpm) each 80 Retention for 5-micron particles (%) 98 Material, vessel Austenitic stainless steel Quantity 1 Design pressure (psig) 200 Design temperature (F) 250 Design flow rate (gpm) 150 Maximum flow rate (gpm) 120 Maximum differential pressure, 100% fouled (psi) 20 Retention for 25-micron particles (%) 98 Material Austenitic stainless steel Quantity 2 Capacity, (gal) each 12,500 Design pressure Atmospheric Design temperature (F) 200 Normal operating temperature span (F) 80-90 Material Austenitic stainless steel Quantity 2 Type Flushable Vessel design pressure (psig) 200 Vessel design temperature (F) 250 Design flow rate, (gpm) each 120 Material Austenitic stainless steel BVPS-2 UFSAR Rev. 12 7 of 8 TABLE 9.3-8 (Cont) Quantity 1 Type Flushable Vessel design pressure (psig) 200 Vessel design temperature (F) 250 Design flow rate (gpm) 60 Material Austenitic stainless steel Quantity 2 Type Flushable Vessel design pressure (psig) 200 Vessel design temperature (F) 250 Design flow rate (gpm) each 120 Material Austenitic stainless steel Quantity 1 Capacity (gal) 65 Design pressure Atmospheric Design temperature ( F) 200 Normal operating temperature Ambient Material Austenitic stainless steel Quantity 1 Capacity (gal) 5.0 Design pressure (psig) 150 Design temperature ( F) 200 Normal operating temperature Ambient

Material Austenitic stainless steel BVPS-2 UFSAR Rev. 0 8 of 8 TABLE 9.3-8 (Cont) Batching Tank Quantity 1 Type Jacketed Capacity (gal) 400 Design pressure Atmospheric Design temperature ( F) 250 Normal operating temperature (F) 165 Material, tank Austenitic stainless steel Material, jacket Carbon steel

BVPS-2 UFSAR Rev. 0 1 of 4 TABLE 9.3-10 BORON RECOVERY SYSTEM COMPONENT DESIGN DATA Component Design Parameter Degasifiers Quantity 2 Capacity, (gpm) each 75 Operating pressure (psig) 2 Design pressure (psig) 125/Full vacuum Operating temperature ( F) 219 Design temperature ( F) 353 Material Type 304 stainless

steel Degasifier Recovery Exchangers Quantity 4 Duty, (Btu/hr) each 3,000,000 Tube side, degasified borated water (gpm) 75 Operating pressure (psig) 100 Design pressure (psig) 200 Operating temperature, in/out (F) 219/139 Design temperature ( F) 350 Material Type 304 stainless

steel Shell side, gasified borated water (gpm) 75 Operating pressure (psig) 50 Design pressure (psig) 200 Operating temperature, in/out (F) 100/180 Design temperature ( F) 350 Material Type 304 stainless

steel BVPS-2 UFSAR Rev. 0 2 of 4 TABLE 9.3-10 (Cont) Component Design Parameter Degasifier Steam Heaters Quantity 2 Duty, (Btu/hr) each 4,460,000

Tube side, gasified borated water (gpm) 85 Operating pressure (psig) 25 Design pressure (psig) 200 Operating temperature, in/out (F) 135/240 Design temperature ( F) 360 Material Type 304 stainless steel Shell side, steam (lb/hr) 5,000 Operating pressure (psig) 100 Design pressure (psig) 165 Operating temperature, in/out (F) 338/338 Design temperature ( F) 375 Material Carbon Steel SA-106-B Degasifier Vent Condensers

Quantity 2 Duty, (Btu/hr) each 905,000 Tube side, component cooling (gpm) 133 Operating pressure (psig) 60 Design pressure (psig) 150 Operating temperature, in/out (F) 105/119 Design temperature ( F) 350 Material Type 304 stainless steel Shell side, degasified gas stream (lb/hr) 935 Operating pressure (psig) 2 Design pressure (psig) 150 Operating temperature, in/out (F) 219/219 Design temperature ( F) 350 Material Type 304 stainless steel

BVPS-2 UFSAR Rev. 0 3 of 4 TABLE 9.3-10 (Cont) Component Design Parameter Degasifier Circulation Pumps Quantity 2 Capacity, (gpm) each 75 Operating pressure (psig) 115 Design pressure (psig) 150 Operating temperature ( F) 219 Design temperature ( F) 219 TDH (ft) 260 Motor, (hp) each 20 Material Type 304 stainless

steel

Degasifier Vent Chillers Quantity 2 Duty, (Btu/hr) each 12,340 Tube side, component cooling water (gpm) 10 Operating pressure (psig) 60 Design pressure (psig) 150 Operating temperature, in/out ( F) 105/107.5 Design temperature ( F) 350 Material Type 304 stainless steel Shell side, degasified gas stream (lb/hr) 11.4 Operating pressure (psig) 1 Design pressure (psig) 150 Operating temperature, in/out (F) 215/110 Design temperature ( F) 350 Material Type 304 stainless steel BVPS-2 UFSAR Rev. 0 4 of 4 TABLE 9.3-10 (Cont) Component Design Parameter Trim Coolers Quantity 2 Duty, (Btu/hr) each 710,000 Tube side, borated water (gpm) 75 Operating pressure (psig) 90 Design pressure (psig) 200 Operating temperature, in/out (F) 139/120 Design temperature ( F) 350 Material Type 304 stainless

steel Shell side, component cooling (gpm) 142 Operating pressure (psig) 60 Design pressure (psig) 150 Operating temperature, in/out (F) 105/115 Design temperature ( F) 350 Material Carbon Steel

Cesium Removal Ion Exchangers

Quantity 2 Capacity, (gpm) each 150 Operating pressure (psig) 150 Design pressure (psig) 175 Operating temperature ( F) 130 Design temperature ( F) 200 Material Type 304 stainless

steel Coolant Recovery Filters

Quantity 2 Capacity, (gpm) each 150 Operating pressure (psig) 120 Design pressure (psig) 150 Operating temperature ( F) 130 Design temperature ( F) 250 Material Type 304 stainless

steel -*---------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------* ' 261 259 STATION NFI. R'TER MOISTURE COMPRESSOR COOLER SEPMATOR 68 67 ,.R RECEIVER STATION AIR 12SASJ AIR 121ASI 102 1311 STATION 1J13 1312 1232 1229 LINER!!_ME.!!_T _ CONTAINMENT INSTRUMENT AIR 121AC) 1101 1102 Sft..Zl82 I J 18 CONDENSATE POliSHING AIR INSTRUMENT NR '1026 131 21 20 ... FlT ** ... REV. 17 INSlOE CONTAINMENT 30

• INSIDE CONT NNMENT ALL VALVE AND EQUIPMENT IDENTIFICATION NUMBERS ON THIS FIGURE ARE PRECEDED BY THE SYSTEM DESIGNATOR "2SAS" <STATION AND CONDENSATE POLISHING AIRl, OR "21AS" UNSTRUMENT AIRl UNLESS OTHERWISE INDICATED REF' BVPS STATION DRAWING' OM-3<4--1A FIGURE 9.3-1 (SHEET 1 OF 2) COMPRESSED AIR SYSTEMS BEAVER VALLEY POWER STATION -UNIT 2 UPDATED FINAL SAFETY ANALYSIS REPORT ' A ' : PREPARED CAEDDI i :

uqo34 Ko\u2\UFSAA\g'I83BBJB_ ... _(,dgM THE CNSU SfSI"EU :

' 1127 1112A SILHA 1114 COMPRESSOR C21 511.248 28-AUG-2008 14:06 K:\u2\UFSAR\g'l0301110-*h-2.dgn TK22 REV. 17 1090 TO SHT.l 1074 1079 INSTRUMENT NR RECEIVER TK22 ALL VALVE AND EQUIPMENT IDENTIFICATION NUMBERS ON THIS FIGURE ARE PRECEDED BY THE SYSTEM DESIGNATOR "SA" (STATION NRI OR "lA" (INSTRUMENT NRI UNLESS OTHERWISE INDICA TEO. FIGURE 9.3-1 (SHEET 2 OF 2) COMPRESSED AIR SYSTEMS BEAVER VALLEY POWER STATION UNIT N0.2 UPDATED FINAL SAFElY ANALYSIS REPORT PREP/IRED ON CI£.DDI THE CNSU , ---------------------------*-****'{**---------**********-**-*----------------------1 FROM RESIDUAL HEAT REMOVAL SYSTEM REGENERATIVE HEAT EXCHANGER E-23 LETDOWN FROM LOOP A COLD LEG 460 A PRESSURIZER AUX SPRAY CHARGING HEADER LOOP 8 COLD LEG RCS LOOP DRAIN HCV 142 311 310 REACTOR COOLANT PUMP SEAL WATER RETURN 204 200C A 308A E-22 NON-REGENERATIVE HEAT EXCHANGER 22 153 154 HCV 186 SEAL WATER INJECTION FILTERS 373 PCV 145 CHARGING PUMPS TO SUMP OR OGS-TK21 378 INSIDE CONTAINMENT OUTSIDE CONTAINMENT SEAL WATER RETURN FILTER FL-23 1....--'----..J E-21 SEAL WATER HEAT EXCHANGER VOLUME CONTROL TANK TK-22 8130A 81308 8131A BL31B 111 BORON RECOVERY SYSTEM DEGASIFIERS CESIUM REMOVAL ION EXCHANGERS AND COOLANT RECOVERY FILTERS FIGURE 9.3-21 REV. 12 1008 DE MINER All Z E R S UNIT 1 COOLANT RECOVERY TANKS ALL VALVE AND EQUIPMENT IDENTIFICATION NUMBERS ON THIS FIGURE ARE PRECEDED BY THE SYSTEM DESIGNATOR "2CHS" UNLESS OTHERWISE INDICATED. CHARGING AND VOLUME CONTROL SYSTEM REFERENCE DRAWINGS OM 7-lA, 7-18, 7-2 AND 7-3 BEAVER VALLEY POWER STATION UNIT N0.2 UPDATED FINAL SAFETY ANALYSIS REPORT FROM RCS CLETDOWNJ 2CHS-LCV-115A 2CHS-VOLUME TK 22 CONTROL TANK 100A 1 OOA GASEOUS WASTE EV21A DEGASIFIERS EV21B REV. 12 1008 TK22 PRIMARY DRAINS TRANSFER TANKS 2CHS-LCV-112 COOLANT RECOVERY FILTERS FLTA 21A & 218 TO STEAM GENERATOR SLOWDOWN HOLD TANKS TO UNIT 1 BORON RECOVERY SYSTEM COOLANT RECOVERY TANKS 1008 CESIUM REMOVAL ION EXCHANGERS IOE21A & 218 2CHS-100B FROM RCS CLETDOWNJ ALL VALVE AND EQUIPMENT IDENTIFICATION NUMBERS ON THIS FIGURE ARE PRECEDED BY THE SYSTEM DESIGNATOR "2BRS" UNLESS OTHERWISE INDICATED. FIGURE 9.3-26 BORON RECOVERY SYSTEM

REFERENCE:

STATION DRAWINGS OM 7-1A, 8-1, 8-2, 9-1, AND 9-2 BEAVER VALLEY POWER STATION UNIT NO. 2 UPDATED FINAL SAFETY ANALYSIS REPORT BVPS-2 UFSAR Rev. 7 9.4-1 9.4 AIR-CONDITIONING, HEATING, COOLING, AND VENTILATION SYSTEMS Heating, ventilating, and air-conditioning systems are provided in the control building (Section 9.4.1), fuel building (Section

9.4.2), auxiliary building (Section 9.4.3), turbine building (Section 9.4.4), engineered safety features equipment areas (Section 9.4.5), emergency diesel generator building (Section

9.4.6), containment structure (Section 9.4.7), intake structure (Section 9.4.8), main steam valve area (Section 9.4.9), service building (Section 9.4.10), safeguards area (Section 9.4.11), cable vault and rod control area (Section 9.4.12), decontamination building (Section 9.4.13), cooling tower pumphouse (Section 9.4.14), gland seal steam exhaust (Section

9.4.15), and condensate polishing building (Section 9.4.16). The ventilation and/or air-conditioning systems for the control

building, emergency diesel generator building, auxiliary building, fuel building, intake structure, safeguards area, and cable vault and rod control area are all, or in part, safety-related. Some of these systems are also classified as engineered safety features (ESF) since they mitigate the consequences of postulated accidents (Section 6.5.1).

The safety-related ventilation and air-conditioning systems for the control building are designed to maintain control room habitability (Section 6.4) under all foreseeable conditions. The supplementary leak collection and release system (SLCRS) is designed to control the release of gaseous radioactive effluents to the environment in the event of an accident (Section 6.5.3.2). The ventilation systems are designed to maintain temperature and/or humidity conditions, to control the air flow from areas with lesser potential for contamination to areas with greater potential for contamination, to minimize buildup of airborne radioactivity in the buildings, and to control the

release of gaseous effluents to the atmosphere. Table 9.4-1 lists all plant ventilation systems and their modes of operation. All air-conditioning, heating, and ventilation systems are designed for the following outdoor conditions (Design Weather Data, Section 2.3):

Summer Design dry bulb 90 F Design wet bulb 75 F Design daily range of design basis 22 F Winter Design dry bulb -5 F BVPS-2 UFSAR Rev. 0 9.4-2 9.4.1 Control Building Ventilation System The functions of the control building ventilation system are to provide cooling, heating, ventilation, pressurization, and smoke

removal for the several areas within the control building. Two ventilation subsystems service the control building areas: the control room air-conditioning subsystem and the control building air-conditioning subsystem. The control room air-conditioning subsystem ventilates the main control room and two adjoining areas: the computer room and the HVAC equipment room. The control building air-conditioning subsystem ventilates the remainder of the control building, which consists of the cable tunnel to the auxiliary building, the instrumentation and relay room, the cable spreading area, the motor control center (MCC) room, and the communications room. The intake and exhaust fans and cooling coils for this subsystem are located in the equipment room of the auxiliary building.

The control room and the control building ventilation subsystems are shown on Figures 9.4-1 and 9.4-2 , respectively. The control room and the control building ventilation subsystems design temperatures, principal components and design parameters, and description of operation are outlined in Tables 9.4-2, 9.4-3, and 9.4-4, respectively.

9.4.1.1 Design Bases

The design of the control room and control building heating, ventilation, and air-conditioning (HVAC) is in accordance with

the following criteria:

1. General Design Criterion 2 and Regulatory Guide 1.29, as they relate to seismic design classification of the system components and the capability of the structures housing the system to withstand the effects

of natural phenomena, as described in Chapters 2 and 3. The system is designed to Seismic Category I criteria.

2. General Design Criterion 4, as it relates to the structures housing the system and the system itself being capable of withstanding the effects of external missiles and internally-generated missiles, pipe whip, and jet impingement forces associated with pipe

breaks. 3. General Design Criterion 5, as it relates to shared systems and components important to safety.

BVPS-2 UFSAR Rev. 14 9.4-3 4. General Design Criterion 19, and 10 CFR 50.67 where applicable, as they relate to providing adequate protection to permit access and occupancy of the control room under accident conditions.

5. General Design Criterion 60, as it relates to the systems' capability to suitably control release of

gaseous radioactive effluents to the environment.

6. Regulatory Guide 1.52, as it relates to system design requirements, maximum system flow requirements, and system functional performance requirements for air filtration and adsorption units of the atmosphere

cleanup system, with the exceptions described in Section 1.8.

7. Regulatory Guide 1.78, as it relates to instrumentation capability to detect and alarm on any hazardous chemical release in the BVPS-2 vicinity, and as it relates to the systems' capability to isolate the control room from such a release. The intent of this Regulatory Guide is met through the

clarifications described in Section 1.8.

8. Single failure criterion, as it relates to air-conditioning and emergency supply filtration equipment.

9. Design temperatures and parameters, as given in Tables 9.4-2 and 9.4-3. 10. Detection of high radiation levels in the control room, or a containment isolation phase B (CIB) shall automatically close the control room outside air

intake dampers. During this condition, the control room is to be maintained above atmospheric pressure by

pressurization fans equipped with charcoal and HEPA filters to provide filtration of the outside air.

11. The capability of the smoke purge function of the control building HVAC system to exhaust smoke generated by a fire. A smoke detector in the control room air intake will initiate an alarm in the control

room. 12. The capability of the non-safety related features (in-line electric heaters) to maintain their structural integrity in the event of a safe shutdown earthquake (SSE) in order not to compromise the function

capability of the system.

13. The capability to prevent building overpressurization in the event of a CO discharge associated with fire suppression.

BVPS-2 UFSAR Rev. 18 9.4-4 9.4.1.2 System Description

The HVAC system of the control building consists of two subsystems - one for the control room envelope and the other for the remainder of the building. The control room envelope and control building HVAC systems are shown on Figures 9.4-1 and 9.4-2. The principal component design and performance

characteristics are given in Table 9.4-3. Modes of operation of the control room ventilation system are given in Table 9.4-4. The Beaver Valley Power Station - Unit 1 (BVPS-1) and Beaver Valley Power Station - Unit 2 (BVPS-2) control room air-conditioning systems are independent and physically separate. The main control room areas are open to each other and are in

the same pressure envelope. The control and operation of the

two air-conditioning systems are not interconnected. The BVPS-1 and BVPS-2 control areas of the main control room are permanently occupied and their respective operators may adjust

operating parameters within system limitations.

9.4.1.2.1 Main Control Room Area Air Conditioning

The control room air-conditioning system serves the control

room, computer room, and the HVAC equipment room. The system consists of two 100-percent capacity air-conditioning units (ACU), each containing one fan, one service water cooling coil, a direct-expansion cooling coil, an electric resistance

preheater, a bag-type filter, and a roll type filter. Each direct-expansion coil is provided with a separate refrigeration unit, which consists of compressor, condenser, and refrigerant

piping (Figure 9.4-1). One of the two ACUs supplies a mixture of outside and return air to the control room envelope during normal operation. The proportions of outdoor air quantities in terms of air changes

per hour are listed in Table 9.4-5. Individual zone heating is provided by seismic duct-mounted non-

safety related electric heating coils, controlled by space

thermostats.

In the event of a CIB signal or a high area radiation signal in

either plant, redundant motorized dampers in the outdoor air intake and exhaust ductwork will close fully, and the air-

conditioning system will continue to run on recirculation.

BVPS-2 UFSAR Rev. 14 9.4-5 After a preset time delay, redundant parallel motorized dampers will open, and the selected control room emergency supply fan will automatically start, maintaining a positive pressure in the area as long as is required. Air is drawn through one of two redundant emergency supply filtration units, each unit consisting of a moisture separator, an electric heating coil, a high efficiency particulate air filter (HEPA), a charcoal bank filter, and a second HEPA. A loss of flow from the emergency supply fan will cause the redundant fan to be energized. The smoke detector, located in the air intake for the control room area, alarms locally and annunciates in the control room. Intake dampers are manually closed to isolate outside smoke, and the air-conditioning system continues to run on 100-percent recirculation air.

The smoke detection system located within the control room area alarms locally and annunciates in the control room. Purging of smoke from the control room area is accomplished by manually positioning the outdoor, recirculation, and exhaust air dampers and running the system on a 100-percent outdoor air supply and 100-percent exhaust mode. Ventilation to the computer room is isolated upon initiation of the halon fire suppression system (Section 9.5.1).

9.4.1.2.2 Control Building Air-Conditioning System (Except Main Control Room Area)

Two 100-percent supply fans and two 100-percent return/exhaust fans ensure sufficient ventilation and heat removal for the cable tunnels, instrument and relay room, cable spreading room, MCC room, and communications room. During normal operating conditions, one supply air fan and one return air fan operate. Intake and exhaust air dampers are in the minimum open position, and the recirculation damper is in the fully open position. Ventilation air is cooled by a single chilled water coil, controlled by a valve actuated by pneumatic thermostatic

controls (Figure 9.4-2). Refer to Section 9.2.2.2 for a discussion on the chilled water coil.

A manual bypass damper is provided around the chilled water coil and its associated roll air filter to permit operation of the ventilation system when the filter or coil is not in operation.

BVPS-2 UFSAR Rev. 18 9.4-6 When the chilled water coil is unable to operate and the space temperature reaches the thermostat setting, the pneumatically-controlled outdoor, exhaust, and return air dampers will modulate to vary the ratio of outdoor air and return air to maintain a constant temperature in the air leaving the space.

Redundant dampers are provided.

On a loss of instrument air, or a high space temperature, the outdoor and exhaust air dampers open fully and the recirculation

air dampers close. This puts the air-conditioning system into a once-through mode of operation. Smoke/atmospheric contaminant purging is accomplished by repositioning the outdoor, recirculation, and exhaust air dampers and running the system on

100 percent outdoor air mode.

The smoke detection system for the control building air-

conditioning system annunciates an alarm in the control room.

9.4.1.3 Safety Evaluation

The essential ventilation equipment within the control building

includes a subsystem servicing the main control room and

adjoining areas and a second subsystem servicing the rest of the control building. The essential ventilation and air-conditioning equipment (specifically, the Service Water supplied

cooling coils) in the Control Room subsystem and all the Control Building (separate from the Control Room), including all ductwork, piping, instrumentation, and valves, are designed as

Seismic Category I systems. All equipment is located within the control building or the auxiliary building, both Seismic

Category I structures.

Upon loss of static pressure across the operating air-conditioning unit, the redundant standby unit starts automatically. However, if the static pressure of the operating control room air-conditioning unit is not lost, and the temperature in the control room continues to rise (indicating loss of refrigerant supply to air-conditioning unit failure), a manual transfer of air-conditioning units is required. The

operation of safety class equipment, motors, and controls is maintained during loss of normal station power and loss of normal offsite power by connection of the emergency diesel

generators to the emergency buses.

After initiation of a CIB or detection of high radiation levels, the control room envelope outdoor air intake and outlet dampers are closed, and the emergency supply filtration unit starts to introduce outdoor air. This pressurized and filtered outdoor air keeps the control room envelope continuously and indefinitely under positive pressure.

Radiation levels in the main control room area are monitored

continuously by redundant safety-related area monitors and by an airborne monitor which analyzes a sample drawn from the combined

recirculation and supply air duct.

BVPS-2 UFSAR Rev. 18 9.4-7 The BVPS-2 control room emergency supply filtration unit has sufficient capacity to filter the total volume of air required for pressurization of the control room envelope in the once-through mode.

The design of the control room emergency supply filtration unit is in accordance with Regulatory Guide 1.52, with a few

exceptions (Section 1.8).

The mechanical refrigerant units in the Control Room ventilation system are non-safety related, and are employed to maintain a

comfortable environment during normal operations (typically

75 F).

Two service water cooling coils in the return air stream are also provided as the primary credited method of cooling the control room envelope following a design basis accident or event. This system is designed to maintain the control room envelope below the 120F equipment limit. Refer to Section

9.2.1 for a discussion of the cooling coil. The control building (except the control room area) air-conditioning is a separate independent system. Filtration, heating, and cooling is provided for the air delivered to this section of the building. The supply fans as well as the

recirculation fans have 100-percent redundant units.

A failure modes and effects analysis (FMEA) to determine if the instrumentation and controls (I&C) and electrical portions meet the single failure criterion, and to demonstrate and verify how the General Design Criteria (GDC) and the Institute of Electrical and Electronics Engineers (IEEE) Standard 279-1971 requirements are satisfied, has been performed on the control

building and control room ventilation systems. The FMEA

methodology is discussed in Section 7.3.2. The results of this analysis can be found in the separate FMEA document (Section

1.7). A more detailed description of the safety evaluation of the control room ventilation system is provided in Section 6.4, Habitability Systems.

9.4.1.4 Inspection and Testing Requirements

All control building air-conditioning, ventilation, and chilled

water systems are initially tested and inspected for air balance, water balance, and completeness of installation. Design provisions have been made that will permit appropriate

in-service inspection and functional testing of system components important to safety. The BVPS-2 maintenance program will include replacement of useable parts such as seals and

linkages.

Preliminary tests are performed as described in Section 14.2.12. The system is in continuous operation. Periodic operation of the standby equipment, in conjunction with routine observation

and maintenance during normal operation, are sufficient to

ensure system availability.

BVPS-2 UFSAR Rev. 18 9.4-8 9.4.1.5 Instrumentation Requirements

9.4.1.5.1 Main Control Room Area

Control switches with indicating lights are provided on the

building service control panel in the main control room for the main control room area HVAC systems. Either of the two ACUs supplies filtered conditioned air to each of the three zones, consisting of the control room, computer room, and HVAC

equipment room. The supply air handling unit may be started

manually or automatically. During normal operation, one air

handling unit is in operation while the other is in standby.

Air cooling and dehumidification is provided by direct-expansion

freon cooling coils in each air handling unit. Discharge air

temperature control is regulated by maintaining a constant evaporator coil pressure. Evaporator coil pressure is

controlled by the compressor unloaders. Return air duct-mounted temperature switches will energize/deenergize a liquid line solenoid valve in accordance with the demands of their

respective areas.

Either of the two freon refrigerant/condensing units provides

the necessary cooling capacity for the system. Heat is rejected through the condenser to the BVPS-2 service water system (SWS). The refrigerant/condensing units are interlocked with their

respective air-conditioning units and controlled automatically from the compressor suction pressure operating on a continuous

pumpdown cycle.

Individual zone heating is provided by duct-mounted electric heating coils, controlled by space thermostatic controls. Each ACU is provided with a service water cooling coil to serve as an

additional backup cooling system. This additional backup system

is a manually operated system.

Control switches with indicating lights are provided on the

building service control panel in the main control room for each

motor-actuated damper.

The BVPS-2 control area is part of a single control room envelope that includes the BVPS-1 control area. Thus, to ensure BVPS-2 personnel safety, the air intakes and exhaust dampers of

both units will be closed to isolate the control room envelope from the outside in case of a CIB or high radiation signal in either unit, a high radiation signal from any one of the control

room area monitors in either unit. In addition, when either

unit is in a shutdown mode, that respective unit's air intake

and exhaust dampers will be administratively closed.

Following one of these conditions, air will be supplied from one of the emergency supply filtration units, which operate

automatically to supply filtered air to the area.

BVPS-2 UFSAR Rev. 18 9.4-8a Failure of the selected train filtration unit to start, as detected by loss of flow from the fan, initiates the start of

the redundant train filtration unit.

Control switches with indicating lights are provided on the

building service control panel in the main control room for the

emergency control room supply air fans. These supply air fans operate automatically. Temperature indication is provided in the main control room for outdoor air temperature, return air temperature, and discharge air temperature. A flow recorder is

also provided in the main control room for the control room

emergency ventilation system.

BVPS-2 UFSAR Rev. 13 9.4-9 Annunciation is provided in the main control room for the control room air-conditioning unit auto trip, control room emergency supply unit auto trip, control room air-conditioning compressors auto trip, emergency supply air low flow, central room area radiation high, smoke detection in outdoor air supply to air-conditioning units, common dirty filter alarm for emergency supply air units moisture separators and filters, high temperature in the charcoal bed of control room emergency air supply, and high-high temperature in charcoal bed of control room emergency air supply. These are also monitored by the

BVPS-2 computer system. 9.4.1.5.2 Control Building (Except Main Control Room Area)

Control switches with indicating lights are provided on the building service control panel in the main control room for each

control building supply air and exhaust air fan. Two supply air and two return/exhaust air fans powered from emergency sources ensure sufficient ventilation of the cable tunnel, cable spreading area, MCC room, communications room, and instrumentation and relay room to dissipate heat loads generated

by equipment during normal and emergency operation. During normal conditions, one supply air and one return air fan operate. The chilled water coil is controlled by a valve actuated by pneumatic thermostatic controls in the supply air duct. On a loss of instrument air, or a high space temperature, outdoor and exhaust air dampers open fully and return air

dampers close. The lead supply air fan and associated return air fan will start and stop automatically, as required, to maintain space temperature within minimum and maximum limits.

Annunciation is provided in the main control room for supply air and return/exhaust air fans auto trip, control building high

temperature and control building low temperature. These are also monitored by the BVPS-2 computer system.

A further description of I&C is given in Section 7.6.6.

9.4.2 Spent

Fuel Pool Area Ventilation System

The spent fuel pool area ventilation system removes heat generated by equipment, and water vapor due to fuel pool evaporation, to provide an environment suitable for equipment operation and personnel during normal plant operating conditions. The fuel building ventilation system is not

required to operate during accident conditions.

BVPS-2 UFSAR Rev. 13 9.4-10 9.4.2.1 Design Bases The design bases of the spent fuel pool area ventilation system include the following:

1. To maintain the spent fuel pool area indoor air temperature between 76F and 96F during normal operation.

2. The spent fuel pool area ventilation system is nonnuclear safety (NNS) class except for the exhaust

portion of the ductwork connected to the leak

collection system, which is Safety Class 3.

3. General Design Criterion 2, and Regulatory Guide 1.29, as they relate to seismic design classification. The distribution ductwork of the ventilation system is seismically designed and will withstand seismic forces

so that the safety-related equipment within the fuel building will not be damaged by ductwork during the postulated seismic events.

4. General Design Criterion 5, as it relates to shared systems and components important to safety. No portion of this system is shared.

5. General Design Criterion 60 and Regulatory Guide 1.52, as they relate to the ability of the system to minimize the release of airborne radioactivity by maintaining the fuel building at negative pressure and

by discharging exhaust air through charcoal filtration units which are part of the SLCRS, as described in Section 6.5.3.2.

6. General Design Criterion 61 and Regulatory Guide 1.13, as they relate to spent fuel pool facility design basis controlled leakage during refueling operations. Air flow is maintained from noncontaminated to potentially contaminated areas.

7. During accident conditions, this system is not required to operate, but the SLCRS continues to operate to exhaust and filter air and to maintain a negative pressure in the spent fuel pool area.

Filtration following a fuel handling accident is not required to maintain doses within the limits of 10 CFR 50.67. 9.4.2.2 System Description The principal components and design parameters of the spent fuel

pool area ventilation system are given in Table 9.4-6. The recirculation portion of the system includes a 20,000 cfm

air handling unit that consists of a roll filter, two chilled water cooling coils, two hot wa ter reheat coils, a fan, controls, and distribution ductwork to all levels.

BVPS-2 UFSAR Rev. 13 9.4-11 The exhaust portion of the system, 3,000 cfm, continuously maintains a negative pressure in the building and is connected with the SLCRS.

Condensate from the air handling unit is directed to the fuel pool (Section 9.1.3). 9.4.2.3 Safety Evaluation

The spent fuel pool area ventilation system is nonsafety-related and is not required to operate during accident conditions. The exhaust portion, which is a part of the safety-related SLCRS, continues to operate during a DBA. Air is drawn from the spent fuel pool area, which maintains a negative pressure, and is normally passed through a filtration unit before being released to the atmosphere. This procedure ensures that the release of

airborne radioactivity to the atmosphere is minimized. Airborne radiation levels are measured by a radiation monitor installed in the exhaust duct, which is part of the supplementary leak collection system.

9.4.2.4 Inspection and Testing Requirements

Routine observation and maintenance is performed to ensure operability of the system. The filtration unit housings and filters are components of the supplementary leak collection system and are factory- and site-tested, as described in Section 6.5.1.4. Preliminary tests are performed as described in Section 14.2.12.

9.4.2.5 Instrumentation Requirements

A control switch with indicating lights for the spent fuel pool area air-conditioning unit is provided on the local control panel. Cooling and dehumidification is provided by a chilled water cooling coil thermostatically-controlled valve to maintain a constant discharge air temperature. The reheat coils and the unit space heaters are thermostatically-controlled to maintain

the space temperature. Indication on the local control panel is provided for return air temperature, cooling coils discharge air temperature, supply air temperature, and outdoor air temperature. Annunciators for spent fuel pool area recirculation fan auto trip, spent fuel

pool area high temperature, and high radiation in the spent fuel pool area exhaust are provided in the main control room and are also monitored by the BVPS-2 computer system.

BVPS-2 UFSAR Rev. 0 9.4-12 9.4.3 Auxiliary Building and Radwaste Area Ventilation System The auxiliary building ventilation system provides an environment suitable for personnel and equipment operation and

minimizes the potential for spread of airborne radioactive material within the building during normal operation. The auxiliary building ventilation system is nonsafety-related, is

designated NNS class, and Seismic Category II. Normally operating portions of this system are not required to operate during accident conditions; however, a Category I backup system is provided for those segments of the building with equipment required during accident conditions. The ventilation system for those portions of the auxiliary building are described in

Section 6.5.3. The radwaste area ventilation system is an extension of the auxiliary building ventilation system. The radwaste area ventilation system is nonsafety-related and is designated NNS class. The radwaste area ventilation system is not seismically designed. It removes heat dissipated into the building from machinery, piping, lighting, and the environment, maintains an environment suitable for personnel access and equipment

operation, and minimizes the potential for the spread of radioactive airborne particulates within the building.

9.4.3.1 Design Bases The design bases of the auxiliary building and radwaste area

ventilation system include the following:

1. General Design Criterion 2, as it relates to the system being capable of withstanding the effects of

natural phenomena such as earthquakes, tornadoes, hurricanes, and floods, as established in Chapters 2

and 3.

2. General Design Criterion 5, as it relates to shared systems. No portion of the auxiliary building and radwaste area ventilation system is shared.

3. General Design Criterion 60, as it relates to control of the release of radioactive materials to the

environment.

4. Regulatory Guide 1.26, as it relates to the quality group classification of system components.

5. Regulatory Guide 1.29, as it relates to the seismic design classification of systems and components. The auxiliary building ventilation system is Seismic Category II.

6. Regulatory Guide 1.140, as it relates to the design, testing, and maintenance criterion for atmosphere

cleanup systems.

BVPS-2 UFSAR Rev. 14 9.4-13 7. To maintain the auxiliary building air temperature in the ventilation equipment area (at el 773 ft - 6 in) and in general areas (below el 773 ft - 6 in) between 60F and 104F coincident with outdoor design temperatures.

8. To maintain the component cooling water pump area and charging pump cubicles at a temperature below 104 F normally but not more than 120F in those circumstances as discussed in Section 6.5.3.2.2 where the Supplemental Leak Collection and Release System (SLCRS) is not available for post-DBA ventilation. This safety feature is provided by the component cooling water pump general area and charging cubicles emergency exhaust system. This portion of the auxiliary building exhaust is constructed in accordance with Category I design criteria and consists of redundant fans and Category I ductwork and dampers. 9. To maintain the ambient temperature in the radwaste area between 65F and 104F, coincident with outdoor design temperatures.

10. To decrease the likelihood of the spread of airborne radioactivity within the auxiliary building by supplying air only to clean areas.

11. To maintain a slightly negative pressure within the auxiliary building and radwaste area by exhausting at

a rate higher than the supply air rate.

12. To maintain air flow paths from areas with a lesser potential for contamination into areas with a greater potential for contamination.

13. The normal flow portions of the auxiliary building and radwaste area ventilation system is NNS class, although the distribution ductwork is additionally supported to withstand seismic forces.

14. To maintain an inward velocity of ventilation air to the shielded cubicle entrances.

15. To prevent area overpressurization from a full CO system discharge if required for fire suppression.

9.4.3.2 System Description

The principal component and design parameters of the auxiliary building ventilation system are given in Table 9.4-7. The air supply portion of the auxiliary building ventilation system includes two 50 percent capacity, 28,200 cfm each, air handling units.

BVPS-2 UFSAR Rev. 14 9.4-14 Each air handling unit includes a preheat coil using hot water as the heating medium, a cooling coil using chilled water (Section 9.2.2.2) as the cooling medium, a reheat coil using hot water as heating medium, and a motor-driven fan. Air is supplied to all levels and to the containment through ductwork. The system is designed on a once-through basis, with the exception that 8,200 cfm of air is recirculated from the auxiliary building equipment room. One air handling unit is used to supply conditioned air for purging the reactor containment when required, as described in Section 9.4.7.3.

The two filter exhaust fans of the SLCRS (Section 6.5.3.2) are used to exhaust the air. Air is exhausted at a rate higher than the supply to maintain the buildings under negative pressure. Exhaust air is continuously filtered in the main filter banks of the SLCRS prior to discharge to the atmosphere through the

elevated release. Where clean areas are adjacent to potentially contaminated areas, air is supplied to the clean areas and exhausted from the potentially contaminated areas to decrease the possibility of any spread of contamination.

Smoke detectors, located in the supply air ductwork downstream of the air-conditioning units, alarm locally and annunciate in

the control room. As described in Section 6.5.3.2.1, an emergency safety-related exhaust fan system consisting of two axial flow exhaust fans, ducting, and dampers, provides ventilation for the charging pump cubicles and component cooling water pumps general area (Figure

9.4-4) in the event of a failure of the credited Supplemental Leak Collection and Release System (SLCRS). During this period, air enters the auxiliary building through the air intake plenum and then into the charging pump cubicles and component cooling water pumps area. Provisions have been made in the ductwork for the addition of portable radiation monitors to monitor exhaust

from the emergency safety-related exhaust fan system. Recirculation fans and service water cooling coils are provided

for each of two redundant MCCs located in the enclosure at el 755 ft-6 in of the auxiliary building. Fans and coils are shown on Figure 9.4-12 and equipment parameters are listed in

Table 9.4-7. Additional cooling is provided in the air ejector and charcoal

delay beds cubicles by reci rculation air fans and chilled water coils. Equipment parameters are listed in Table 9.4-7. In addition, smoke detectors are located in recirculation ductwork which alarm locally and annunciate in the control room upon detection of smoke in the air ejector and charcoal delay beds.

The auxiliary building elevator machinery room is cooled by an exhaust fan with an associated automatically operated, fresh air inlet damper. Fan parameters are listed in Table 9.4-7. BVPS-2 UFSAR Rev. 12 9.4-14a An air-conditioning system, consisting of a self-contained air-conditioning unit and associated ductwork and registers, cools the post-accident sampling system cubicle at El 735'-6" of the auxiliary building. Equipment parameters are listed in Table 9.4-7. The radwaste area ventilation system consists of an air supply that comes from the auxiliary building ventilation system air handling units. The air supply ductwork includes a hot water heating coil for heating the building.

9.4.3.3 Safety Evaluation

Air from the auxiliary building and radwaste area is exhausted through the safety-related, redundant filters of the SLCRS. This reduces the potential for radioactively contaminated air

being released to the atmosphere.

BVPS-2 UFSAR Rev. 12 9.4-15 The motor-operated interface dampers between the auxiliary building and radwaste area ventilation system and SLCRS are Category I safety-related dampers (Figure 9.4-4). These dampers are part of the SLCRS and are described in Section 6.5.3.2. The supply and exhaust ductwork of the auxiliary building portion of the ventilation system is designed to withstand seismic forces, and the operation of safety-related equipment will not be affected by ductwork during the postulated seismic events. The radwaste area ventilation system meets the criteria for a NNS class system in Regulatory Guide 1.26 since it does not

perform a safety function. Its failure will not cause any safety-related system to fail. The system is designed to provide a controlled environment for personnel access and

equipment operation. Concentrations of airborne particulate and noble gases are

continually sampled and analyzed by a radiation monitoring system. A FMEA to determine if the I&C and electrical portions meet the single failure criterion, and to demonstrate and verify how the GDC and IEEE Standard 279 1971 requirements are satisfied, has been performed on the auxiliary building and radwaste area ventilation system. The FMEA methodology is discussed in Section 7.3.2. The results of this analysis can be found in the

separate FMEA document (Section 1.7). 9.4.3.4 Inspection and Testing Requirements

The auxiliary building ventilation system is inspected after installation to ensure that the equipment is properly installed

and operates correctly. The system is tested and balanced after installation. The system is in continuous operation and, as such, periodic inspection is not required. Preliminary tests

are performed as described in Section 14.2.12. 9.4.3.5 Instrumentation Requirements

The auxiliary building ventilation system air handling units are controlled from the main control room via individual control

switches with appropriate indicating lights. Pneumatic temperature controllers and a flow controller maintain the control point for the preheat coils, cooling coils, hot water control valves, reheat coils, and an air-operated vane damper. Local flow, pressure differential, and temperature indicators are provided for monitoring of the auxiliary building ventilation system.

BVPS-2 UFSAR Rev. 13 9.4-16 Annunciator displays, with associated BVPS-2 computer inputs, are actuated in the main control room for air-handling unit auto-trip, high air flow, no air flow, and high discharge temperature, preheat coil low temperature, prefilter high

differential pressure, and loss of instrument air supply. Flow indicators, mounted locally and in the main control room, are provided for monitoring of the auxiliary building emergency exhaust system.

Annunciator displays, with the associated BVPS-2 computer inputs, are actuated in the main control room for auxiliary building emergency exhaust fans motor overload and charging pump

cubicle and component cooling water pump area low air flow. A temperature controller, installed in the radwaste area, automatically modulates a hot water control valve to maintain the desired space temperature.

Local flow and temperature indicators are provided for monitoring of the waste handling building air system.

The radwaste area motor-operated exhaust dampers and the emergency exhaust fans are controlled from the main control room via individual control switches, with appropriate indicating

lights. 9.4.4 Turbine Building Area Ventilation System

The turbine building area ventilation system removes heat dissipated by equipment, piping, lighting, and solar heat gains, and maintains an environment suitable for personnel access and equipment operation in the turbine building. The system uses outside air as the cooling medium.

The turbine, service, and auxiliary building walkway system ensures a safe means of egress from plant areas.

The system is nonsafety-related and is designated NNS class.

9.4.4.1 Design Bases The design bases of the turbine building ventilation system are

as follows:

1. General Design Criterion 2, as it relates to the system being capable of withstanding the effects of

natural phenomena, as established in Chapters 2 and 3.

2. General Design Criterion 5, as it relates to shared systems. No portion of the turbine building area

ventilation system is shared.

BVPS-2 UFSAR Rev. 0 9.4-17 3. Regulatory Guide 1.26, as it relates to the quality group classification of system components.

4. Regulatory Guide 1.29, as it relates to the seismic design classification of systems and components. The

turbine building area ventilation system is

nonseismic.

5. During the summer, to maintain the turbine building temperature range from 103F at the operating floor to 11OF just below the roof in unoccupied areas, coincident with outdoor design temperatures. During the winter, to maintain the indoor temperature at a minimum of 60F, coincident with outdoor design temperatures.

6. General Design Criterion 60 does not apply since provisions are made to prevent airborne radioactivity from entering the turbine building environment (vents from the air ejector condensers and the gland exhaust condensers are hard piped from the turbine building and monitored before discharge to the environment) and valve stem leakoff collection is provided for valve stems. 7. Positive pressure in the turbine, service, and auxiliary building walkway spaces is provided to ensure a safe egress for personnel in the event of

smoke conditions.

9.4.4.2 System Description

The turbine building area ventilation system is shown on Figure 9.4-7 and the principal components and design parameters are listed in Table 9.4-8. The supply portion of the system consists of two axial flow supply fans (125,000 cfm each), associated ductwork, and nine banks of paired wall intake air dampers (total 18). Each fan supplies outside air, or a mixture of outside air and

recirculated air, to maintain the designated system exit air temperature of 65 F. The supply fans are located on the north wall of the turbine building. The ventilation supply air is distributed through ductwork to

all levels of the turbine building. In addition, there are two propeller-type recirculation fans to

provide mixing of the air to create a more uniform temperature in the building.

The exhaust portion of the system consists of ten exhaust fans located on the turbine building roof, one exhaust fan in the elevator machinery room, one exhaust fan in the toilet room, and one exhaust fan in the battery room. Each of nine exhaust fans of the ten roof exhaust fans has two air intake dampers associated with it which open when the associated fan starts and

close when the fan stops. The BVPS-2 UFSAR Rev. 0 9.4-18 The remaining roof exhaust fan is used for building depressurization and has no associated intake damper. Hot water unit heaters are provided to maintain the turbine building at an ambient temperature of 60F during plant shutdown or as required during plant operation, coincident with the outside winter design temperature. The turbine, service, and auxiliary building walkway is

ventilated by supply and exhaust fans for smoke removal. The supply fan is of greater capacity than the exhaust fan to provide positive pressure in the walkway, and to prevent

infiltration of smoke from adjacent areas. A fire damper is located adjacent to the supply fan in the turbine building wall to maintain the integrity of the fire barrier boundary.

9.4.4.3 Safety Evaluation

The ventilation system for the turbine building and turbine, service, and auxiliary building walkway does not have safety-related functions and its failure will not compromise other

safety-related systems within the turbine building. 9.4.4.4 Inspection and Testing Requirements

The system is inspected after installation to ensure that the equipment is properly installed and operates correctly. The system is tested and balanced after installation. Preliminary tests are performed as described in Section 14.2.12.

The system is in continuous operation and, as such, periodic inspection is not required.

9.4.4.5 Instrumentation Requirements Control switches with indicating lights for the turbine building ventilation supply fans and the turbine building power roof ventilators are provided on a local ventilation control panel.

Selector switches for the ventilation louvers and control switches with indicating lights for the turbine building recirculation air fans are also provided on this local

ventilation control panel. A local control switch and thermostat are provided for the elevator machinery room exhaust fan located within the elevator machinery room.

The turbine building ventilation system provides outdoor air as required for cooling, and recirculation of air to maintain the space ambient temperature required to ensure proper operation of

equipment and controls during normal plant operations.

BVPS-2 UFSAR Rev. 0 9.4-18a When a ventilation supply fan is started, a solenoid air valve is energized to allow signal air to pass from a receiver controller to

BVPS-2 UFSAR Rev. 0 9.4-19 the outdoor air and return air damper actuators. As the temperature rises above the set point of the receiver controller, the outdoor air damper will modulate open and the return damper will modulate close as required to maintain desired unit discharge temperature. When the discharge temperature drops below the set point, the reverse will occur.

Indication on the local ventilation control panel is provided for discharge air temperature. Main control room annunciation is provided for a loss of air flow from the turbine building battery room and this annunciation is also monitored by the BVPS-2 computer system.

9.4.5 Engineered

Safety Features Ventilation Systems The engineered safety features ventilation systems (ESFVS)

ventilate various areas of BVPS-2 that house ESF equipment. The ventilation systems use outdoor air or service water, or a combination of outdoor air and service water, cooling to provide a suitable and controlled environment for personnel and equipment, with maximum safety against the spread of radioactive contamination. An exhaust system for these areas is provided by

the SLCRS described in Section 6.5.3. 9.4.5.1 Design Bases

The design bases for the various systems that comprise the ESFVS are described in their respective sections, as listed in Section

9.4.5.2. 9.4.5.2 Systems Description

The ESFVS is comprised of the emergency diesel generator ventilation system (Section 9.4.6), the intake structure

ventilation system (Section 9.4.8), the main steam and feedwater valve area ventilation system (Section 9.4.9), the battery room ventilation system (Section 9.4.10.2), the emergency switchgear ventilation system (Section 9.4.10.3), the safeguards area ventilation system (Section 9.4.11), the cable vault and rod control area ventilation system (Section 9.4.12), and the fission product removal and control system (Section 6.5). The system descriptions of these ESFVS are described in detail in the aforementioned sections.

9.4.5.3 Safety Evaluation

Safety evaluations for the systems that comprise the ESFVS are described in their respective sections, as listed in Section 9.4.5.2. 9.4.5.4 Inspection and Testing Requirements

Inspection and testing requirements that apply to each of the ESFVS are described in their respective sections, as listed in Section 9.4.5.2.

BVPS-2 UFSAR Rev. 0 9.4-20 9.4.5.5 Instrumentation Requirements Instrumentation and controls applicable to the systems that comprise the ESFVS are described in their respective sections, as listed in Section 9.4.5.2.

9.4.6 Emergency

Diesel Generator Building Ventilation System

The emergency diesel generator building ventilation system removes heat dissipated into the building from the equipment, lighting, and environment to maintain conditions suitable for personnel access and equipment operation during normal and post-accident conditions.

9.4.6.1 Design Bases

The emergency diesel generator building ventilation system is a safety-related system and is designed in accordance with the following criteria:

1. General Design Criterion 2, as it relates to the system being capable of withstanding the effects of

natural phenomena such as earthquakes, tornadoes, hurricanes, and floods, as established in Chapters 2 and 3. 2. General Design Criterion 4, as it relates to the system being capable of withstanding the effects of external missiles and internally-generated missiles, pipe whip, and jet impingement forces associated with pipe breaks.

3. General Design Criterion 5, in that no systems or system components important to safety are shared.

4. General Design Criterion 17, as it relates to power being available to the emergency diesel generator ventilation system in the event of loss of offsite power (LOOP).

5. Regulatory Guide 1.26, as it relates to the quality group classification of the equipment.

6. Regulatory Guide 1.29, as it relates to the seismic design classification of the equipment.

7. No high or moderate energy line breaks are anticipated to occur in the diesel generator building.

8. Each emergency diesel generator room is maintained below 122F when its emergency diesel generator is operating. When the emergency diesel generators are not operating, each room is maintained below 104F in the summer and above 60F in the winter, coincident with outdoor design temperatures.

BVPS-2 UFSAR Rev. 0 9.4-20a 9. It meets the single failure criterion in that a failure in the emergency diesel generator ventilation system in one

BVPS-2 UFSAR Rev. 12 9.4-21 emergency diesel generator room does not affect the ventilation system in the other diesel generator room. 9.4.6.2 System Description

The emergency diesel generator building ventilation system is shown on Figure 9.4-8. The principal components and design parameters are given in Table 9.4-9. There are two adjacent, totally independent, emergency diesel

generator rooms. Each room has an independent ventilation system, consisting of a normal exhaust fan, a primary supply

fan, and a secondary supply fan.

The normal exhaust fan maintains minimum ventilation in the room, when the emergency diesel generator is not operating, in order to remove heat gains from transmission and lighting sources. The normal exhaust fan also prevents the accumulation of gases or fuel-vapor mixtures within the emergency diesel

generator room. The normal exhaust fan is provided with Class 1E power and will run in conjunction with the primary and secondary supply fans.

Each normal exhaust fan exhausts through backdraft dampers. Air enters the room by infiltration. Heating is provided by electric unit heaters in order to maintain a 60F ambient temperature for personnel comfort. The electric unit heaters are QA Category III, are seismically supported, but are not seismically designed.

The primary supply fan automatically starts when its associated emergency diesel generator starts up. The secondary supply fan will run in parallel with the primary supply fan, and will

operate when needed to supplement the primary supply fan. In the event that CO is being discharged into the emergency diesel generator room, the associated primary supply fan will not start and the normal exhaust fan will shut off. The primary and secondary supply fans remove heat dissipated from the diesel engine, engine exhaust system, generator, lighting sources, solar transmission, and other miscellaneous heat gains into the diesel generator space whenever the emergency diesel generator is operating. Each primary supply fan is accompanied by seismically supported, motorized, outdoor air and return air dampers, supply air ductwork, and control instrumentation. Each secondary supply fan is also accompanied by ductwork and control instrumentation. The intake and exhaust openings are missile-protected.

The diesel engine combustion air intake pipes and exhaust muffler pipes are independent of the emergency diesel generator

building ventilation system.

BVPS-2 UFSAR Rev. 0 9.4-22 9.4.6.3 Safety Evaluation The emergency diesel generator building ventilation system maintains an ambient temperature suitable for personnel and equipment. The ventilation system is designed so that the temperature in each diesel generator room does not exceed 122 F when the diesel generator is operating. Operation of the primary and secondary supply fans, normal

exhaust fans, and associated motorized dampers is maintained during loss of normal station power by automatic connection to

the emergency buses.

An independent ventilation system is provided for each emergency diesel generator room in compliance with the single failure criterion. Failure of one independent ventilation system will not compromise operation of the other independent ventilation system. The independent ventilation system for each emergency diesel generator room and the related intake and exhaust dampers are

designed as Safety Class 3, Seismic Category I, and QA Category I. A FMEA to determine if the I&C and electrical portions meet the single failure criterion, and to demonstrate and verify how the GDC and IEEE Standard 279-1971 requirements are satisfied, has been performed on the emergency diesel generator building ventilation system. The FMEA methodology is discussed in Section 7.3.2. The results of this analysis can be found in the

separate FMEA document (Section 1.7). 9.4.6.4 Inspection and Testing Requirements

The system is inspected after installation to ensure that the equipment is properly installed and operates correctly. The system is tested and balanced after installation. Periodic operating of the system in conjunction with routine observation and maintenance during operation ensures system availability.

The normal exhaust ventilation system is in continuous operation and periodic inspection is not required. Preliminary tests are performed as described in Section 14.2.12.

9.4.6.5 Instrumentation Requirements

Each emergency diesel generator room normal exhaust fan is controlled locally via individual control switches with indicating lights. The exhaust fans run continuously in the automatic mode or manual mode provided no fire generator high temperature exists in the associated room.

Each emergency diesel generator room primary supply fan is controlled from the main control room via individual control switches with indicating lights. The supply fan will

automatically start with its

BVPS-2 UFSAR Rev. 20 9.4-23 associated diesel generator start-up, provided no fire generated high temperature exists in the room associated.

Each emergency diesel generator room secondary supply fan is

electrically interlocked with its primary supply fan, and is thermostatically controlled locally and from the main control room via individual control switches with indicating lights. The secondary supply fan will operate provided no fire generated

high temperature exists in the room.

Air is supplied to the secondary supply fan from the mixed air

plenum of the primary supply fan. The fan is automatically controlled and is started by a room thermostat set below 122 to prevent the ambient air temperature of the space from exceeding its setting.

Whenever an emergency diesel generator room primary supply fan starts, its associated exhaust air damper will open fully, and the outdoor air and return air dampers will be modulated via a temperature controller located in the discharge air duct. When the supply fan stops, its associated exhaust and outdoor air

dampers will close, and the return air damper will be fully

opened. A computer point will be energized whenever the exhaust

air damper is fully closed.

Annunciation is provided in the main control room for each

supply fan motor thermal overload, and each emergency diesel generator room high and low temperatures. The previous

conditions are also monitored by the BVPS 2 computer.

Unit heaters are provided in the emergency diesel generator

rooms and are controlled by wall-mounted thermostats to maintain

a predetermined temperature in the area.

9.4.7 Containment

Ventilation System

The containment ventilation systems are comprised of the following three systems: containment atmosphere recirculation system, containment purge air system, and control rod drive mechanism ventilation system.

9.4.7.1 Containment Atmosphere Recirculation System

The containment atmosphere recirculation system portion of the

containment ventilation systems is designed to maintain the bulk air temperature in the containment suitable for personnel and equipment operation during normal plant operation. The system

is nonsafety-related and is designated NNS class.

BVPS-2 UFSAR Rev. 19 9.4-24 9.4.7.1.1 Design Basis

The design basis of the containment atmosphere recirculation

system is in accordance with the following criterion: To limit the containment bulk air temperature to 108 F during normal operation.

Performance characteristics of the containment atmosphere

recirculation system are given in Table 9.4-10.

9.4.7.1.2 System Description

The containment atmosphere recirculation system is shown on

Figure 9.4-9. The principal components and design parameters are listed in Table 9.4-11. The containment atmosphere recirculation system consists of three 50-percent capacity atmosphere recirculation unit coolers with air distribution

ductwork. Each unit cooler consists of a motor-driven fan and

cooling coils.

Two of the three atmosphere recirculation unit coolers function during normal operation. Air is drawn by the fan over the respective unit's cooling coils and then is discharged into, and distributed through, ductwork to the containment levels. Self-acting backdraft dampers are installed at the discharge of each

fan to prevent reverse flow through an idle fan.

The cooling coils in each recirculation unit cooler assembly are served by a chilled water system (Section 9.2.2) during normal

plant operation.

The electrical power is supplied from redundant emergency buses and is de-energized during an SI signal initiation, as described

in Section 8.3.

BVPS-2 UFSAR Rev. 18 9.4-24a 9.4.7.1.3 Safety Evaluation

Two of the three containment atmosphere recirculation unit coolers are required to limit the containment bulk air

temperature to 108 F during normal operation.

BVPS-2 UFSAR Rev. 16 9.4-25 With loss of all cooling water, such as a LOOP, containment bulk temperature will not exceed 135 degrees F.

The containment atmosphere recirculation fans are NNS class, Seismic Category 2, and are provided with Class 1E power. The containment atmosphere recirculation system cooling coils are Non-Nuclear Safety, Seismic Class 2. The system components and ductwork are designed to Seismic Category I requirements. The containment atmosphere recirculation system is not required to operate during accident conditions.

The fans are stopped automatically by an SI signal and a high containment water level signal to protect the integrity of the emergency power source. The fan high-high vibration signal will trip the fan but is not required to protect the integrity of the emergency power source.

9.4.7.1.4 Inspection and Testing Requirements

The system is inspected after installation to ensure that the equipment is properly installed and operated correctly. The system is tested and balanced after installation.

Preliminary tests are performed as described in Section 14.2.12.

9.4.7.1.5 Instrumentation Requirements Control switches with indicating lights for the containment air

recirculation fans are provided in the main control room and on the emergency shutdown panel. Control of the fans is similar from both locations. Two of the three fans are running during

normal plant operation. The containment air recirculation fans are capable of being

started manually in the event of a loss of plant power. The fans are stopped automatically by an SI signal, a high containment water level, or a containment air recirculation fan

high-high vibration signal. The third (swing) fan can be racked into either emergency bus if one of the other two fans is out of service. Cooling water for the containment air recirculation fans cooling coils is provided by the chilled water system during normal operation.

The containment air recirculation cooling coils outlet flow and temperature are monitored by means of indicators in the main control room. Containment air recirculation fans auto stop is

annunciated in the main control room and is also monitored by the plant computer.

The fan's vibration is monitored in the main control room by means of an indicator. High vibration is annunciated in the main control room and is also monitored by the plant computer.

BVPS-2 UFSAR Rev. 17 9.4-26 9.4.7.2 Deleted

BVPS-2 UFSAR Rev. 17 9.4-27 9.4.7.3 Containment Purge Air System The containment purge air system is designed to reduce the airborne radioactivity in the containment after the plant has

reached cold shutdown, and to provide outdoor air during extended periods of occupancy such as during refueling, when the containment may be maintained at a slightly negative pressure.

9.4.7.3.1 Design Bases

The design bases for the containment purge air system are the following:

1. The capacity of the containment purge air system provides approximately one change of containment free air volume every hour. Section 12.3.3 discusses

activity levels in the containment following a purge of 8 hours.

2. The containment purge air is supplied at a rate consistent with reducing airborne activity to as low

as reasonably achievable.

3. The containment purge supply air is heated or cooled as required.

4. The containment penetrations, the containment isolation valves, and the piping between the valves are Safety Class 2. The remainder of the system is NNS class. The ductwork within the containment building is seismically supported.

5. During refueling, the exhaust air flow may be reduced as indicated in Table 6.5-8.

9.4.7.3.2 System Description

The containment purge air system is shown on Figure 9.4-9. The performance characteristics are pr ovided in Tables 9.4-7 and 6.5-7. The containment purge air system consists of supply and

exhaust air subsystems. An outdoor air pressure-equalizing line with a manually-operated valve is provided between the isolation valve outside the containment on the purge supply line and its containment penetration. This line is used to bring the containment to atmospheric pressure prior to purging. The purge system is actuated manually after containment is at atmospheric pressure.

The purge air is supplied from one of the auxiliary building air-conditioning units, as described in Section 9.4.3.2.

Purge exhaust is provided by the SLCRS, as described in Section 6.5.3.2. The exhaust fans have the capacity to handle approximately one containment air change per hour maintaining

the containment under a slightly negative pressure.

BVPS-2 UFSAR Rev. 17 9.4-28 The purge exhaust can be manually routed through filter units of the SLCRS ensuring that no radioactivity beyond allowable limits is released to the atmosphere.

A containment airborne monitor provides the plant operators with a high radioactivity alarm. Upon receipt of an alarm the purge exhaust can be manually rerouted through SLCRS filters. Monitors are provided in the purge exhaust ductwork which may be configured to automatically close the containment purge

isolation valves upon detection of high radioactivity in the airstream.

Supply and exhaust ductwork are provided with containment butterfly isolation valves. During normal operation of the plant, the purge supply circuit is inoperative and the isolation valves are closed. Provisions are also made to direct a small quantity of the exhaust air to the BVPS-1 process vent filters and gaseous waste blowers for discharge at the top of the

cooling tower, as described in Section 11.3.2.4. 9.4.7.3.3 Safety Evaluation

The isolation valves are closed during normal containment operation.

Mechanical locking devices are provided to prevent an inadvertent opening of these containment isolation valves.

To control discharge of radioactive air to the outside atmosphere, during operation with the containment at atmospheric

pressure, air in the containment and in the purge exhaust duct is monitored for radioactivity. High radiation in the containment atmosphere initiates an alarm in the main control room. The operator, upon receipt of the alarm, can reroute the purge exhaust from normal to filtered exhaust and elevated release. Detection of high radioactivity in the purge exhaust airstream may automatically close the containment purge isolation valves.

During refueling activities in the containment, the purge may be routed through the filtered leak collection exhaust at reduced air flow rate as indicated in Table 6.5-8. This system is not required to operate during accident conditions.

9.4.7.3.4 Inspection and Testing Requirements

The containment isolation valves for the containment purge air system are tested for air-tightness as part of the containment leak testing program (Chapter 16).

The system is inspected after installation to ensure that the equipment is properly installed and operates correctly. The system is tested and balanced after installation. System components are periodically tested to insure system operation.

BVPS-2 UFSAR Rev. 17 9.4-29 9.4.7.3.5 Instrumentation Requirements A control switch with indicating lights is provided for the leak collection normal exhaust fan on the building service control panel located in the main control room. This exhaust fan exhausts air from the containment to the atmosphere, maintaining a slightly negative pressure during the purge and refueling activity.

A two-position control switch with indicating lights is provided on the building service control panel for the motor-operated containment diverting dampers which divert supply air from the auxiliary building to the containment. A three-position selector switch with indicating lights is

provided on the building service control panel for the motor-operated containment diverting dampers which divert exhaust air to the leak collection normal exhaust or filtered exhaust.

Indicating lights are provided on the building service panel for the following manually-operated containment dampers: The damper (ball valve) located outside the containment on the pressure-equalizing line, which will be opened before initial purging starts; the dampers located inside the containment on the

exhaust line, which will be closed during refueling to allow a small amount of air to be exhausted after being monitored for radiation.

Redundant radiation monitors are located in the containment exhaust ductwork. Upon detecting a predetermined high level of

radiation during purging the motor-operated containment isolation valves may be configured to automatically close and the leak collection normal exhaust fan will stop running.

During refueling activities in the containment, the purge may be directed to the SLCRS filtered exhaust, and the normal exhaust

fan will be isolated. Upon detection of a predetermined high level of radiation, the containment isolation valves may be configured to automatically close.

Control switches with indicating lights are provided on the building service control panel to indicate valve position for

each of the motor-operated containment isolation valves. Air flow indication is provided in the main control room.

Annunciation is provided in the main control room for reactor containment radiation high, reactor containment radiation high-

high, and leak collection normal exhaust fan trip. These are also monitored by the plant computer system.

BVPS-2 UFSAR Rev. 17 9.4-30 9.4.7.4 Control Rod Drive Mechanism Ventilation System The control rod drive mechanism (CRDM) ventilation system is a forced air cooling system that provides for the removal of heat from the CRDM magnetic jack coil windings during normal operation.

The system is designated as NNS class. 9.4.7.4.1 Design Bases

The CRDM ventilation system is designed in accordance with the following criteria:

1. The CRDM ventilation system will maintain the temperature of the stationary and movable grippers and lift coil wiring insulation below 392F during normal reactor operation.

2. The CRDM ventilation system has the capability of supplying a minimum air flow of 66,000 scfm cooling air when the normal power supply is interrupted and the reactor is to be maintained at hot standby.

3. General Design Criterion 2, as it relates to structures housing the system and the system itself

being capable of withstanding the effects of natural

phenomena such as earthquakes, tornadoes, hurricanes, and floods, as established in Chapters 2 and 3.

4. General Design Criterion 4, with respect to structures housing the system and the system itself being capable

of withstanding the effects of external missiles and

internally-generated missiles, pipe whip, and jet impingement forces associated with pipe breaks.

5. Regulatory Guide 1.29, as it relates to the seismic design classification of system components. This system is designated as Seismic Category I. The CRDM

ventilation system fans are Seismic Category II.

9.4.7.4.2 System Description

The CRDM ventilation system is a forced air cooling system that provides a reliable supply of cooling air to the CRDM magnetic

jack coil windings during normal reactor operation. Cooling is provided by three ventilation subsystems, each with

two 33-percent design capacity fans. The CRDM ventilation system fans draw containment ambient air through the CRDM shroud and detachable ductwork. The six CRDM ventilation system fans

discharge the air that is drawn from the CRDM shroud, through coils that are cooled by the primary component cooling water (CCW) system and through gravity dampers before discharging to the containment atmosphere. All six fans are provided with Class 1E power and are de-energized during an SI.

BVPS-2 UFSAR Rev. 17 9.4-31 The CRDM ventilation system fans can be manually started from the main control room during all modes of plant operation except an SI. The CRDM ventilation system is shown on Figure 9.4-9 and its performance characteristics are provided in Table 9.4-13. 9.4.7.4.3 Safety Evaluation

During normal operation, three fans, one from each of the three ventilation subsystems, will be operating to supply a total of 66,000 scfm airflow through the CRDM coil area. The remaining

three fans are standby units which can be started manually from the main control room or automatically upon failure of an associated fan.

The CRDM ventilation system fans are NNS class, Seismic Category II, and are provided with Class 1E power. The CRDM ventilation system cooling coils are Safety Class 3, Seismic Class 1, and are provided with cooling water from the primary CCW system, as described in Section 9.2.2.1. The system

components and ductwork are Seismic Category 1. The CRDM ventilation system fans and coils are not required to

operate during a DBA. On a loss of power and a safety injection (SI) signal, the CRDM ventilation system fans are disconnected from the Class 1E power supply. The CRDM ventilation system fans may then be started manually, with power supplied from the Class 1E power supply, providing the following conditions are met:

1. Manual reset of SI signal, 2. Emergency diesel generator is operating properly, and

3. Emergency diesel generator is capable of accepting the electrical load.

It is considered highly unlikely that a complete loss of CRDM cooling could occur because of the system design and use of multiple fans. In the unlikely event of a complete loss of CRDM

cooling air, a loss of insulation life to CRDM magnetic coil windings will occur when the reactor is at operating temperature. Continuous overheating will result in shorting of the coil windings and tripping of the rods. This is not a safety-related problem since the rod will trip and shut down the reactor.

BVPS-2 UFSAR Rev. 17 9.4-32 9.4.7.4.4 Inspection and Testing Requirements The CRDM system is inspected after installation to ensure that the equipment is properly installed and operates correctly. The system is tested and balanced after installation. Preliminary tests are performed as described in Section 14.3.12.

The system is in continuous operation and, as such, periodic inspection is not required.

9.4.7.4.5 Instrumentation Requirements Control switches with indicating lights are provided for the CRDM ventilation system fans on the building services control panel in the main control room.

Selector switches with indicating lights are provided in the main control room for operation of the CRDM cooling coils cooling water inlet valves.

A control switch with indicating lights is provided in the MCC for operation of the CRDM cooling coils cooling water isolation

valve. Indicating lights are provided in the main control room for indication of CRDM cooling coils cooling water isolation valve position.

CRDM shroud fan coil inlet and outlet air temperatures are monitored by the plant computer system.

Alarms are provided on the building services control panel to indicate automatic start or stop of the CRDM shroud fans and

these alarms are also monitored by the plant computer.

9.4.8 Intake

Structure Ventilation System

The intake structure ventilation system consists of two subsystems: the primary intake structure ventilation system and

the alternate intake structure ventilation system. 9.4.8.1 Primary Intake Structure Ventilation System

The primary intake structure ventilation system provides an environment suitable for personnel access and equipment

operation during both normal and accident conditions. The system is safety-related and is designated Safety Class 3.

9.4.8.1.1 Design Bases The design of the primary intake structure ventilation system is

in accordance with the following criteria:

BVPS-2 UFSAR Rev. 17 9.4-33 1. General Design Criterion 2, as it relates to the system being capable of withstanding the effects of natural phenomena such as earthquakes, tornadoes, hurricanes, and floods, as established in Chapters 2

and 3.

2. General Design Criterion 4, as it relates to the system being capable of withstanding the effects of external missiles and internally-generated missiles, pipe whip, and jet impingement forces associated with

pipe breaks.

3. General Design Criterion 5, in that no systems or system components are shared except the common structure.

4. General Design Criterion 17, as it relates to assuring proper functioning of the essential electric power

system. 5. Regulatory Guide 1.117, as it relates to the protection of structures, systems, and components important to safety from the effects of tornado missiles.

6. Regulatory Guide 1.26, as it relates to the quality group classification of system components. This system is classified as QA Category I, Safety Class 3 with the exception of the electric unit heaters which are classified QA Category II, Safety Class NNS.

7. Regulatory Guide 1.29, as it relates to the seismic design classification of system components. This

system is classified as Seismic Category I.

8. Branch Technical Positions ASB 3 1 and MEB 3 1, as they relate to postulated breaks and failures in high and moderate energy piping systems outside the reactor containment.

9. Branch Technical Position CMEB 9.5-1, as it relates to the capability of the system to remove smoke.

10. The ambient temperature in the structure is maintained above 55F during the winter by electric unit heaters and below 115F during the summer, by a forced air ventilation system.

11. The primary intake structure ventilation system is safety-related and Seismic Category I, except for the unit heaters. The unit heaters, which are nonsafety-related nor seismically designed, are held in place by seismically designed supports so they do not interfere with the operation of other safety-related items

during a seismic event.

BVPS-2 UFSAR Rev. 17 9.4-34 9.4.8.1.2 System Description The primary intake structure ventilation system is shown on Figure 9.4-11, and the principal components and design parameters are given in Table 9.4-14. The intake structure is common to both BVPS-1 and BVPS-2. All BVPS-2 ventilation system active components will run independently of BVPS-1 components.

There are three separate, independent, and redundant intake pump cubicles utilized for BVPS-2, each with its own cubicle housingand ventilation system. Thus, the failure of one system

will not interfere with the operation of the others. The primary intake structure ventilation system consists of

three axial flow, 7,500 cfm capacity ventilating fans, three outdoor air intake dampers, and three roof vents. Air is exhausted through roof vents provided with gravity-type dampers.

These vents are also used for smoke removal. Outdoor air is introduced through a tornado missile-protected

opening with motor-operated damper and discharged into the structure by a supply fan.

Exhaust and intake openings are provided with missile hoods. Three roof vents with self-acting backdrop dampers are provided for the relief of static pressure in the building.

Heating is provided to the intake structure to maintain space temperature above 55F. Heating of the intake structure is not safety-related or seismically designed. The unit heaters are

seismically supported to prevent damage to safety-related

equipment. The electric unit heaters are connected to BVPS-1 nonsafety-related motor control centers and are controlled automatically by room thermostats. The electric heaters start on falling temperature and maintain the temperature by recirculating the

room air. During normal conditions, the fans are in the auto control mode. In the cubicles for pumps 2SWS*P21A and B, an increase in room temperature above the setting of the corresponding room thermostat will open the outdoor air damper. This will cause

the supply fan to start, allowing the cubicle to be ventilated with outdoor air. In the cubicle for pump 2SWS*P21C, an increase in space temperature above the setting of the room

thermostat will start the supply fan. This will cause the outdoor air damper to open, allowing the cubicle to be ventilated with outdoor air.

BVPS-2 UFSAR Rev. 17 9.4-35 9.4.8.1.3 Safety Evaluation The temperature in the pump cubicles is maintained within the design limits of safety related equipment in the cubicles for accident conditions (which bound normal operating conditions).

Maximum design limits are based on a service water pump winding

temperature of 266 F (nominal 122 F ambient). The minimum design limit is based on the temperature at which service water pump grease will flow adequately (20 F for typical lubricants). Power is supplied to the ventilation system by the respective emergency bus supplying the associated service water pump, as described in Chapter 8. Two fans are powered from separate emergency power sources. The third fan has the capability of

being powered from either emergency power source. The ventilation system for the intake structure pump cubicle is Safety Class 3, QA Category I, and Seismic Category I except for the electric unit heaters, which are QA Category III and seismically supported, but not seismically designed.

There are three separate and redundant intake pump structure cubicles utilized for BVPS-2, each with its own ventilation system. The failure of one system will not interfere with the safe shutdown of the plant, and therefore meets the requirements of single failure criterion.

A FMEA to determine if the I&C and electric portions meet the single failure criterion, and to demonstrate and verify how the GDC and IEEE Standard 279-1971 requirements are satisfied, has been performed on the primary intake structure ventilation system. The FMEA methodology is discussed in Section 7.3.2. The results of this analysis can be found in the separate FMEA document (Section 1.7).

9.4.8.1.4 Inspection and Testing Requirements The primary intake structure ventilation system is inspected

after installation to ensure that the equipment is properly installed. The system is tested and balanced after installation. Preliminary tests are performed as described in Section 14.2.12.

Periodic operations of the system in conjunction with routine observation and maintenance during operation ensure system

availability. 9.4.8.1.5 Instrumentation Requirements

Control switches with indicating lights are provided locally in each cubicle, one switch each for the two separate source powered ventilation fans, and two switches for the third ventilation fan, which can be powered from either power source.

BVPS-2 UFSAR Rev. 17 9.4-36 Temperature switches with adjustable settings are provided for automatic operation of the pump cubicle ventilation fans, and outdoor air supply dampers. These temperature switches are

mounted locally. Automatic trip of the ventilation fans, and high and low cubicle

temperatures, are monitored by the BVPS-2 computer system. Alarms are provided on the building services control panel that

annunciate on an automatic trip of any of the ventilation fans and/or on a high or low cubicle temperature.

BVPS-2 UFSAR Rev. 0 9.4-37 A locally mounted power transfer switch is provided to transfer control of one of the ventilation fans, which can be powered by one of the two power sources, to either power source.

Heating is provided by electric unit heaters controlled by wall-mounted room thermostats. The heaters will start on a decrease in room temperature and stop when the preset temperature on the

thermostat is reached. 9.4.8.2 Alternate Intake Structure Ventilation System

The alternate intake structure ventilation system provides an environment suitable for personnel access and equipment operation during normal plant operation. This system is not required to operate under accident conditions and is NNS class.

9.4.8.2.1 Design Bases The design bases of the alternate intake structure ventilation

system are as follows:

1. General Design Criterion 2, as it relates to the system being capable of withstanding the effects of

natural phenomena, as established in Chapters 2 and 3.

2. General Design Criterion 5, as it relates to shared systems. No portion of the system is shared.

3. Regulatory Guide 1.26, as it relates to the quality group classification of system components.

4. Regulatory Guide 1.29, as it relates to the seismic design classification of systems and components. The

alternate intake structure ventilation system is

designed to Seismic Category II criteria.

5. Outdoor air is drawn in through a motorized damper, circulated through the structure, and exhausted to the atmosphere by propeller-type exhaust fans to maintain the area below 104F, coincident with summer outdoor design temperatures. Electrical heating is provided

to maintain the area above 40F, coincident with winter outdoor design temperatures.

6. The electrical components of the two redundant ventilation units is powered from the emergency power supply. 9.4.8.2.2 System Description The alternate intake structure ventilation system consists of two 100-percent capacity exhaust fans, each with their own motorized intake and exhaust dampers and related ductwork.

BVPS-2 UFSAR Rev. 9 9.4-38 Outdoor air is drawn in through the motorized intake damper, circulated through the structure, and exhausted through the motorized exhaust damper by the exhaust fan.

When an increase in room temperature is detected by a room thermostat, the intake and exhaust dampers will open automatically. With a further increase in temperature, the

exhaust fan will start automatically. The electric heaters start on falling temperature and maintain

the temperature by circulating the room air. The electric unit heaters are provided from normal power. The ventilation system is shown on Figure 9.4-11 and the principal components and design parameters are given in Table 9.4-15. A furnace supplies heated air to the lower pump bays to prevent ice formation during extremely cold weather. The air handler blower will operate continuously on normal power when the unit is placed in service. The furnace burner will operate by thermostat on falling temperature.

9.4.8.2.3 Safety Evaluation

The system is nonsafety-related and is not required to operate during a DBA.

The temperature in the intake structure is maintained below 104F to ensure the required environment for operation of the pumps and associated equipment.

Power is supplied to the damper actuators and fans from emergency buses. Although this is not a safety-related system, the equipment is designed to withstand historic seismic forces.

9.4.8.2.4 Inspection and Testing Requirements

The alternate intake structure ventilation system is inspected after installation to ensure that the equipment is properly installed. The system is also tested and balanced after installation. Preliminary testing is performed in accordance with Section 14.2.12.

Observation of the system and routine maintenance during the course of normal operation are sufficient to ensure system availability.

9.4.8.2.5 Instrumentation Requirements

Control switches with indicating lights for each of the alternate intake structure ventilation fans are provided locally (near each respective ventilation fan).

Thermostats are locally mounted for automatic control of the air exhaust dampers, outside air supply dampers, and ventilation

fans. BVPS-2 UFSAR Rev. 9 9.4-38a In the event of an SIS signal, the alternate intake structure ventilation fans will be shunt tripped off the emergency buses. The fans may be administratively loaded on to the emergency diesel generators after the SIS signal has been reset.

An alarm is provided on the alternate intake structure annunciator panel located in the alternate intake structure for indication of a space high temperature and a space low temperature.

BVPS-2 UFSAR Rev. 12 9.4-39 A trouble alarm is provided on the main control room annunciator panel for indication of trouble with the alternate intake structure ventilation system and is also monitored by the BVPS-2 computer.

The alternate intake structure is provided with thermostatically controlled electric unit heaters to ensure the minimum ambient temperature required for freeze protection and proper operation of equipment located within the space.

9.4.9 Main Steam and Feedwater Valve Area Ventilation System Cooling in the main steam and feedwater valve area (MSFVA) is

accomplished by the MSFVA ventilation system. The MSFVA ventilation system maintains a suitable environment for personnel access and equipment operation during all modes of

plant operation except a high energy line break in the MSFVA. The MSFVA ventilation system is comprised of Seismic Category I axial flow fans with ductwork and non-safety related Seismic Category II cooling system for main steam valve room coolers.

9.4.9.1 Design Bases Design bases for the MSFVA systems are as follows:

1. General Design Criterion 2, as it relates to structures housing the system and the system itself

being capable of withstanding the effects of natural phenomena such as earthquakes, tornadoes, hurricanes, and floods, as established in Sections 2 and 3.

2. General Design Criterion 4, as it relates to structures housing the system and the system itself being capable of withstanding the effects of external missiles and internally-generated missiles, pipe whip, and jet impingement forces associated with pipe

breaks.

3. General Design Criterion 5, as it relates to shared systems. No portion of the system is shared.

4. Regulatory Guide 1.26, as it relates to the quality group classification of system components. This system is designated as Safety Class 3.

5. Regulatory Guide 1.29, as it relates to the seismic design classification of system components. This

system is designated as Seismic Category I.

6. During normal plant operation, the MSFVA ventilation system maintains the ambient temperature in the MSFVA at 120F or less, coincident with outdoor design temperatures.

BVPS-2 UFSAR Rev. 12 9.4-40 7. During plant shutdown, the MSFVA is maintained at a minimum temperature of 55F with electric unit heaters, coincident with outdoor design temperatures. 9.4.9.2 System Description

Two 100-percent capacity ventilation systems are provided in the MSFVA. Each system consists of a fan, a roll-type filter, dampers, cooling coils, temperature control valves, ductwork, and supply and return grills. The MSFVA ventilation system maintains the ambient temperature

in the MSFVA by recirculating 31,400 cfm of air through the MSFVA ventilation system cooling coils.

Air is drawn into the MSFVA by the axial flow fan through a motor-operated damper, a roll filter, and the cooling coils. The air is then discharged through a motor-operated damper and

various distribution ductwork into the MSFVA. The MSFVA ventilation system is shown on Figure 9.4-12 and the principal component performance characteristics are presented in Table 9.4-16. 9.4.9.3 Safety Evaluation The MSFVA ventilation system consists of two 100-percen t capacity separate and redundant ventilation systems. Each of the separate MSFVA ventilation systems consists of a Seismic Category I axial flow fan powered with Class 1E power. Each

system also includes a Seismic Category II roll filter and non-safety related, Seismic Category II cooling coils that are cooled by chilled water. The Chilled Water System is described in Section 9.2.2.2.2.

The MSFVA system is provided with air-operated flow control valves which will fail open to ensure cooling water flow to the MSFVA ventilation system cooling coils.

Normally, one train of the MSFVA ventilation system is in operation while the other train is on standby. Upon detecting a loss of air flow, which may be caused by loss of an operating fan or a duct blockage, the redundant system will automatically start. Chilled water cooling flow to the backup unit will normally be isolated and must be manually aligned when the redundant unit

starts. During a high energy line break, the MSFVA ventilation system's electric motors will fail on exposure to high temperatures for

an extended period. The ventilation system is not required in the MSFVA to bring down the temperature.

BVPS-2 UFSAR Rev. 12 9.4-41 A FMEA to determine if the I&C and electrical portions meet the single failure criterion, and to demonstrate and verify how the GDC and IEEE Standard 279-1971 requirements are satisfied, has been performed on the MSFVA ventilation system. The FMEA

methodology is discussed in Section 7.3.2. The results of this analysis can be found in the separate FMEA document (Section 1.7). The MSFVA system ductwork is Seismic Category I. Components related to the Chilled Water Cooling Coils are Seismic Category II. 9.4.9.4 Inspection and Testing Requirements

The MSFVA ventilation system is inspected after installation to ensure that the equipment is properly installed and operates correctly. The system is tested and balanced after installation. Preliminary tests are performed as described in Section 14.2.12.

The system is in continuous operation and periodic operation of the standby equipment in conjunction with routine observation

and maintenance during normal operation are sufficient to ensure system availability.

9.4.9.5 Instrumentation Requirements Control switches with indicating lights for the MSFVA ventilation and cooling supply fans are provided on the building service panel in the main control room. Local selector switches are provided for the chilled water flow control valves for manual open or modulating modes. The auto modulating mode is controlled by temperature controllers that monitor and maintain the fans' exhaust air temperature.

The ventilation and cooling system supply fans may be started manually or automatically. When a supply fan is placed in the

start position, the unit isolation dampers go to the full open position. Upon reaching a predetermined position of their opening travel, limit switches, attached to the motor-operated dampers, will energize the ventilation supply fan and when this fan is started, the automatic roll filters are started.

During normal or emergency operating conditions, one supply fan runs continuously with the redundant supply fan on standby in the auto position. Upon sensing a low air flow, the standby

fan will start automatically. Discharge air temperature indicators for the supply fans are

located on the local control panel. The ventilation and cooling supply fans have annunciation

provided in the main control room for fan auto trip, air temperature high, and high filter differential pressure. These conditions are also monitored by the BVPS-2 computer system.

BVPS-2 UFSAR Rev. 12 9.4-42 9.4.10 Service Building Ventilation System The service building ventilation system is comprised of four separate ventilation systems. They are: the normal switchgear and cable spreading area ventilation system; the battery room ventilation system; the emergency switchgear room ventilation system; and the service building equipment room ventilation

system. 9.4.10.1 Normal Switchgear and Cable Spreading Area Ventilation System The normal switchgear and cable spreading area ventilation system removes heat from this area and maintains a suitable environment for personnel access and equipment operation.

9.4.10.1.1 Design Bases The normal switchgear and cable spreading area ventilation

system is designed in accordance with the following criteria:

1. The system maintains an ambient temperature at or below 104F during the summer and a minimum temperature of 55F during the winter, coincident with outdoor design temperatures.

2. General Design Criterion 2, as it relates to the system being capable of withstanding the effects of

natural phenomena, as established in Chapters 2 and 3.

3. General Design Criterion 5, as it relates to shared systems. No portion of the normal switchgear and cable spreading area ventilation system is shared.

4. Regulatory Guide 1.26, as it relates to the quality group classification of the system components.

5. Regulatory Guide 1.29, as it relates to the seismic design classification of systems and components.

9.4.10.1.2 System Description

The principal component design and performance characteristics are presented in Table 9.4-17. Outdoor air is used to ventilate and cool the area. The system consists of one supply fan and one return-exhaust fan, distribution ductwork, fire dampers, roll-type filter, supply and return air grilles, and dampers. Outdoor air is supplied by the supply fan. The return-exhaust fan either exhausts the air to the outdoors or returns it to the supply air duct. The components and

BVPS-2 UFSAR Rev. 0 9.4-43 ductwork, except ductwork at el 745 ft-6 in, are not supported seismically. The ductwork at el 745 ft-6 in is designed seismically and is designated Seismic Category I.

Return-exhaust and outdoor air dampers are modulated by a thermostat in the supply air duct to maintain the supply air above a desired minimum temperature.

Outdoor and/or return air is filtered through a roll-type filter before being supplied to the area.

Heating is provided by hot water and electric unit heaters controlled by room thermostats.

9.4.10.1.3 Safety Evaluation

The normal switchgear and cable spreading area ventilation system is nonsafety-related, and the system is not required to operate during or after a DBA.

9.4.10.1.4 Inspection and Testing Requirements

The system is inspected after installation to ensure that the equipment is properly installed and operates correctly. The system is tested and balanced after installation. Preliminary

tests are performed as described in Section 14.2.12. The system is in continuous operation and, as such, periodic

inspection is not required. 9.4.10.1.5 Instrumentation Requirements

Control switches with indicating lights are provided on the normal switchgear ventilation control panel, located in the normal switchgear room, for the supply air and exhaust air ventilation fans. The two ventilation fans are interlocked such that the starting or stopping of one ventilation fan will

automatically initiate the starting or stopping of the other ventilation fan.

Temperature indicators are provided on the normal switchgear ventilation control panel to indicate supply air to and exhaust air from the normal switchgear and cable spreading areas.

Supply air and return-exhaust air dampers are controlled automatically by the supply air temperature sensors, provided

the supply air fan is operating. Automatic trip of either the supply air ventilation fan or

return-exhaust air ventilation fan activates an alarm on the building services control panel in the main control room and is monitored by the BVPS 2 computer system.

BVPS-2 UFSAR Rev. 0 9.4-44 The automatic roll-type filter is energized upon starting of the supply air ventilation fan. 9.4.10.2 Battery Room Ventilation System

The battery room ventilation system removes heat and maintains proper ventilation to preclude the buildup of hydrogen. The

system is safety-related and designated Safety Class 3. 9.4.10.2.1 Design Bases

The battery room ventilation system is designed in accordance with the following criteria:

1. The system maintains the ambient temperature at or below 104F during the summer and a minimum temperature of 55F in the winter, coincident with outdoor design temperatures.

2. The ventilation rates are sufficient to limit the concentration of hydrogen below 2 percent by volume.

3. General Design Criterion 2, as it relates to structures housing the system, and the system itself being capable of withstanding the effects of natural phenomena such as earthquakes, tornadoes, hurricanes, and floods, as established in Sections 2 and 3.

4. General Design Criterion 4, with respect to structures housing the system, and the system itself being capable of withstanding the effects of external missiles and internally-generated missiles, pipe whip, and jet impingement forces associated with pipe

breaks.

5. General Design Criterion 5, as it relates to shared systems and components important to safety.

BVPS-2 UFSAR Rev. 0 9.4-45 6. General Design Criterion 17, as it relates to assuring proper functioning of the essential electric power systems. 7. Regulatory Guide 1.26, as it relates to the quality group classification of systems and components. This

system is designated as Safety Class 3.

8. Regulatory Guide 1.29, as it relates to the seismic design classification of system components. This system is designated Seismic Category I.

9. Branch Technical Position CMEB 9.5-1, as it relates to the capability of the system to remove smoke.

9.4.10.2.2 System Description

The battery room ventilation system is shown on Figure 9.4-13 and the principal components design and performance characteristics are presented in Table 9.4-18. The ventilation system consists of two 100-percent capacity exhaust fans, fire

dampers, ductwork, supply and return air grilles, and dampers.

Air is exhausted from the battery room by the exhaust fan. Transfer grilles in each room supply air to the room from the emergency switchgear areas. 9.4.10.2.3 Safety Evaluation

The battery room ventilation system has two 100-percent capacity fans, each powered from a separate emergency power bus; thus the failure of one fan or source of power does not leave the system inoperable.

The fans and components are QA Category I and supplied with emergency power to ensure their operation during all modes of BVPS-2 operation. The components and ductwork are supported to

withstand seismic forces. A FMEA to determine if the I&C and electrical portions meet the single failure criterion, and to demonstrate and verify how the GDC and IEEE Standard 279-1971 requirements are satisfied, has been performed on the battery room ventilation system. The FMEA

methodology is discussed in Section 7.3.2. The results of this analysis can be found in the separate FMEA document (Section 1.7). 9.4.10.2.4 Inspection and Testing Requirements

The system is inspected after installation to ensure that the equipment is properly installed and operates correctly. The system tested and balanced after installation. Preliminary

tests are performed as described in Section 14.2.12.

BVPS-2 UFSAR Rev. 0 9.4-46 The system is in continuous operation and periodic operation of the standby equipment, in conjunction with routine observation and maintenance during normal operation, are sufficient to ensure system availability.

9.4.10.2.5 Instrumentation Requirements

Control switches with indicating lights are provided on the building services control panel in the main control room for the two battery room exhaust air ventilation fans.

No pressure differential across one exhaust air ventilation fan will automatically start the redundant fan.

Alarms are provided for automatic start or stop of either exhaust air ventilation fan on the building services control

panel and are also monitored by the BVPS-2 computer system. Loss of air flow from any battery room or total loss of air flow

from the battery room ventilation system causes an alarm on the building services control panel and is monitored by the BVPS-2 computer system.

9.4.10.3 Emergency Switchgear Room Ventilation System

The emergency switchgear room ventilation system removes heat from this room and maintains a suitable environment for personnel access and equipment operation during all BVPS-2 operating conditions. The system is safety-related and designated Safety Class 3.

9.4.10.3.1 Design Bases The emergency switchgear room ventilation system is designed in

accordance with the following criteria:

1. The system maintains the ambient temperature at or below 104F during the summer and a minimum temperature of 55F in the winter, coincident with outdoor design temperatures.

2. General Design Criterion 2, as it relates to structures housing the system, and the system itself being capable of withstanding the effects of natural phenomena such as earthquakes, tornadoes, hurricanes, and floods, as established in Sections 2 and 3.

3. General Design Criterion 4, with respect to structures housing the system, and the system itself being capable of withstanding the effects of external missiles and internally-generated missiles, pipe whip, and jet impingement forces associated with pipe breaks.

BVPS-2 UFSAR Rev. 0 9.4-47 4. General Design Criterion 5, as it relates to shared systems and components important to safety.

5. General Design Criterion 17, as it relates to assuring proper functioning of the essential electric power system. 6. Regulatory Guide 1.26, as it relates to the quality group classification of system components.

7. Regulatory Guide 1.29, as it relates to the seismic design classification of system components. This

system is designated as Seismic Category I.

8. Branch Technical Position CMEB 9.5-1, as it relates to the capability of the system to remove smoke.

9.4.10.3.2 System Description

The emergency switchgear room ventilation system is shown on Figure 9.4-13 and the principal components, design, and performance characteristics are p resented in Table 9.4-19. Outdoor air is used for cooling and ventilating the area.

The system consists of two 100-percent capacity supply fans, two 100-percent capacity exhaust fans, a cartridge-type throwaway filter, distribution ductwork, and dampers. Each set of fans and associated motor-operated dampers is powered by an

independent emergency bus. Outdoor air is drawn in through a missile-protected opening, through a cartridge-type throwaway air filter, and into the emergency switchgear room by one of the supply fans. The room air is returned to the supply fan or exhausted by one of the exhaust fans to the outdoors through another missile-protected opening. Outdoor air, return air, and exhaust air dampers are modulated by the temperature controller, located at the discharge of the supply fan, to maintain the supply air at a desired temperature.

A portion of the air supplied is drawn into the battery room and is exhausted by the battery room ventilation system.

Heating is provided by electric unit heaters controlled by room thermostats.

9.4.10.3.3 Safety Evaluation

The system is designed on the basis of 100-percent redundancy; thus the failure of one set of components or its separate emergency power supply would permit continued operation.

The system components are Seismic Category I design and are supplied with Class 1E power to ensure operation during all

modes of BVPS-2 BVPS-2 UFSAR Rev. 16 9.4-48 operation. The components and ductwork are supported to withstand seismic forces. A FMEA to determine if the I&C and electrical portions meet the single failure criterion, and to demonstrate and verify how the GDC and IEEE Standard 279-1971 requirements are satisifed, has been performed on the emergency switchgear room ventilation system. The FMEA methodology is discussed in Section 7.3.2. The results of this analysis can be found in the separate FMEA document (Section 1.7).

9.4.10.3.4 Inspection and Testing Requirements

The system is inspected after installation to ensure that the equipment is properly installed and operates correctly. The system is tested and balanced after installation. Preliminary

tests are performed as described in Section 14.2.12. The system is in continuous operation and periodic operation of the standby equipment, in conjunction with routine observation and maintenance during normal operation, are sufficient to ensure system availability.

9.4.10.3.5 Instrumentation Requirements

Control switches with indicating lights are provided on the building services control panel in the main control room to operate the supply and exhaust air fans for the emergency

switchgear area. The exhaust air fans are interlocked so that the starting of one supply air fan will automatically start its respective exhaust air fan.

High or low temperature of the air coming from the supply air fan will automatically shut down both the supply and exhaust air

fans. Supply, exhaust, and return air dampers are controlled by the

supply air temperature sensors. Temperature indicators of the supply air temperature are provided on the building services control panel. Automatic start or stop of any of the emergency switchgear ventilation

fans will cause an alarm on the building services control panel and is monitored by the BVPS-2 computer system. An alarm is provided for high differential pressure across the roll-type filter, which is also monitored by the BVPS-2 computer system.

The BVPS-2 computer system also monitors high and low supply air temperatures. Automatic or manual control stations for adjusting the supply air temperature set point is mounted on the

building services control panel in the main control room.

BVPS-2 UFSAR Rev. 12 9.4-49 9.4.10.4 Service Building Equipment Room Ventilation System The service building equipment room ventilation system removes heat from this room and maintains a suitable environment for

personnel access and equipment operation. The system is nonsafety-related and is designated NNS class.

9.4.10.4.1 Design Bases The service building equipment room ventilation system is

designed in accordance with the following criteria:

1. The system maintains the ambient temperature at or below 104F during the summer and a minimum temperature of 55F during the winter, coincident with outdoor design temperatures.

2. General Design Criterion 2, as it relates to the system being capable of withstanding the effects of natural phenomena, as established in Chapters 2 and 3.

3. General Design Criterion 5, as it relates to shared systems. No portion of this ventilation system is

shared. 4. Regulatory Guide 1.26, as it relates to the quality group classification of system components.

5. Regulatory Guide 1.29, as it relates to the seismic design classification of systems and components. The service building equipment room is nonseismic.

9.4.10.4.2 System Description

The principal component and design parameters are presented in Table 9.4-20. Outdoor air is used to ventilate and cool the area. The system consists of two 50-percent capacity roof exhaust fans, intake hood, and dampers. Air is exhausted from the room by the two roof exhaust fans, which are controlled by room thermostats.

Air enters the room through the intake hood, which is common to both the service building equipment room ventilation and normal switchgear and cable spreading area ventilation systems. A motorized damper, interlocked with the exhaust fans, is tied with the intake hood ductwork.

Hot water unit heaters controlled by wall-mounted thermostats provide heat for the area in the winter.

BVPS-2 UFSAR Rev. 0 9.4-50 9.4.10.4.3 Safety Evaluation The service building equipment room ventilation system is nonsafety-related, is not required to operate during or after a

DBA, and is nonseismic. 9.4.10.4.4 Inspection and Testing Requirements

The system is inspected and tested after installation to ensure that the equipment is properly installed and operates correctly.

Preliminary tests are performed as described in Section 14.2.12. The system is in continuous operation and, as such, periodic

inspection is not required. 9.4.10.4.5 Instrumentation Requirements

Control switches with indicating lights are provided on a local control panel for the service building equipment room powered roof ventilators. The motorized damper for outdoor air intake is controlled by the starting and stopping of the ventilators. Space heating/cooling thermostats are provided for controlling

the operation of each ventilator. Wall-mounted thermostats control the hot water unit heaters that

are used to heat the area. Additionally, room heating is accomplished by the use of ventilators.

9.4.11 Safeguards Area Ventilation System The safeguards area ventilation system maintains a suitable environment for equipment operation and personnel access. This ventilation system consists of two identical systems: south safeguards area ventilation system and north safeguards area

ventilation system. The system is designed as Safety Class 3. 9.4.11.1 Design Bases

The design bases for the safeguards area ventilation system are in accordance with the following criteria:

1. General Design Criterion 2, as it relates to the structures housing the system and the system itself

being capable of withstanding the effects of natural phenomena such as earthquakes, tornadoes, hurricanes, and floods, as established in Chapters 2 and 3.

2. General Design Criterion 4, as it relates to the structures housing the system and the system itself being capable of withstanding the effects of externally and internally-generated missiles, pipe whip, and jet impingement forces associated with pipe breaks.

BVPS-2 UFSAR Rev. 14 9.4-51 3. General Design Criterion 5, as it relates to shared systems. No portion of this system is shared.

4. Regulatory Guide 1.26, as it relates to the quality group classification of systems and components. This system is designated as Safety Class 3, QA Category I.

5. Regulatory Guide 1.29, as it relates to the seismic design classification of systems and components. This

system is designated as Seismic Category I.

6. The temperature of the area is maintained during the summer at a maximum of 104F when there is no safeguards area equipment in operation (during normal plant operation), and at a maximum of 124F following a DBA, which decreases to below 124F after 3 hours when the quench spray and low head safety injection pumps are shut down. During normal plant operation, a

minimum temperature of 55F is maintained during the winter, coincident with outdoor design temperatures. 9.4.11.2 System Description

The safeguards area ventilation system is shown on Figure 9.4-12 (design basis analysis (DBA) flow rates are also provided). The design parameters of the principal components are provided in Table 9.4-21. The safeguards area is divided into two identical areas - the south safeguards area and the north safeguards area. Identical ventilation systems are provided for each of the two areas. Each ventilation system consists of an air-conditioning unit with a fan, service water cooling coils, volume control dampers, supply grilles, distribution ductwork, and electric unit heaters. Smoke detectors, located in the supply air ductwork downstream of the air-conditioning units, alarm locally and

annunciate in the control room. During the cooling mode of the system, the thermostat controls the operation of the fan, which draws air over the cooling coils and recirculates air in the area. Service water flows through the cooling coils at all times.

During the heating mode of the system, the thermostat controls the electric unit heaters and maintains area temperature above

55 F. 9.4.11.3 Safety Evaluation

The safeguards area ventilation system is designed to maintain an ambient temperature suitable for equipment operation and

personnel access during normal plant operation.

BVPS-2 UFSAR Rev. 14 9.4-52 During a DBA, temperature is maintained at an adequate level to support operation of emergency equipment in the area. The ventilation system is supplied from the Class 1E power buses to maintain operability during accident conditions. The safeguards area ventilation system is designed as Safety Class 3, Seismic

Category I, and QA Category I. Each of the separate safeguards areas is provided with an independent ventilation system. Failure of the ventilation

system in one of the safeguards areas will not impair the operation of the ventilation system in the redundant safeguards area. Thus, protection against single failure is provided on a

system-area basis. Each area is also maintained under negative pressure, to prevent any airborne radioactive contamination from leaking out to the atmosphere, by the SLCRS described in Section 6.5.3.2.

A FMEA to determine if the I&C and electrical portions meet the single failure criterion, and to demonstrate and verify how the GDC and IEEE Standard 279-1971 requirements are satisfied, has been performed on the safeguards area ventilation system. The FMEA methodology is discussed in Section 7.3.2. The results of this analysis can be found in the separate FMEA document (Section 1.7). 9.4.11.4 Inspection and Testing Requirements The safeguards area ventilation system is inspected after installation to ensure that the equipment is properly installed

and operates correctly. The system is tested and balanced after installation. Preliminary tests are performed as described in Section 14.2.12.

The system is in continuous operation and periodic operation of the standby equipment, in conjunction with routine observation

and maintenance during normal operation, are sufficient to ensure system availability. 9.4.11.5 Instrumentation Requirements Control switches and indicating lights for each air-conditioning unit are provided in the main control room. The air-conditioning units can be operated manually, or automatically on rise and/or fall of space temperature.

The air-conditioning units' motor overload trip is annunciated in the main control room and is also monitored by the BVPS-2

computer. 9.4.12 Cable Vault and Rod Control Area Ventilation System and Alternate Shutdown Panel Room Ventilation System The cable vault and rod control area ventilation system maintains a suitable environment for personnel access and equipment operation by providing cooling during normal plant conditions and heating during normal and accident conditions. The supplementary leak collection and release system (SLCRS, Section 6.5.3.2) provides safety related cooling during accident

conditions. The primary system is safety-

BVPS-2 UFSAR Rev. 8 9.4-53 related and designated as Safety Class 3. A secondary system, which supplements normal operation cooling, is nonsafety-related and is designated NNS class. The alternate shutdown panel (ASP) room ventilation system maintains a suitable environment for personnel occupancy and equipment operation, as well as room pressurization during a fire in the control building or cable tunnel area northwest of the auxiliary building. The system is safety-related and designated Safety Class 3.

9.4.12.1 Design Bases The design bases for the cable vault and rod control area

primary ventilation system are as follows:

1. The temperature of the area is maintained between 65 F and 104°F during normal plant operation and at a minimum of 65 F during accident conditions.

2. General Design Criterion 2, as it relates to structures housing the system and the system itself being capable of withstanding the effects of natural phenomena such as earthquakes, tornadoes, hurricanes, and floods, as described in Chapters 2 and 3.

3. General Design Criterion 4, with respect to structures housing the system, and the system itself being capable of withstanding the effects of external missiles and internally-generated missiles, pipe whip, and jet impingement forces associated with pipe

breaks.

4. General Design Criterion 5, as it relates to shared systems and components important to safety. No portion of the system is shared.

5. General Design Criterion 17, as it relates to assuring proper functioning of the essential electric power

system. 6. General Design Criterion 60, as it relates to the system capability to suitably control release of gaseous radioactive effluents to the environment.

7. Regulatory Guide 1.26, as it relates to the quality group classification of system components.

8. Regulatory Guide 1.29, as it relates to the seismic design classification of systems and components. The cable vault and rod control area primary ventilation system is designed to Seismic Category I criteria.

9. Regulatory Guide 1.52, as it relates to the design, testing, and maintenance criteria for post-accident ESF cleanup systems.

BVPS-2 UFSAR Rev. 8 9.4-54 10. Branch Technical Position CMEB 9.5-1, as it relates to the design provisions given to implement the fire protection program in the removal of smoke. The design bases of the ASP room ventilation system include

the following:

1. General Design Criterion 2, as it relates to structures housing the system and the system itself to withstand the effects of natural phenomena such as

earthquakes, tornadoes, hurricanes, and floods, as described in Chapters 2 and 3.

2. General Design Criterion 4, as it relates to structures housing the system and the system itself to

withstand the effects of external missiles, internally-generated missiles, pipe whip, and jet impingement forces associated with pipe breaks.

3. General Design Criterion 5, as it relates to shared systems and components important to safety. No

portion of the system is shared.

4. General Design Criterion 19, as relates to providing access and occupancy of spaces outside the control room housing equipment necessary for safe shutdown of the reactor.

5. Regulatory Guide 1.26, as it relates to the quality group classification of system components.

6. Regulatory Guide 1.29, as it relates to the seismic design classification of systems and components. The

alternate shutdown panel room ventilation system is

designed to Seismic Category I criteria.

7. The capability of the nonsafety-related features (in-line electric heaters) to maintain their structural integrity in the event of a safe shutdown earthquake (SSE) in order not to compromise the capability of the

system. 9.4.12.2 System Description

The cable vault and rod control area primary and secondary ventilation systems are shown on Figure 9.4-14 and the design parameters of the principal components are provided in Table 9.4-22. The systems consists of two safety-related 100-percent capacity air-conditioning units, two nonsafety-related unit coolers, volume control dampers, supply and return air grills, and related ductwork. Each safety-related air-conditioning unit contains a chilled

water cooling coil, a service water cooling coil, a hot water heating coil, a roll-type filter, and a centrifugal fan. Service water flow to the service water cooling coil is normally isolated to conserve service water system flow margin. BVPS-2 UFSAR Rev. 18 9.4-55 The primary system operates on 100 percent recirculation mode. During normal operation, the chilled water cooling coil is used to cool the recirculated air. During emergency conditions, when chilled water may not be available, the Supplemental Leak

Collection and Release System (SLCRS) performs the cooling

function. Water flows to the heating and chilled water cooling

coils are modulated by the return air thermostat.

Failure of one safety-related unit to start, as sensed by the

area high temperature, automatically starts the standby unit.

The secondary ventilation system consists of two nonsafety-

related unit coolers, one located in the cable vault and the other in the cable tunnel area, augment normal operation cooling for the relay room and various spaces at el 755 feet-6 inches. Each cooler operates continuously during normal plant operation with 100-percent recirculation using chilled water as a cooling

medium. During Carbon Dioxide discharge in the area, the secondary ventilation system will shut off to prevent damage to

the cooling coils.

The area is maintained under negative pressure by the SLCRS as

described in Section 6.5.3.2.

The ASP room ventilation system is shown on Figure 9.4-14 , and the design parameters are shown in Table 9.4-22. The system consists of one self-contained air-conditioning unit, a motor-operated water-regulating valve, an electric duct heater, a motor-operated damper, volume control dampers, fire

dampers, supply air diffuser, return air grille, and related

duct work.

The air-conditioning unit employs a refrigerant compressor, a

direct expansion cooling coil, a water-cooled condenser, a motor-operated water regulating valve, a cartridge-type air

filter, and a centrifugal fan.

During normal plant operations this system will not run except during periodic testing. In the event of a fire in the cable tunnel area (CT-l), the instrumentation and relay room (CB-l), the cable spreading room (CB-2), or the west communications room (CB-6), operators will be occupying the alternate shutdown panel room and the ventilation system will be continuously operating. Once manually started, the system is controlled by room

thermostats.

9.4.12.3 Safety Evaluation

The cable vault and rod control area primary ventilation system was originally designed to limit maximum ambient temperature to 120 F during loss of chilled water. Subsequently, the service water cooling medium which performed this function was isolated. Safety related cooling is now performed by SLCRS.

The safety-related air-conditioning units and associated controls are supplied with emergency power to ensure their operation during emergency conditions. The primary ventilation system is QA Category I, Safety Class 3, and Seismic Category I.

The air-BVPS-2 UFSAR Rev. 0 9.4-56 conditioning units are redundant, such that failure of one unit does not incapacitate the system.

A FMEA to determine if the I&C and electrical portions meet the single failure criterion, and to demonstrate and verify how the GDC and IEEE Standard 279-1971 requirements are satisfied, has been performed on the cable vault and rod control area ventilation system. The FMEA methodology is discussed in Section 7.3.2. The results of this analysis can be found in the

separate FMEA document (Section 1.7). The ASP room ventilation system is designed to maintain room-

temperature at 75 degrees F in the event of a fire in the control building or cable tunnel area. The alternate shutdown capability approach is described in Section 3.1.3 of the Fire

Protection Evaluation Report. The air-conditioning unit and associated controls are supplied with emergency power to ensure their operation in the event of a loss-of-offsite power. The air-conditioning unit is QA Category I, Safety Class 3, and Seismic Category I. The system is not

redundant because a fire in the control building or cable tunnel area and any other accident which might render all other means of safe shutdown inoperable are not postulated to occur

simultaneously. 9.4.12.4 Inspection and Testing Requirements

The systems are inspected after installation to ensure that the equipment is properly installed and operates correctly. The

systems are tested and balanced after installation. Preliminary tests are performed as described in Section 14.2.12. The cable vault and rod control area ventilation system is in continuous operation. Periodic operation of the standby equipment and the alternate shutdown panel room ventilation system, in conjunction with routine observation and the maintenance during normal

operation, are sufficient to ensure system availability.

BVPS-2 UFSAR Rev. 8 9.4-56a 9.4.12.5 Instrumentation Requirements The following paragraphs describe instrumentation provided for safety-related air-conditioning units.

Control switches with indicating lights for the cable vault and rod control area air-conditioning units are provided on the

building services control panel in the main control room. Temperature indication is provided locally (on the cable vault

ventilation panel) for the air supply to, and the air exhaust from, both air-conditioning units.

Return air temperature to the cable vault and rod control area air-conditioning units is monitored, and, through temperature sensors, automatically operates the hot water coil water supply

valve and the chilled water coil water supply valve to maintain the required space temperature.

Space temperature thermostats for sensing the cable vault and rod control area temperatures are located in the cable vault and rod control area. These thermostats will be used for automatic

operation of the air-conditioning units. An increase in space temperature above the high-high set point of the duty unit space thermostat will automatically stop the duty unit. The standby unit will start automatically when the space temperature exceeds the high-high set point of its

respective space thermostat. High pressure drop across the roll filter, serviced by a pressure differential switch, will automatically start the drive assembly which will advance clean media into the air stream. Run-out of filter media will be indicated by a warning light

provided on the filter terminal box. Indicating lights are provided on the building services control panel to indicate air supply damper position and air exhaust damper position for each air-conditioning unit. Indicating lights are also provided on the building services control panel

to indicate the valve position of the service water supply valve to each air-conditioning unit.

The nonsafety-related unit coolers are started and stopped manually from local panels. Indicating "start" and "stop" lights are provided.

Annunciation is provided for automatic trip of either air-conditioning unit. Annunciation is also provided for the cable

vault BVPS-2 UFSAR Rev. 0 9.4-56b and rod control area high temperature and high-high temperature. These conditions are also monitored by the BVPS-2 computer. Control switches with indicating lights are provided locally for the alternate shutdown panel room air-conditioning unit. When the air-conditioning unit start pushbutton is depressed, first stage cooling is energized and the fan of the air-conditioning unit will run. As the temperature in the room increases above the high setpoint of the temperature switch, the second stage cooling is energized. When cooling is no longer required, the

air-conditioning unit stop pushbutton is depressed and the fan control switch is placed in the on position. The fan will run for ventilation and when the temperature of the area drops below the low setpoint of the temperature switch, an electric duct heater located downstream of the air-conditioning unit will be energized. An airflow switch provided with the heater will

prevent the heater from operating unless the fan is running. Temperature of the entering and leaving air, and the pressure drop across the cartridge filter are provided by local indicators.

9.4.13 Decontamination Building Ventilation System The decontamination building ventilation system ventilates, removes heat, and maintains a suitable environment for personnel access and equipment operation under normal conditions.

The system is nonsafety-related and is designated as NNS class. 9.4.13.1 Design Bases

The decontamination building ventilation system is designed in accordance with the following criteria:

1. The system maintains the ambient temperature below 104F during the summer and above 60F during the winter, coincident with outdoor design temperatures.

2. General Design Criterion 2, as it relates to the system being capable of withstanding the effects of

natural phenomena, as established in Chapters 2 and 3.

3. General Design Criterion 5, as it relates to shared systems. No portion of the system is shared.

BVPS-2 UFSAR Rev. 0 9.4-56c 4. General Design Criterion 60, as it relates to the capability to suitably control the release of gaseous radioactive effluents to the environment.

5. Regulatory Guide 1.140, as it relates to the design for normal ventilation exhaust system air filtration

and adsorption units.

6. Regulatory Guide 1.26, as it relates to the quality group classification of system components.

7. Regulatory Guide 1.29, as it relates to the seismic design classification of systems and components. The decontamination building ventilation system is nonseismic.

9.4.13.2 System Description

The decontamination building ventilation system is shown on Figure 9.4-15. The principal components and design parameters are given in Table 9.4-23. BVPS-2 UFSAR Rev. 12 9.4-57 The ventilation system consists of two subsystems, the normal roof exhaust ventilation subsystem and the filtration and exhaust subsystem.

The normal roof exhaust subsystem ventilates the decontamination building when operating. This subsystem consists of two powered roof ventilator exhaust fans, two associated backdraft dampers, a radiation monitor located in the duct common to both fans, and a motorized damper at the west wall fresh air intake. The roof fans and motorized damper are controlled manually, or by two

room thermostats when operating. The filtration and exhaust subsystem ventilates the gaseous waste storage tank (GWST) area and the cask washdown area. The subsystem consists of a filter assembly, an electrical duct heater, a filter assembly bypass, two parallel centrifugal flow

exhaust fans with backdraft dampers, associated ductwork, and manually- and motor-operated dampers. Upstream of the parallel centrifugal fans is an interconnecting cross-over with a manually-operated damper. Downstream of the centrifugal fans is a common, radiation-monitored exhaust stack.

The filtration assembly includes one prefilter, one charcoal filter, and one HEPA. A motor-operated damper upstream of the filtration assembly modulates air flow to the filters in order to maintain proper air-residence condition for optimal filter utilization. An electric duct heater upstream of the filtration assembly heats the air stream to reduce the relative humidity to

less than 70 percent before the air stream passes through the filter banks.

The filtration and exhaust subsystem receives air from four flexible hoses used for venting spent fuel casks, and from the GWST area which is adjacent to the decontamination building.

The flexible hose connections are equipped with redundant manually-operated dampers. When the fuel cask ventilation system is not in operation, the manual isolation dampers for the flexible hose connections are maintained in a closed position. When operating, the roof fans ventilate the decontamination building, the filter bypass centrifugal fan ventilates the GWST area, and the filtration assembly and second centrifugal fan are available for spent fuel cask venting. In the event of radiation detection in the roof exhaust, the roof fans are

automatically shut off. Radiation detection in the exhaust stack from exhaust originating in the GWST area will automatically close the filter bypass flow path and open the

filtration assembly flow path. The decontamination building and GWST area are cooled and

ventilated by outside air. The decontamination building is heated by centrifugal fan air flow across hot water heaters. The GWST area is heated by explosion-proof, forced air electric

heaters. BVPS-2 UFSAR Rev. 8 9.4-58 9.4.13.3 Safety Evaluation The decontamination building and GWST area ventilation systems are nonsafety-related.

Exhaust air from the decontamination building is radiation-monitored at the roof exhaust. Exhaust air from the GWST

area and from spent fuel cask venting is radiation-monitored in the exhaust stack.

Two redundant roof fans exhaust air from a common ductwork in the decontamination building. The filtration and exhaust subsystem is equipped with a cross-over between the two flow paths and centrifugal fans, thereby making the centrifugal fans redundant. The fans may each be utilized for either the filtration or the bypass flow path.

The required filtration assembly air-residence condition is maintained by an upstream modulating damper and a controlling flow element. Pressure differential indicators within the filtration assembly monitor filter buildup. Fire detectors within the filtration assembly monitor filter temperatures.

9.4.13.4 Inspection and Testing Requirements

The system is inspected after installation to ensure that the equipment is properly installed and operates correctly.

The system is tested and balanced after installation. Preliminary tests are performed as described in Section 14.2.12. The ventilation system with the exception of the roof fans is in continuous operation and, as such, periodic inspection is not required. The roof fans are operated in conjunction with surveillance and calibration of the associated radiation monitor. Periodic routine surveillance and preventive

maintenance are performed at regular intervals. 9.4.13.5 Instrumentation Requirements

Control switches with indicating lights are provided for the two powered roof ventilation fans, on the decontamination building temperature control panel located in the decontamination building.

An air intake damper opens when either of the powered roof ventilation fans are operating and closes when the powered roof ventilation fans are not operating.

Control switches are also provided on the decontamination building filtration and exhaust panel for the unfiltered and filtered exhaust from the GWST area and decontamination building ventilation fans.

BVPS-2 UFSAR Rev. 0 9.4-58a Dampers on the intake of these fans will open while the respective ventilation fan is operating and close when the respective ventilation fan is not operating.

BVPS-2 UFSAR Rev. 8 9.4-59 A damper on the intake of the filtration unit is operated automatically by flow controllers on the intake of the filtration unit.

Flow indicators are mounted on the air flow control panel in the decontamination building to monitor the exhaust ventilated by the power roof ventilation fans, and the

filtered and unfiltered exhaust ventilation fans. Radiation monitors are provided to monitor the exhaust flow of the powered roof ventilation fans and the filtered and unfiltered exhaust ventilation fans. The airborne concentrations are provided at the radiation monitoring cabinet in the main control room. A low radiation signal will cause the shutdown of the normal exhaust ventilation fan associated with the exhaust flow, and start the filter exhaust fan. A high radiation level is alarmed at the decontamination building temperature control panel, and will cause the filter exhaust fan to shutdown. Annunciation is also provided at the building services control panel in the main control room to indicate high radiation in the decontamination building, dirty filters on the filtration unit, and high temperature and a high-high temperature in the charcoal filter bed.

Low air flow from the GWST area or no air flow from the filtered and unfiltered ventilation fans are alarmed at the

building services control panel and are monitored by the BVPS-2 computer system.

9.4.14 Cooling Tower Pumphouse Ventilation System The cooling tower pumphouse ventilation system maintains a suitable environment for proper equipment operation and personnel access under normal conditions. The system is not safety-related and is designated as NNS class.

9.4.14.1 Design Bases

The cooling tower pumphouse ventilation system design is based on the following: 1.General Design Criterion 2, as it relates to the system being capable of withstanding the effects of natural phenomena, as established in Chapters 2 and

3.

2.General Design Criterion 5, as it relates to shared

systems. No portion of the system is shared.

3.Regulatory Guide 1.26, as it relates to the quality

group classification system components.

BVPS-2 UFSAR Rev. 12 9.4-60 4. Regulatory Guide 1.29, as it relates to the seismic design classification of systems and components. The cooling tower pumphouse ventilation system is nonseismic.

5. The system maintains an ambient temperature below 104 F during the summer and above 60F in the winter, coincident with outdoor design temperatures.

9.4.14.2 System Description The principal system component design parameters and performance characteristics are given in Table 9.4-24. The cooling tower pumphouse ventilation system uses outdoor air for cooling the area. The ventilation system consists of two 100-percent capacity supply fans, four power roof ventilators, motorized intake and return air dampers, and distribution ductwork. Return and intake air dampers are modulated to keep a constant supply air temperature. Supply fans are started manually and normally run continuously. Power roof ventilators are started and stopped automatically, according to the position of the dampers, such that the same amount of outside air supplied in the cooling

tower pumphouse can be exhausted into the atmosphere. Heating is provided by electric unit heaters installed in the

area and controlled by wall-mounted thermostats. 9.4.14.3 Safety Evaluation

The cooling tower pumphouse ventilation system is nonsafety-related and is designated NSS class.

9.4.14.4 Inspection and Testing Requirements

The cooling tower pumphouse ventilation system is inspected, tested, and air-balanced after installation.

Since the system is continuously in use, periodic tests beyond the normal observations and inspections in a maintenance program are not required.

Preliminary testing requirements are contained in Section 14.2.12. 9.4.14.5 Instrumentation Requirements

Control switches with indicating lights for the cooling tower pumphouse ventilation system are located on a local panel. During normal operation, each supply fan runs continuously. The outdoor air and return air dampers are modulated by a supply air thermostat to maintain a constant supply air temperature. The power roof

BVPS-2 UFSAR Rev. 12 9.4-61 ventilators start automatically as the outdoor air supply dampers reach predetermined positions. Cooling tower pumphouse ventilation system trouble alarms are provided in the main control room and are also monitored by the plant computer

system. 9.4.15 Gland Seal Steam Exhaust Ventilation System

The gland seal steam exhaust ventilation system directs the air from the gland seal steam condenser for monitoring before releasing it to the atmosphere. This system is not safety-related and is designated as NNS class.

9.4.15.1 Design Bases The gland seal steam exhaust system design is based on the

following:

1. General Design Criterion 2, as it relates to the system being capable of withstanding the effects of

natural phenomena, as established in Chapters 2 and 3.

2. General Design Criterion 5, as it relates to shared systems. No portion of the gland seal steam exhaust

ventilation system is shared.

3. Deleted

4. Regulatory Guide 1.26, as it relates to the quality group classification of system components.

5. Regulatory Guide 1.29, as it relates to the seismic design classification of systems and components. The discharge of the gland seal steam exhaust ventilation system is designed in accordance with Seismic Category II criteria.

6. Two 100-percent capacity gland steam filter exhaust fans are included in the system. The filter exhaust fans are not normally used because the gland steam exhausters provide sufficient system flow.

9.4.15.2 System Description

The principal system components and design parameters are given in Table 9.4-25. The system consists of two 100-percent capacity centrifugal exhaust fans, dampers, and related ductwork. Air is supplied to the moisture separator-electric heating coil by the exhaust fan and is released to the atmosphere via the ventilation vent of the normal exhaust flow path of the SLCRS. An electric heating

coil in each bank can raise the gland seal steam exhaust temperature by the amount required to lower the relative humidity to 70 percent or less. A moisture separator is located upstream of the electric heating coil to remove water particles from the air prior to being heated and filtered.

BVPS-2 UFSAR Rev. 12 9.4-62 9.4.15.3 Safety Evaluation This system is nonsafety-related and is not required to perform any safety-related function.

Since the gland seal steam exhaust system consists of two redundant 100 percent capacity systems, only half of the system

is required to be in operation to accomplish its function. Radiation monitors in the main stack vent of the SLCRS will detect any radioactive particulate or gaseous activity. 9.4.15.4 Inspection and Testing Requirements

The system is inspected, tested, and air balanced after installation.

The system is in continuous operation. Periodic operation of the standby equipment in conjunction with routine observation

and maintenance during normal operation are sufficient to ensure system availability.

Preliminary tests are performed as described in Section 14.2.12. 9.4.15.5 Instrumentation Requirements

Control switches with indicating lights are provided locally for the gland seal steam exhaust fans. This system is operated manually. Electric heaters are provided upstream of the filter bank to control moisture content of the gland seal steam exhaust. The electric heaters are controlled automatically by means of a moisture switch located upstream in the ductwork. Radiation monitors are provided in the main vent stack of the SLCRS as described in Section 6.5.3.2.

BVPS-2 UFSAR Rev. 16 9.4-63 Electric heating coils will be energized by moisture switches when the moisture content of the air exceeds the setting of the moisture controllers, as sensed by moisture transmitters located in the ductworks upstream of the heating coil. The coil stays energized as long as the incoming air moisture exceeds the controller setting. Continuous readings of relative humidity are indicated by moisture indicating gauges.

9.4.16 Condensate Polishing Building Ventilation System

The condensate polishing building ventilation system ventilates, removes heat, and maintains a suitable environment for personnel access and equipment operation under normal conditions. The

system also filters, before releasing to the atmosphere, air that may contain gaseous and particulate contaminants. The system is nonsafety-related and is designated as NNS class.

9.4.16.1 Design Basis

The condensate polishing building ventilation system is designed in accordance with the following criteria:

1. General Design Criterion 2, as it relates to the system being capable of withstanding the effects of

natural phenomena, as established in Chapters 2 and 3.

2. General Design Criterion 5, as it relates to shared systems. No portion of this system is shared.

3. General Design Criterion 60, as it relates to the system's capability to suitably control release of gaseous radioactive effluent to the environment.

4. Regulatory Guide 1.26, as it relates to the quality group classification of system components.

5. Regulatory Guide 1.29, as it relates to the seismic design classification of systems and components. The condensate polishing building ventilation system is not seismically supported.

6. Regulatory Guide 1.140, as it relates to the design for normal ventilation exhaust system air filtration units. The operation of such systems, also under RG 1.140, is controlled manually as circumstances require. 7. The system will maintain the ambient temperature below 104F during the summer and above 60F during winter, in the general areas, and at 75F in the condensate polishing building control room, coincident with outdoor design temperatures.

BVPS-2 UFSAR Rev. 16 9.4-64 9.4.16.2 System Description The principal system components and design parameters are given in Table 9.4-26. The building is ventilated by a general areas ventilation system. In addition to this system, the equipment room and the elevator machinery room are provided with their own local ventilation systems. The condensate polishing building control room has a separate air- conditioning system.

The general areas ventilation system for the condensate polishing building consists of one supply subsystem and three exhaust subsystems: the normal exhaust, the cubicle exhaust, and the process air exhaust.

The supply subsystem provides all general areas of the building with outdoor air during summer, and a mixture of outdoor and return air during winter. The subsystem consists of one automatic roll filter, one face and bypass reheat coil, one centrifugal fan, associated ductwork, and modulating dampers.

The normal exhaust subsystem draws air from the noncontaminated cubicles and discharges it either to the atmosphere, via the main ventilation stack, or to the supply subsystem for

recirculation. The mode of operation and the amount of return air are achieved by air- operated dampers which are thermostatically controlled. The subsystem consists of one

axial fan, associated ductwork, and dampers. The cubicle exhaust subsystem exhausts air from the cubicles

that may contain contaminated particulates and filters it before discharging it to the main ventilation stack into the atmosphere. The subsystem consists of one centrifugal fan with variable inlet vanes, associated ductwork, controls, and one filtration assembly containing one pre- filter bank and one HEPA bank. The process air exhaust subsystem filters and exhausts air that may contain gaseous contaminants. The air is released and drawn

from the process equipment located in the building and from fume hoods located in the primary chemical laboratory. The subsystem consists of one centrifugal fan that draws the air through one filtration assembly and discharges it into the atmosphere via the ventilation stack. The filtration assembly consists of one moisture separator, one electric heating coil, one charcoal gasketless adsorber, and two HEPA banks, one upstream and one downstream of the charcoal bank. The electric heating coil raises the air temperature by the amount required to lower the relative humidity to 70 percent or less, to ensure maximum charcoal efficiency.

The elevator machinery room ventilation system consists of one propeller exhaust fan, one motor-operated outdoor air damper, and one motor-operated exhaust air damper, all mounted on the

wall. The system operates (dampers open, fan starts) and stops (the reverse) as dictated by the thermostat located in the room.

BVPS-2 UFSAR Rev. 16 9.4-65 The equipment room ventilation system consists of one motor-operated outdoor air intake damper and two roof exhaust fans with backdraft dampers, all thermostatically controlled. The

roof exhaust fans will start in sequence on a rise in temperature, and the outdoor air damper will open when the first fan starts. On a decrease in the room temperature, the reverse

occurs. The system can also be started and stopped manually. The condensate polishing building control room will be air-conditioned by the 100 percent air-conditioning unit. This unit contains one fan, one roll filter, and one cooling coil using chilled water (Section 9.2.2.2). The unit supplies a mixture of outside and return air. During summer, the supply air is cooled by the chilled water cooling coil, which is thermostatically controlled by a temperature control valve. Air is heated during

winter by the electric duct heater installed in the supply duct and controlled thermostatically.

9.4.16.3 Safety Evaluation The condensate polishing building air-conditioning system is

nonsafety-related and is not required to perform any safety-related function.

The areas which may contain radioactive contaminants are kept under a slightly negative pressure. Continuous infiltration is ensured from the noncontaminated areas toward the potentially contaminated areas. Areas that do not normally contain contamination may have their ventilation fans run intermittently if not credited for radionuclide filtration (e.g. Cubicle Exhaust Fans).

The required filtration assembly air residence time is

maintained in the process air filtration assembly by controlling the air flow with an upstream modulating damper and flow element. Fire detectors within the filtration assembly monitor filter temperatures. Fire protection is provided for the charcoal filter bank, as described in Section 9.5.1.

In the cubicle filtration assembly, the proper residence time for filter utilization is achieved by the exhaust fan variable inlet vanes, controlled by a downstream flow element.

Condensate from filtration assemblies is collected in a seal tank in the condensate polishing building. The tank discharges

into the equipment drains system, as described in Section 9.3.3. Pressure differential indicators within each filtration assembly monitor filter buildup. Exhaust air from all three exhaust subsystems is monitored by off-line gas and particulate detectors prior to being released to the environment through the ventilation stack, as described in Section 11.5. All three exhaust fans will be interlocked to stop on high radiation signal. Additional monitoring for radiation is also provided in

the ductwork that exhausts the recovery filter areas.

BVPS-2 UFSAR Rev. 16 9.4-66 9.4.16.4 Inspection and Testing Requirements The ventilation systems are inspected after installation to

ensure that the equipment is properly installed and operates correctly. The systems are tested and balanced after installation. Preliminary tests are performed as described in

Section 14.2.12. 9.4.16.5 Instrumentation Requirements

Control switches with indicating lights for the process air filtration exhaust fan are provided at the local airflow control

panel. The process air filtration exhaust fan can be operated manually or automatically. Automatically, the fan will start and its associated air operated damper will open, provided the supply subsystem fan is running, and will stop and close the damper when the supply subsystem fan is stopped. A moisture transmitter is provided to send a signal to the electric heating coil to maintain the relative humidity in the filtration

assembly. Annunciation is provided at the building service control panel

in the main control room for process air filtration exhaust fan auto trip, process air filtration exhaust fan low airflow, process air filtration system high temperature charcoal filter, process air filtration system high/high temperature charcoal filter, high pressure differential across process air filtration system filters and moisture separator, and process air filtration system high humidity. All of the preceding are annunciated by a common trouble alarm, and are also monitored by the BVPS-2 computer.

Indicators are provided on the local air flow panel for process air discharge air flow. Control switches with indicating lights for the cubicle exhaust air filtration fan are provided at the local airflow control

panel. The cubicle exhaust fan is manually started and stopped from the local airflow control panel. Starting the fan will open its respective air-operated damper and stopping the fan

will close the damper. Annunciation is provided at the building service control panel

in the main control room for cubicle exhaust fan auto trip, cubicle exhaust fan low air flow, and cubicle exhaust air filtration system filters high differential pressure. All of

the preceding are annunciated by a common trouble alarm, and are also monitored by the BVPS-2 computer.

BVPS-2 UFSAR Rev. 16 9.4-67 Indicators are provided on the local air flow panel for cubicle air discharge air flow.

Control switches with indicating lights for the normal air ventilation supply and exhaust fans are provided at the local normal air ventilation system temperature control panel.

The normal air ventilation supply and exhaust fans can be manually started and stopped from the local control panel. The respective air-operated dampers open and close when fans are

started and stopped. The normal air ventilation exhaust fan can be operated automatically. The fan will start when the supply fan is started and stopped when the supply fan is stopped.

Annunciation is provided at the building service control panel in the main control room for normal air ventilation supply fan auto trip, normal air ventilation exhaust fan auto trip, normal air ventilation supply fan roll filter high differential pressure, and normal air ventilation supply fan freeze

conditions. All of the preceding are annunciated by a common trouble alarm, and are also monitored by the BVPS-2 computer.

Indicators are provided on the normal air ventilation system temperature control panel for normal air ventilation discharge temperature and normal air ventilation mixed air temperature.

A control switch with indicating lights for the elevator machinery room propeller exhaust fan is provided locally. The elevator machinery room propeller exhaust fan can be operated manually or automatically. The associated dampers of this fan will open when the fan is started, and close when the fan is stopped. Automatically, the fan is started on a high temperature in the elevator machinery room and stopped on a low temperature in the elevator machinery room.

An annunciator is provided at the building service control panel in the main control room for elevator machinery room propeller

exhaust fan auto trip. This condition is annunciated by a common trouble alarm and is monitored by the BVPS-2 computer.

Control switches with indicating lights for the equipment room roof exhaust fans are provided locally. The equipment room roof exhaust fans can be operated manually or automatically. The

associated dampers of these fans will open when the fan is started, and close when the fan is stopped. Automatically, the fans are started on a high temperature in the equipment room and

stopped on a low temperature in the equipment room. An annunciator is provided at the building service control panel

in the main control room for equipment room roof exhaust fans auto trip. This condition is annunciated by a common trouble alarm and monitored by the BVPS-2 computer.

BVPS-2 UFSAR Rev. 0 9.4-68 A control switch with indicating lights for the condensate polishing building control room air-conditioning unit is provided. The air-conditioning unit is manually started and stopped. Annunciation is provided at the building service control panel in the main control room for condensate polishing building

control room air-conditioning unit auto trip and for control room filter dirty. These conditions are annunciated by a common trouble alarm. This air-conditioning unit's auto trip is also

monitored by the BVPS-2 computer. Indication is provided locally for condensate polishing building

control room temperature.

BVPS-2 UFSAR Tables for Section 9.4

BVPS-2 UFSAR Rev. 12 1 of 1 TABLE 9.4-1 PLANT VENTILATION SYSTEMS MODES OF OPERATION

Leak Collection 6.5-2 X X X X X X Control room area pressurization filtration 9.4-1 X X Control room area air-conditioning 9.4-1 X X X X X X Control building ventilation (cable tunnel, cable spreading, etc.) 9.4-2 X X X X X X Spent fuel pool ventilation 9.4-15 X X X X X Auxiliary building ventilation 9.4-4 X X X X Turbine building ventilation 9.4-7 X X X X Waste handling building ventilation 9.4-4 X X X X Emergency diesel generator building

ventilation 9.4-8 X X Containment atmosphere recirculation 9.4-9 X X X X Containment atmosphere filtration 9.4-9 X X Intake structure pump house ventilation 9.4-11 X X X X X X Main steam and feedwater valve area 9.4-12 X X X X X X Condensate polishing building ventilation - X X X X

BVPS-2 UFSAR Rev. 0 1 of 1 TABLE 9.4-2 CONTROL BUILDING AREA DESIGN TEMPERATURES

Room or Area Summer Temperature*

( F) Winter Temperature 

( F) Main control room area (el 735 ft 6 in) 75/75 75 Computer room (el 735 ft 6 in) 75/75 75 HVAC equipment room (el 735 ft 6 in) 104/104 75 MCC Room (el 707 ft 6 in) 104/120 65 Communication room (el 707 ft 6 in) 104/120 65 Cable tunnel (el 712 ft 6 in) 104/120 65 Cable spreading room (el 725 ft 6 in) 104/120 65 Instrumentation and

relay room 104/120 65

NOTE: *During normal plant operation/After DBA.

BVPS-2 UFSAR Rev. 4 1 of 1 TABLE 9.4-3 CONTROL BUILDING AIR-CONDITIONING AND VENTILATING SYSTEMS PRINCIPAL COMPONENTS AND DESIGN PARAMETERS

System Number of Units Capacity (cfm-each) Head (in WG) Motor (hp) Total Load (Btu/hr-each) Control room air-conditioning system Supply air, air-conditioning

units 2 18,000 7.8(SP)* 40 693,600 Emergency

supply fans 2 1,000 10.1(TP)** 5 ________ Control building air- conditioning

system Supply air

fans 2 13,000 6(TP)** 20 ________ Return air

fans 2 13,000 5(TP)** 20 ________ Cooling coil 1 13,000 ________ __ 581,000 NOTES: *Static pressure.

• • Total pressure.

BVPS-2 UFSAR Rev. 0 1 of 1 TABLE 9.4-5 CONTROL ROOM AREA VENTILATION SYSTEM OUTSIDE AIR RATES IN TERMS OF AIR CHANGES PER HOUR Room Air Changes (per hour)

Control Room 0.31 Computer Room 0.48 BVPS-2 UFSAR Rev. 0 1 of 1 TABLE 9.4-6 SPENT FUEL POOL AREA (FUEL BUILDING) VENTILATION SYSTEM PRINCIPAL COMPONENTS AND DESIGN PARAMETERS

Components Design Parameters

Recirculation Air-Conditioning Unit Fan Quantity Capacity (cfm) Static pressure (inch WG) Motor (hp)

1 20,000 4.25 30 Filter Quantity Pressure drop, clean/dirty (inch W/G)

1 0.16/0.55 Cooling Coils Quantity (number of coils/ACU) Capacity, total (MBH) Maximum water flow (gpm) 2 1,470 440 Heating Coils Quantity (number of coils/ACU) Capacity, total (MBH) Maximum water flow (gpm) 2 796 30 Unit Heaters Quantity Capacity, (MBH) each 13 1 @ 158 12 @ 70.5

BVPS-2 UFSAR Rev. 9 1 of 2 TABLE 9.4-7 AUXILIARY BUILDING AND RADWASTE AREA VENTILATION SYSTEM PRINCIPAL COMPONENTS AND DESIGN PARAMETERS

Components (Air Handling Units) Design Parameters

Supply Fans Quantity Capacity, (cfm) each Static pressure (in WG) Motor, (hp) each

2 28,200 8.5 60 Cooling Coils Quantity Capacity, (MBH) total Flow rate, (gpm) total 2 1,410 152 Heating Coils Quantity Capacity, (MBH) total Flow rate, (gpm) total 2 730 10 Radwaste Area Heating Coil Quantity Capacity, (MBH) Flow rate (gpm)

1 367 12 MCC Enclosure Fans Quantity Capacity, (cfm) each Static pressure (in WG) Motor, (hp) each 2 2,800 1.0 3 MCC Enclosure Cooling Coils Quantity Capacity, (MBH) each Flow rate, (gpm) each

2 26.7 15 Air Ejector/Charcoal Delay Bed

Recirculation Fans

Quantity Capacity, (cfm) each 2 5,700 BVPS-2 UFSAR Rev. 0 2 of 2 TABLE 9.4-7 (Cont) Components (Air Handling Units) Design Parameters Static pressure (in WG)

Motor, (hp) each 1.25 3 Air Ejector/Charcoal Delay Bed

Recirculation Cooling Coils Quantity Capacity, (MBH) each Flow rate, (gpm) each 2 40.7 7 Auxiliary Building Elevator Machinery

Room Fan Quantity Capacity (cfm) Static pressure (in WG) Motor (hp) 1 5,000 0.48 1 Post Accident Sampling System Cubicle

Self-Contained Air Conditioning Unit Quantity Capacity (cfm) Capacity (MBH) Static Pressure (in WG) Motor (hp) 1 1,000 22.0 0.59 1/5 BVPS-2 UFSAR Rev. 0 1 of 1 TABLE 9.4-8 TURBINE BUILDING VENTILATION SYSTEM PRINCIPAL COMPONENTS AND DESIGN PARAMETERS Component Parameters Supply Fans Turbine Room Walkway Quantity 2 1 Fan capacity, (cfm) each 125,000 2,533 Stator pressure (in WG) 5.5 0.125 Motor, (hp) each 150 1/4 Circulating Fans Quantity 2 - Capacity, (cfm) each 90,000 - Static pressure (in WG) free delivery - Motor, (hp) each 25 - Intake Dampers Turbine Building Wall Quantity Nine banks/2 each bank Hot Water Unit Heaters Quantity/capacity 11 @ 960 MBH each 4 @ 460 MBH each 1 @ 107.7 MBH each

Exhaust Fans Elevato r Mchry Room Turbine Bldg. Roof Battery Room Toilet Room Walkway Quantity 1 10 1 1 1 Capacity, (cfm) each 5,000 75,000 2,000 400 1,809 Static pressure (in WG) 0.48 free dlvy 2.0 2.0 free dlvy Motor, (hp) each 1 20 3 3/4 1/4

BVPS-2 UFSAR Rev. 0 1 of 1 TABLE 9.4-9 EMERGENCY DIESEL GENERATOR BUILDING VENTILATION SYSTEM PRINCIPAL COMPONENTS AND DESIGN PARAMETERS

Components Design Parameters

Normal Exhaust Fans Quantity Capacity, (cfm) each Total pressure (in WG) Motor, (hp) each

2 3,100* 0.43* 1 Primary Supply Fans Quantity Capacity, (cfm) each Total pressure (in WG) Motor, (hp) each 2 62,225* 2.19* 50 Secondary Supply Fans Quantity Capacity, (cfm) each Total pressure (in WG) Motor, (hp) each 2 36,300* 3.55* 50 Electric Unit Heaters (per room) Quantity/capacity

Quantity/capacity 4 at 25 kW each 1 at 5 kW each

• As Built Parameters BVPS-2 UFSAR Rev. 18 1 of 1 TABLE 9.4-10 CONTAINMENT ATMOSPHERE RECIRCULATION SYSTEM PERFORMANCE CHARACTERISTICS Function Performance Characteristics

Maximum containment

temperature allowed

108 F Number of units in operation

2 Single unit capacity cfm MBH 167,000 5,833 Total capacity cfm MBH 334,000 11,666

BVPS-2 UFSAR Rev. 15 1 of 1 TABLE 9.4-11 CONTAINMENT ATMOSPHERE RECIRCULATION SYSTEM PRINCIPAL COMPONENTS AND DESIGN PARAMETERS

Components Design Parameters

Containment Atmosphere Recirculation

Units Quantity Number of cooling coils per unit Number of fans per unit

Fan mode operation Cooling medium during normal operation 3 12 1 150,000 cfm/fan Chilled water Fan Total Pressure head (in WG) Motor, hp 9.3 300 BVPS-2 UFSAR Rev. 17 1 of 1 TABLE 9.4-12 DELETED BVPS-2 UFSAR Rev. 0 1 of 1 TABLE 9.4-13 CRDM VENTILATION SYSTEM PRINCIPAL COMPONENTS AND DESIGN PARAMETERS

Components Design Parameters

CRDM Fans Type Quantity Capacity, (scfm) each Total pressure (in WG) Motor, (hp) each Axial 6 22,000 14 75 Cooling Coils Quantity of coil banks Quantity of coils per coil bank Capacity, total heat load per coil bank (MBH) Primary component cooling water flow rate per coil bank (gpm) Entering air temperature ( F) dry bulb at 100 F entering water temperature 3 2 1,066 200 190 BVPS-2 UFSAR Rev. 0 1 of 1 TABLE 9.4-14 PRIMARY INTAKE STRUCTURE VENTILATION SYSTEM PRINCIPAL COMPONENTS AND DESIGN PARAMETERS

Components Design Parameters

Supply Fans

Quantity

Capacity, (cfm) each Static pressure (in WG)

Motor, (hp) each 3

7,500 1.4* 3 Unit Heaters Quantity Capacity, (MBH)/(kW) each

3 2 @ 17.1/5 kW

1 @ 51.2/15 kW

• As Built Parameters

BVPS-2 UFSAR Rev. 9 1 of 1 TABLE 9.4-15 ALTERNATE INTAKE STRUCTURE VENTILATION SYSTEM PRINCIPAL COMPONENTS AND DESIGN PARAMETERS

Components Design Parameters

Exhaust Fans

Quantity

Capacity, (cfm) each Static pressure (in WG)

Motor, (hp) each 2

20,000 1.0 10 Unit Heaters Quantity Capacity, (MBH) each

2 34.1 Propane Furnace Quantity

Capacity (MBH) 1

1,000

BVPS-2 UFSAR Rev. 12 1 of 1 TABLE 9.4-16 MAIN STEAM AND FEEDWATER VALVE AREA VENTILATION SYSTEM PRINCIPAL COMPONENTS AND DESIGN PARAMETERS

Supply Fans Quantity Capacity, (cfm) each Total pressure, (in WG) each Motor, (hp) each

2 31,400 8.9 75 Cooling Coils Quantity Capacity, (MBH) each Cooling water flow rate, (gpm) each Air entering temperature, ( F) dry bulb 2 985.5 85 120 Electric Unit Heaters Quantity Capacity, (MBH/kW) each

Quantity Capacity, (MBH/kW) each

5 76.7/25 1 21.1/7.5 Roll Filters Quantity Capacity, (cfm) each

2 31,400

BVPS-2 UFSAR Rev. 0 1 of 1 TABLE 9.4-17 NORMAL SWITCHGEAR AND CABLE SPREADING AREA VENTILATION SYSTEM PRINCIPAL COMPONENTS AND DESIGN PARAMETERS Components Design Parameters

Supply Fan Quantity Capacity (cfm) Total pressure (in WG) Motor, (hp) 1 117,000 5.8 150 Return-Exhaust Fan Quantity Capacity (cfm) Total pressure (in WG) Motor (hp)

1 114,300 5.5 150 Auto Roll Filters Quantity

Media 1 Glass fiber Electric Unit Heaters Quantity Capacity, (MBH) each

4 2 @ 17 2 @ 34 Hot Water Unit Heaters Quantity Capacity, (MBH) each

11 60

BVPS-2 UFSAR Rev. 0 1 of 1 TABLE 9.4-18 BATTERY ROOM VENTILATION SYSTEM PRINCIPAL COMPONENTS AND DESIGN PARAMETERS

Components Design Parameters

Exhaust Fans Quantity Capacity, (cfm) each Total pressure (in WG) Motor, (hp) each

2 7,500 4 7 1/2 BVPS-2 UFSAR Rev. 0 1 of 1 TABLE 9.4-19 EMERGENCY SWITCHGEAR ROOM VENTILATION SYSTEM PRINCIPAL COMPONENTS AND DESIGN PARAMETERS Components Design Parameters

Supply Fans Quantity Capacity, (cfm) each Total pressure (in WG) Motor, (hp) each 2 58,250* 4.4* 75 Exhaust Fans Quantity Capacity, (cfm) each Total pressure (in WG) Motor, (hp) each

2 53,450* 4.3* 60 Filters Quantity Media 1 Pleated Unit Heaters Quantity Capacity, (MBH) each

Coil type 8 2 @ 17 2 @ 34 4 @ 68 Electric

• As Built Parameters

BVPS-2 UFSAR Rev. 0 1 of 1 TABLE 9.4-20 SERVICE BUILDING EQUIPMENT ROOM VENTILATION SYSTEM PRINCIPAL COMPONENTS AND DESIGN PARAMETERS Components Design Parameters

Roof Exhaust Fans Quantity Capacity, (cfm) each Static pressure, (in WG) each Motor, (hp) each 2 25,000 0.25 7 1/2 Horizontal Unit Heaters Quantity MBH (each) Coil Type 11 60 Hot water

BVPS-2 UFSAR Rev. 9 1 of 1 TABLE 9.4-21 SAFEGUARDS AREA VENTILATION SYSTEM PRINCIPAL COMPONENTS AND DESIGN PARAMETERS

Components Design Parameters

Air Handling Units Quantity Capacity, (cfm) each Static pressure, (in WG) Motor, (hp) each

2 16,000 3.9 20 Cooling Coils Capacity (MBH) Face velocity (fpm) Leaving air temp dry bulb ( F) Water flow rate (gpm) 430 801 96.2 175 Electric Unit Heaters Quantity Capacity, (MBH) each 12 4 @ 25.6 4 @ 34.1 2 @ 42.6 2 @ 51.2

BVPS-2 UFSAR Rev. 8 1 of 2 TABLE 9.4-22 CABLE VAULT AND ROD CONTROL AREA VENTILATION SYSTEMS PRINCIPAL COMPONENTS AND APPROXIMATE DESIGN PARAMETERS

Components Design Parameters

Primary Ventilation System Air-Conditioning Units Quantity Capacity, (cfm) each Static pressure (in WG) Motor, (hp) each Filter pressure drop Clean/Dirty (in WG) 2 15,000 6.5 25 0.2/0.5 Chilled Water Coil for Air-Conditioning Unit Capacity (MBH) Chilled water flow (gpm) 959.8 295.3 Service Water Cooling Coil for Air Conditioning Unit Capacity (MBH) Service water flow (gpm) 414 0 Heating Coil for Air-Conditioning Unit Capacity (MBH) Hot water flow (gpm) 844 24.6 Secondary Ventilation System Cable Tunnel Unit Cooler Quantity Capacity (cfm) Static pressure (in WG) Motor (hp)

1 4,200 1.5 2 Chilled Water Coil for Cable Tunnel Unit Cooler Capacity (MBH) Chilled Water Flow (gpm)

324 57.5

BVPS-2 UFSAR Rev. 0 2 of 2 TABLE 9.4-22 (Cont) Components Design Parameters Cable Vault and Rod Control Area Unit Cooler Quantity Capacity (cfm) Static Pressure (in WG) Motor (hp) 1 4,700 1.3 2 Chilled Water Coil for Cable Vault and Rod Control Area Unit Cooler Capacity (MBH) Chilled Water Flow (gpm) 360 57.5 Alternate Shutdown Panel Room Ventilation System Self-Contained Air-Conditioning Unit Quantity Capacity (cfm) Static Pressure (in WG) Fan motor (hp) Compressor motor (hp) Filter pressure drop clean/dirty (in WG) 1 1,800 2 2 7 1/2 0.2/0.5 Direct Expansion Coil Capacity (MBH)

46 Condenser Capacity (MBH) Service water flow (gpm) 57 12

BVPS-2 UFSAR Rev. 0 1 of 1 TABLE 9.4-23 DECONTAMINATION BUILDING VENTILATION SYSTEM PRINCIPAL COMPONENTS AND DESIGN PARAMETERS

Components Design Parameters

Roof Ventilators Fans Quantity Capacity, (cfm) each Static pressure (in WG) Motor, (hp) each

2 4,350 0.25 1.5 Centrifugal Exhaust Fans Quantity Capacity, (cfm) each Static pressure, (in WG) Motor, (hp) each 2 1,000 11.75 5 Filtration Unit Quantity Capacity (cfm) 1 1,000 Prefilter Quantity Pressure drop, clean (in WG) Pressure drop, dirty (in WG)

1 0.5 1.0 HEPA Filter Quantity Pressure drop, clean (in WG) Pressure drop, dirty (in WG) 1 1.0

1.5 Charcoal

Filter Quantity Pressure drop, clean (in WG) Pressure drop, dirty (in WG) 1 1.0 1.0 Electric Duct Heater Quantity Capacity (kW) 1 5.0 BVPS-2 UFSAR Rev. 0 1 of 1 TABLE 9.4-24 COOLING TOWER PUMPHOUSE VENTILATION SYSTEM PRINCIPAL COMPONENTS AND APPROXIMATE DESIGN PARAMETERS

Components Design Parameters

Supply Fans Quantity Capacity, (cfm) each Total pressure (in WG) Motor, (hp) each

2 72,000 1.0 20 Roof Ventilators Quantity Capacity, (cfm) each Static pressure (in WG) Motor, (hp) each 4 36,000 Minimal 5

BVPS-2 UFSAR Rev. 12 1 of 1 TABLE 9.4-25 GLAND SEAL STEAM EXHAUST SYSTEM PRINCIPAL COMPONENTS AND DESIGN PARAMETERS

Exhaust Fans Quantity Capacity, (cfm) each Total pressure (in WG) Motor, (hp) each

2 750 9.96 3 Electric Heaters Quantity kW (each)

2 4 Backdraft Dampers Quantity

2 Air Control Dampers Quantity 2 Moisture Separators Quantity Centrifugal Water Separator with drain trap 2 1 BVPS-2 UFSAR Rev. 0 1 of 3 TABLE 9.4-26 CONDENSATE POLISHING BUILDING VENTILATION SYSTEM PRINCIPAL COMPONENTS AND DESIGN PARAMETERS

Components Design Parameters

Supply Subsystem: Supply Fan Quantity Capacity (cfm) Static pressure (in WG) Motor (hp)

1 18,540 3.75 40 Roll Filter Quantity Capacity (cfm) Pressure drop, clean/dirty (in WG) 1 25,300 0.4/0.5 Preheat Coil Quantity Capacity (MBH) 1 960.6 Normal Exhaust Subsystem: Exhaust Fan Quantity Capacity (cfm) Static pressure (in WG) Motor (hp) 1 12,205 5.26 25 Cubicle Exhaust Subsystem: Exhaust Fan Quantity Capacity (cfm) Total pressure (in WG) Motor (hp)

1 8,140 10.75 25 BVPS-2 UFSAR Rev. 2 2 of 3 TABLE 9.4-26 (Cont) Components Design Parameters Filter Assembly Quantity Number of prefilters Prefilter bank pressure drop, clean/dirty (in WG) Number of HEPA HEPA bank pressure drop, clean/dirty (in WG)

1 9 0.25/1.0

9 1.0/4.0 Process Air Exhaust Subsystem: Exhaust Fan Quantity Capacity (cfm) Static pressure (in WG) Motor (hp) 1 5,276 14.50 30 Moisture Separator Quantity Number of Moisture separators Moisture separator bank pressure drop, clean/dirty (in WG) 1 6 1.0/2.0 Electric Heating Coil Quantity Capacity (kW) Number of stages Number of HEPA upstream charcoal bank HEPA bank pressure drop, clean/dirty (in WG) Charcoal filtration bank, quantity Type of charcoal absorber Charcoal filter bank pressure drop, clean/dirty (in WG) Number of HEPA downstream charcoal bank HEPA filter bank pressure drop, clean/dirty (in WG)

1 24 2 6 1.0/4.0 1 Gasketless

1.5/1.5 6 1.0/4.0 BVPS-2 UFSAR Rev. 0 3 of 3 TABLE 9.4-26 (Cont)

Components Design Parameters Elevator Machinery Room Ventilation System: Exhaust Fan

Quantity Capacity (cfm) Total pressure (in WG) Motor (hp)

1 5,000 0.48 1 Equipment Room Ventilation System: Exhaust Fan Quantity Capacity (cfm) each Total pressure (in WG) Motor, (hp) each 2 1,975 0.5 0.75 Condensate Polishing Building Air-Conditioning System: Air-Conditioning Unit Quantity Fan capacity (cfm) Fan total pressure (in WG) Auto roll filter pressure drop, clean/dirty (in WG) Cooling coil quantity Cooling coil capacity (MBH) 1 11,000 4.0 0.17/0.55 1 828 Electric Reheat Coil Quantity Capacity (kW) Number of stages 1 13.5 1 MOD 2048 NC REFRIGERANT CONDENSING UNIT CONTROL ROOM REFRIGERANT AND SW PIPING -SYSTEM B IS SHOWN SYSTEM A IS SIMILAR REV. 12 NOTE: ALL DAMPERS SHOWN ARE NORMALLY OPEN UNLESS OTHERWISE INDICATED LEGEND NC NORMALLY CLOSED T THROTTLED FO FAILS OPEN FC FAILS CLOSED SW SERVICE WATER MOD MOTOR OPERATED DAMPER 25B 25A ALL DAMPER. VALVE AND EQUIPMENT IDENTIFICATION NUMBERS ON THIS FIGURE ARE PRECEDED BY THE SYSTEM DESIGNATOR "2HVCH UNLESS OTHERWISE INDICATED. FIGURE 9. 4-1 COMPUTER AND CONTROL ROOM AIR-CONDITIONING AND VENTILATION SYSTEM

REFERENCE:

STATION DRAWINGS OM 44A-2 AND 3 BEAVER VALLEY POWER STATION UNIT NO. 2 UPDATED FINAL SAFETY ANALYSIS REPORT INTAKE OUTSIDE AIR AUXILIARY BUILDING NORTH WALL AUX Ill ARY -BUILDING WEST WALL 245 C0 2 PRESSURE RELIEF DAMPER MECHANICAL ROOM PRIMARY AUXILIARY BUILDING CONTROL BUILDING AND CABLE TUNNEL AREA CABLE TUNNEL AUXILIARY BUILDING CABLE TUNNEL CONTROL BUILDING ' ' ' ' CABLE SPREADING AREA CONTROL BUILDING MOTOR CONTROL CENTER ROOM CONTROL BUILDING REV. INSTRUMENT A Tl ON & RELAY ROOM CONTROL BUILDING 240 238 COMMUNICATIONS ROOM 12 ALL DAMPER AND EQUIPMENT IDENTIFICATION NUMBERS ON THIS FIGURE ARE PRECEDED BY THE SYSTEM DESIGNATOR u2HVC" UNLESS OTHERWISE INDICATED. FIGURE 9.4-2 CONTROL BUILDING VENTILATION SYSTEM

REFERENCE:

STATION DRAWING OM 44A-1 BEAVER VALLEY POWER STATION UNIT NO. 2 UPDATED FINAL SAFETY ANALYSIS REPORT 2058 AUXILIARY BLDG AND RADWASTE AREA EXHAUST AUXILIARY BLDG AND RADWASTE AREA EXHAUST FROM ACU211A COMPONENT COOLING PUMP GENERAL AREA EL. 735' -6" TO RMP-ROI310 2078 TO LEAK COLLECTION SYSTEM TO LEAK COLLECTION SYSTEM + + + CHARGING PUMP CUBICLES EL. 735' -6" FROM ACU2116 235 FROM POST ACCIDENT SAMPLING FROM POST ACCIDENT SAMPLING SYSTEM CUBICLE 2148 TO LEAK COLLECTION SYSTEM 755'-6" ELEVATION TO ROI306 ALL DAMPER. VALVE AND EQUIPMENT IDENTIFICATION NUMBERS ON THIS FIGURE ARE PRECEDED BY THE SYSTEM DESIGNATOR u2HVP" UNLESS OTHERWISE INDICATED. FIGURE 9.4-4 AUXILIARY BUILDING AIR-CONDITIONING AND VENTILATION SYSTEM SAFETY RELATED EQUIPMENT

REFERENCE:

STATION DRAWINGS OM 44D-1 & 2 BEAVER VALLEY POWER STATION UNIT NO. 2 UPDATED FINAL SAFETY ANALYSIS REPORT I OUTSIDE AIR TURBINE BUILDING SUPPLY FN267 SERVICE BUILDING 2HVP-FN268 AUXILIARY BUILDING EXHAUST TURBINE.SERVJCE & AUXILIARY BUILDING ENCLOSED WALKWAY OUTSIDE AIR TURBINE __.. BUILDING TURBINE BUILDING ... TURBINE BUILDING TOILET ROOM OUTSIDE EXHAUST.._ FN2'-15 TURBINE ROOM WEST SUPPLY FAN TO DISTRIBUTION DUCTWORK FN249 DOOR....._ AIR LOUVER INTAKE REV. 1 2 I 21?E ...,_.___ I OUTSIDE AIR ...,_.___ J TYPICAL OF TURBINE __.. 9 DAMPERS BUILDING 21A-H AND J. AND 9 DAMPERS 22A-H AND J. t RETURN.-___ F_N_24_6 __ _, TURBINE BUILDING BATTERY ROOM OUTSIDE AIR ALL DAMPER AND EQUIPMENT IDENTIFICATION NUMBERS ON THIS FIGURE ARE PRECEDED BY THE SYSTEM DESIGNATOR u2HVT" UNLESS OTHERWISE INDICATED. AIR ill t RETURN AIR TURBINE ROOM EAST SUPPLY FAN TO DISTRIBUTION DUCTWORK F I GURE 9. 4 -7 TURBINE BUILDING VENTILATION SYSTEMS

REFERENCE:

STATION DRAWING OM 44F-2 & 5 BEAVER VALLEY POWER STATION UNIT NO. 2 UPDATED FINAL SAFETY ANALYSIS REPORT / OUTSIDE AIR 22A PLENUM 23A PLENUM 238 + RETURN AIR INTAKE FN271A SECONDARY SUPPLY FAN FN270A PRIMARY SUPPLY FAN SECONDARY SUPPLY FAN FN2708 PRIMARY SUPPLY FAN TO SUPPLY AIR DISTRIBUTION DUCTWORK TO SUPPLY AIR DISTRIBUTION DUCTWORK TO SUPPLY AIR DZSTRIBUTION DUCTWORK FN222A 21A NORMAL EXHAUST FAN FN2228 NORMAL EXHAUST FAN 218 FIGURE 9.4-8 REV. 12 PLENUM OUTS IDE PLENUM OUTSIDE ALL D-AMPER AND EQUIPMENT IDENTIFICATION NUMBERS ON THIS FIGURE ARE PRECEDED EMERGENCY DIESEL GENERATOR BUILDING VENTILATION SYSTEM

REFERENCE:

STATION DRAWING OM 44F-4 BEAVER VALLEY POWER STATION UNIT NO. 2 UPDATED FINAL SAFETY ANALYSIS REPORT BY THE SYSTEM DESIGNATOR n2HVD" UNLESS OTHERWISE INDICATED. r------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------1 TO LEAK COLLECTION NORMAL EXHAUST FANS OUTSIDE CONTAINMENT INSIDE CO TAINMENT EXHAUST AIR EXHAUST AIR COOLING COILS RECIRCULATION FANS RECIRCULATION UNIT FN211JIA FN201C COOLERS --"""=--.-__;;::ow CONTAINMENT AMBIENT AIR CONTAINMENT ATMOSPHERE RECIRCULATION SYSTEM TO CONTAINMENT AMBIENT AIR COOLING COILS COOLING COILS REV 17 TO OISTRIBUTION DUCTWORK PRIMARY COMPONENT COOLING WATER FROM AUXILIARY BUILDING VENTILATION SYSTEM AIR TO \.ll---t:::Kif-------,.-----::::::----CX}----+ OISTRIBUTION FROM FILTER SEPARATOR UNIT-I CONTAINMENT PURGE AIR SYSTEM HEADER FROM SHROUD FROM SHROUD FROM SHROUD CONTROL ROD DRIVE MECHANISM SHROUD VENTILALTION SYSTEM ALL DAMPER, VALVE AND EQUIPMENT IDENTIFICATION NUMBERS ON THIS FIGURE ARE PRECEDED BY THE SYSTEM DESIGNATOR '2HVR' UNLESS OTHERWISE INDICATED FIGURE 9.4-9 CONTAINMENT AREA VENTILATION SYSTEM

REFERENCE:

STATION DRAWINGS OM 44C-1 AND 2 BEAVER VALLEY POWER STATIION -UNIT No. 2 UPDATED FINAL SAFETY ANALYSIS REPORT OUTSIDE AIR T OUTSIDE AIR T OUTSIDE AIR T REV. 12 OUTSIDE 269A 269B FN269A FN2698 FROM UNIT_,.. RETURN AIR ' ' RETURN AIR FN257A SUPPLY FAN ' t RETURN AIR FN2578 SUPPLY FAN ' ' 1 AREA FN257C SUPPLY FAN CUBICLE FOR 2SWS-P21A CUBICLE FOR 2SWS-P21B CUBICLE FOR 2SWS-P21C PRIMARY INTAKE STRUCTURE VENTILATION ITEMS SHOWN WITHOUT MARK NUMBERS WERE FURNISHED WITH UNIT 1. t EXHAUST t FANS OUTSIDE ALTERNATE INTAKE STRUCTURE VENTILATION ALL DAMPER AND EQUIPMENT IDENTIFICATION NUMBERS ON THIS FIGURE ARE PRECEDED BY THE SYSTEM DESIGNATOR u2HVWu UNLESS OTHERWISE INDICATED. F I GURE 9. 4 -1 1 INTAKE STRUCTURE VENTILATION SYSTEMS

REFERENCE:

STATION DRAWING OM 44F-1 BEAVER VALLEY POWER STATION UNIT NO. 2 UPDATED FINAL SAFETY ANALYSIS REPORT I EQUIPMENT ROOM I SERVICE WATER SOUTH PUMP ROOM AUX STM GEN FEED PUMP QUENCH PUMP P21A SAFETY INJECTION PUMP P21A RSS PUMP CUBICLE "A" RSS PUMP CUBICLE "C" I EQUIPMENT ROOM I .___--L....,........_ __ __, SERVICE WATER NORTH PUMP ROOM AUX STM GEN FEED PUMP QUENCH PUMP P21B SAFETY INJECTION PUMP P21B REV. 12 RSS PUMP CUBICLE "D" + + RSS PUMP CUBICLE "B" SOUTH SAFEGUARDS AREA SUPPLY & RECIRCULATION NORTH SAFEGUARDS AREA SUPPLY & RECIRCULATION 2HVP-FN265A SCREENED I SCREENED OPENING OPENING 1--.. I I SERVICE WATER 2HVP-CLC265B 2HVP-FN265B 1--.-I SERVICE WATER HOT WATER CHILLED WATE I I :J z w _J a... DISTRIBUTION DUCTWORK CABLE VAULT BUILDING WEST WALL DISTRIBUTION DUCTWORK CABLE VAULT BUILDING SOUTH WALL MCC 2-E03 AND MCC RECIRCULATION SYSTEMS MINIMUM REQUIRED SAFEGUARDS DBA FLOW RATES RSS PUMP CUBICLES ABOVE EL. 718'-6" ANNULUS CEL. 718'-6"1 ANNULUS ( EL. 738 I -6") ALL OTHER AREAS 2005 CF M C EACH l 8106 CFM 1004 CFM 0 CFM 202B AUXILIARY BUILDING MAIN STEAM VALVE AREA PIPE TUNNEL PIPE TUNNEL AREA SUPPLY & RECIRCULATION t t t FAN ROOM COMPRESSOR AREA MAIN STEAM VALVE AREA SUPPLY & RECIRCULATION ALL DAMPER, VALVE AND EQUIPMENT IDENTIFICATION NUMBERS ON THIS FIGURE ARE PRECEDED BY THE SYSTEM DESIGNATOR "2HVR" UNLESS OTHERWISE INDICATED. FIGURE 9.4-12 MAIN STEAM. SAFEGUARDS. AND PIPE VENTILATION AND AIR-CONOJTIONING

REFERENCE:

STATION DRAWING OM 44B-1 BEAVER VALLEY POWER STATION UNIT NO. 2 UPDATED FINAL SAFETY ANALYSIS REPORT TUNNEL SYSTEM OUTSIDE AIR EXHAUST AIR FN261A FN 216A FN 216B EXHAUST FANS VENT EQUIP RM CONTIGUOUS AREAS 204A 2048 BATTERY ROOM 2-5 242 243 NORMAL + SWITCHGEAR AREA t CABLE SPREADING AREA REV. 12 239A 2398 219 + BATTERY + BATTERY ROOM 2-1 ROOM 2-3 + + 230A 2308 + + BATTERY ROOM 2-2 BATTERY ROOM 2-4 RETURN DUCTWORK OVERHEAD BATTERY ROOMS 2-1 & 2-3 T + TT D I STR l BUTION DUCTWORK OVERHEAD BATTERY ROOMS DISTRIBUTION DUCTWORK OVERHEAD BATTERY ROOMS 2-1 & 2-3 EMERGENCY SWITCHGEAR ROOM ORANGE SWGR PURPLE SWGR ALL DAMPER, VALVE AND EQUIPMENT IDENTIFICATION NUMBERS ON THIS FIGURE ARE PRECEDED BY THE SYSTEM DESIGNATOR u2HVZ" UNLESS OTHERWISE INDICATED. ROOM ROOM FIGURE 9.4-13 2-2 & 2-4 SERVICE BUILDING VENTILATION SYSTEM SAFETY RELATED EQUIPMENT

REFERENCE:

STATION DRAWING OM 44F-3 BEAVER VALLEY POWER STATION UNIT NO. 2 UPDATED FINAL SAFETY ANALYSIS REPORT HOT WATER SERVICE CHILLED :::J z w ..J a.. FLTA 244A HOT WATER SERVICE WATER ..,______,..._____, CHILLED WATER :::J z w _j 26B 0. 2HVP FL T 301 FLTA 244B VENT EQUIP ROOM PIPE TUNNEL ACU208A ACU208B ALTERNATE SHUTDOWN PANEL ROOM AIR CONDITIONING & VENT SYSTEM CONTl GUOUS AREA CABLE VAULT & ROD CONTROL AREA (EASTl CABLE VAULT & ROD CONTROL AREA !WEST! CABLE TUNNEL AUX AREA l RELAY T ROOM + CABLE VAULT & ROD CONTROL AREA !WEST> CHILLED WATER 239 REV. 12 CABLE VAULT & ROD CONTROL AREA SUPPLY AND RECIRCULATION 205A 205B ALL DAMPER. VALVE AND EQUIPMENT IDENTIFICATION NUMBERS ON THIS FIGURE ARE PRECEDED BY THE SYSTEM DESIGNATOR n2HVRn UNLESS OTHERWISE INDICATED. FIGURE 9,4-14 CABLE VAULT AND ROO CONTROL AREA AIR-CONDITIONING AND VENTILATION SYSTEMS

REFERENCE:

STATION DRAWING OM 448-3 BEAVER VALLEY POWER STATION UNIT NO. 2 UPDATED FINAL SAFETY ANALYSIS REPORT BVPS-2 UFSAR Rev. 16 9.5-1 9.5 OTHER AUXILIARY SYSTEMS 9.5.1 Fire Protection System

9.5.1.1 Design Bases The fire protection system (FPS) for Beaver Valley Power Station - Unit 2 (BVPS-2) has been designed such that any single fire will not cause an unacceptable risk to public health and safety, will not prevent the performance of necessary safe shutdown functions, and will not significantly increase the risk of radioactive release to the environment.

The FPS is designed using the guidance of Branch Technical Position (BTP) CMEB 9.5-1, Rev. 2, and the National Fire Codes and Standards of the National Fire Protection Association (NFPA). The versions of the NFPA Codes and Standards used in the design are indicated where they are referenced.

Additional criteria used in the design of the FPS are described as follows:

1. 10CFR50.48 and General Design Criterion 3, as they relate to the structures, systems, and components important to safety being designed and located so as to minimize and be consistent with other safety requirements and the probability and effect of fires and explosions. Noncombustible and heat resistant materials are used wherever practical throughout the unit, particularly in locations such as the reactor containment and main control room. Fire detection and

suppression systems of appropriate capacity and capability are provided and designed to minimize the adverse effects of fires on structures, systems, and components important to safety. Fire fighting systems are designed to assure that their rupture or inadvertent operation will not significantly impair the safety capability of these structures, systems, and components.

2. General Design Criterion 5, as it relates to shared systems. The yard fire loop is shared with Beaver

Valley Power Station - Unit 1 (BVPS-1).

3. Defense-in-Depth Criterion - For each fire hazard, a suitable combination of fire prevention, fire detection, and suppression capability is provided to withstand safely the effects of a fire.

4. Fire Suppression Capability and Capacity - Fire suppression capability is provided, with capacity adequate to extinguish any fire that can credibly occur and that can have adverse effects on equipment and components important to safety.

BVPS-2 UFSAR Rev. 15 9.5-2 5. Backup Fire Suppression Capability - Total reliance for fire protection is not placed on a single automatic fire suppression system. Appropriate backup fire suppression capability is provided.

6. Single Failure Criterion - The single failure criterion was applied to fire suppression systems that protect systems and equipment important to safety, including equipment required for safe shutdown. The single failure criterion is applied such that no single active failure shall result in complete loss of protection of both the primary and backup fire suppression capability.

7. Noncombustible aluminum and steel cable trays and conduits are used throughout. The design includes separation of trains, channels, and nonsafety cables into different cable trays. Suitable fire shields such as fire wrap materials, tray covers, and tray bottoms are provided to prevent common mode hazards to both safety systems.

8. Fire rated seals are provided where penetrations pass through fire rated floors and walls in safety-

related areas.

9. In general, samples of all power cables (including 5 kV and 600 V cables), 1 kV control cable & 300 V instrument cable were tested and, as a minimum, meet Institute of Electrical and Electronics Engineers (IEEE) Standard 383-1974 or similar industry testing for non-safety applications. (Refer to Section 8.3.3 for further details.)

10. Nuclear Electric Insurance Limited (NEIL) - Recommendations from NEIL will be reviewed and a position will be established which is mutually

agreeable.

9.5.1.2 Fire Protection Program Details

Based on guidance provided in Generic Letter 86-10, the provisions of the BVPS-2 Fire Protection Program (FPP) which normally would have been part of the BVPS-2 Technical Specifications have instead been incorporated into Section 9.5.1, Appendix 9.5A, and BVPS Administrative Procedures. As

stated in the BVPS-2 Safety Evaluation Report (NUREG 1057, Supplement No. 3), a condition of the BVPS-2 Operating License (Condition 2.F) requires the FPP to be implemented and

maintained. 9.5.1.2.1 Fire Protection Program

The FPP for BVPS-2 establishes the necessary policy for the protection of structures, systems, and components important to the safety of BVPS-2. The FPP includes procedures, equipment, and personnel required to implement the program.

BVPS-2 UFSAR Rev. 17 9.5-3 1. The basis for the design of the FPP is to provide defense in depth by achieving an adequate balance in:

a. Preventing fires from starting, b. Rapidly detecting, controlling, and extinguishing fires that occur, thus limiting fire damage, and

c. Providing protection for structures, systems, and components important to the safety of the plant so that a fire, if not promptly extinguished by the fire suppression systems and activities, would not prevent the safe shutdown of BVPS-2.

Certain areas of the plant have fire protection features or equipment that may be described in the UFSAR and/or associated NRC SER; however, this equipment is not specifically required for regulatory compliance to 50.48. Table 9.5-12 provides a list of these areas. A fire in any of those areas would not affect the ability to achieve safe shutdown, would not affect the ability to minimize and control a release of radioactivity, and the areas are not adjacent to safety related areas, and therefore, associated fire protection features are outside the scope of 50.48. 2. The FPP organization and responsibilities are as follows: a. UFSAR Sections 13.1 and 13.2 describe the departments responsible for administration of the

FPP and for related training.

b. The Site Fire Marshal is responsible for the day-to-day overall formulation, implementation, and assessment of the effectiveness of the FPP. The Site Fire Marshal shall meet the requirements for membership in the Society of Fire Protection

Engineers.

c. The Fire Protection Engineer is responsible for the fire protection safe shutdown evaluation. The Fire Protection Engineer shall meet the eligibility requirements for membership in the

Society of Fire Protection Engineers.

d. The fire brigade organization consists of qualified brigade members only. The minimum number of qualified members to be onsite at all times is five. The function of the fire brigade (also referred to as the emergency squad) is to execute the necessary actions during an emergency to alleviate or minimize the consequences of the

emergency. Minimum physical requirements are established for the fire brigade members. Physical

BVPS-2 UFSAR Rev. 16 9.5-4 examinations are conducted every 3 years and are reviewed by the Medical Department. Members of the brigade are assigned responsibility as follows: (1) The Brigade Chief has overall coordination responsibilities to ensure that all actions necessary to control and extinguish the fire

are undertaken.

(2) Additional brigade members carry out the orders of the Brigade Captain in controlling and extinguishing the fire and/or caring for the injured. 
(3) The Brigade Chief is authorized to commandeer any qualified employee to assist 

the brigade force when assistance is required. The brigade assistant(s) are responsible to perform the assigned tasks to the best of their ability without disruption to the brigade force.

(4) BVPS-2 designates certain individuals as fire marshalls. Only qualified brigade 

members and supervisors are considered. The

Fire Marshall aids in safely evacuating nonessential personnel from the area and assists the brigade in any way necessary to

alleviate and minimize the consequences of the fire emergency. The Fire Marshall, if required, may commandeer any qualified

employee for assistance.

3. The Operations Quality Assurance Program for fire protection items will be conducted in accordance with Section 9.5.1.5.

The FPP was developed using the appropriate NFPA publications and also using the recommendations of the Nuclear Electric Insurance Limited. 9.5.1.2.2 Fire Protection Evaluation

The BVPS-2 Fire Protection Evaluation Report (Appendix 9.5A) demonstrates the ability of BVPS-2 to achieve shutdown and minimize radioactivity release to the environment in the event

of a fire. The fire protection safe shutdown evaluation was performed by

qualified fire protection and reactor systems engineers. The fire protection evaluation discusses the following:

1. In situ and transient fires,

2. The consequences of a fire in any fire area, BVPS-2 UFSAR Rev. 0 9.5-5 3. Specific measures for fire protection, fire detection, fire suppression, and fire containment, and 4. Alternate shutdown capability required for each area.

Fires which may occur in shared facilities are evaluated in

Appendix 9.5A. Appendix 9.5A separately identifies, evaluates, and indicates

appropriate protection to be provided in locations where safety- related losses may occur as a result of one or more of the following:

1. Concentrations of combustibles, including transient combustible materials which may be used in normal operation, such as refueling, maintenance, and plant modifications, 2. Continuity of combustible contents, including furnishings, building materials, or combinations conducive to the spread of a fire,

3. Exposure fire, including heat, smoke, or water exposure, including those that may require evacuation from areas required to be attended to for safe shutdown, 4. Fires in the main control room and in safety-related areas,

5. Lack of access that may impede fire extinguishment in safety-related areas,

6. Lack of explosion-prevention measures,

7. Loss of electric power or control circuits, or

8. Inadvertent operation of the fire suppression system.

Appendix 9.5A establishes that the FPP objectives are met. Appendix 9.5A lists applicable elements of the program, with explanatory statements to identify location, type of system, and design criteria. The analysis identifies deviations from the regulatory guidelines which are discussed in Appendix 9.5A and describes and evaluates an equivalent level of protection. 9.5.1.2.3 Fire Protection Bases

9.5.1.2.3.1 Fire Detection Instrumentation

1. Operability of the fire detection instrumentation ensures that adequate warning capability is available for the prompt detection of fires. This capability is required in order to detect and locate fires in their early stages. Prompt detection of fires will reduce the potential for damage to safety-related equipment

BVPS-2 UFSAR Rev. 0 9.5-6 and is an integral element in the overall facility fire protection program.

2. In the event that a portion of the fire detection instrumentation is inoperable, the establishment of frequent fire patrols or in containment air temperature monitoring in the affected areas is required to provide detection capability until the inoperable instrumentation is restored to

operability. 9.5.1.2.3.2 Fire Suppression Systems

1. Total reliance is not placed in a single fire suppression system. Appropriate backup fire suppression is provided.

2. A single active failure or a crack in a moderate energy line in any fire suppression system does not impair the primary and/or backup fire suppression

capability.

3. The BVPS-2 fire suppression system is capable of delivering water to manual hose stations located within reach of areas containing safety-related equipment required for safe shutdown following a

safe shutdown earthquake (SSE).

4. The effects of lightning are included in the overall BVPS-2 FPP. Lightning grounds have been provided where necessary to prevent lightning from adversely

affecting the plant.

5. The consequences of inadvertent operation of the fire suppression systems have been addressed and inadvertent operation of the systems will not

prevent the safe shutdown of BVPS-2.

6. A fire occurring at both units simultaneously is beyond the design basis for the site. A fire spreading from one unit to the other is not

considered probable due to the following:

a. Plant design features and existing fire barriers relative to fire loadings in each fire area,

b. Physical separation between BVPS-1 and BVPS-2 plant structures with the exception of shared facilities (such as the intake structure and control building) as defined in Section 1.2.1

which meet, GDC 5, and

c. Defense-in-depth criterion utilized at both BVPS-1 and BVPS-2 relative to fire prevention, detection, and suppression capabilities.

7. Two full design capacity fire pumps, one motor-driven and one engine-driven, deliver water to the spray and sprinkler systems and to the yard distribution piping loop. The BVPS-2 UFSAR Rev. 13 9.5-6a design capacity of each fire pump is based on the maximum probable water demand imposed by the simultaneous operation of the turbine building sprinkler system and two fire hydrants. Fuel storage for the engine-driven fire pump is sufficient to permit operation of the engine for 8 hours. 8. The operability of the fire suppression systems ensures that adequate fire suppression capability is

available to confine and extinguish fires occurring in any portion of the facility where safety-related equipment is located. The fire suppression system

consists of the water system, spray and/or sprinklers, CO, halon and fire hose stations. The collective capability of the fire suppression systems is adequate to minimize potential damage to safety-related equipment and is a major element in the facility fire protection program.

9. In the event that portions of the fire suppression systems are inoperable, alternate backup firefighting equipment is required to be made available in the affected areas until the inoperable equipment is restored to service. When the

inoperable firefighting equipment is intended for use as a backup means of fire suppression, a longer period of time is allowed to provide an alternate means of fire fighting than if the inoperable equipment is the primary means of fire suppression.

10. The test requirements identified in BVPS Administrative Procedures provide assurance that the minimum operability requirements of the fire suppression systems are met. An allowance is made for ensuring a sufficient volume of halon in the halon storage tanks by verifying either the weight or the level of the tanks. The halon systems are indoor, underfloor cable area systems not susceptible to outdoor weather conditions The systems are dry pipe (rust is not expected) gas suppression systems.

11. In the event the fire suppression water system becomes inoperable, corrective measures must be taken as defined in administrative procedures since this system provides the major fire suppression capability of the plant.

9.5.1.2.3.3 Fire Rated Assemblies The operability of the fire barrier and barriers penetrations

ensure that fire damage will be limited. These design features minimize the possibility of a single fire involving more than one fire area prior to detection and extinguishment. The fire barriers, fire barrier penetrations for conduits, cable trays and piping, fire windows, fire BVPS-2 UFSAR Rev. 0 9.5-6b dampers, and fire doors are periodically inspected to verify their operability. 9.5.1.2.4 Alternative Shutdown

Alternative shutdown capability is provided where protection or separation of systems or equipment required for safe shutdown is not adequate. An alternate shutdown panel has been installed specifically for a fire in Fire Areas CB-1, CB-2, CB-3, CB-6, and CT-1. For a description of methods used to safely shut the

plant down, see Appendix 9.5A. 9.5.1.2.5 Implementation of Fire Protection Programs

1. The FPP (plans, personnel, and equipment) for buildings storing new reactor fuel will be fully operational before fuel is received at the site; A fire in adjacent fire areas will not affect the fuel storage area due to building design.

2. The FPP for the entire BVPS-2 reactor unit will be fully operational prior to initial fuel loading.

3. The FPP provides for continuing evaluation of fire hazards. 9.5.1.3 Administrative Controls

Administrative controls are used to maintain the performance of the FPS and personnel. Procedures will be developed to establish the following controls:

1. All waste, debris, scrap, rags, oil spills, or other unnecessary combustibles resulting from work activity in safety-related areas are to be removed and/or cleaned up as soon as possible.

BVPS-2 UFSAR Rev. 15 9.5-7 a. For noncontinuous work activities, highly combustible materials will be cleaned up at the end of the shift or activity, whichever is sooner.

b. Low hazard combustible material will be removed at the end of the work activity.

2. Approved trash containers are provided in safety-related areas.

3. Periodic inspections for accumulation of combustibles and transient fire loading during maintenance are conducted in safety-related areas in accordance with

housekeeping procedures.

4. Combustibles required for operation and maintenance in safety-related areas are stored in proper receptacles or approved storage cabinets. Stairwells are not used for storage of combustibles. Flammable liquids required for maintenance are issued only in fixed amounts and in approved containers.

5. Charcoal and particulate filters not stored in approved fire-retardant containers will be removed from safety-related areas as soon as possible or stored in areas serviced by a deluge spray or sprinkler system.

6. Transient combustible materials in safety-related areas will not be left unattended unless special provisions have been provided or the material is properly stored. The Site Fire Marshal will be contacted, if necessary, to specify additional fire protection for potential transient fire hazards that

cannot be avoided.

7. Work practices for the protection of safety-related equipment from fire damage or loss due to work involving ignition sources (such as welding, cutting, grinding, and open-flame work) will be established in accordance with the guidelines of BTP CMEB 9.5-1. Training of firewatch personnel in the use of fire extinguishing equipment will be undertaken.

8. All lumber and wood required for use in safety-related areas will be treated, and fire-retardant wood will be limited to temporary use. Large wooden timbers, or any special size or application-type lumber not available as treated wood, may be coated or wrapped

with an Underwriters' Laboratory (UL) listed fire-retardant compound or material. Exceptions are wood in the form of crates or shipping boxes (including any packing material) which will be removed as soon as possible after removal of equipment from boxes.

BVPS-2 UFSAR Rev. 13 9.5-8 9. Removal of permanent or portable fire protection equipment from service will be accomplished in accordance with approved administrative procedures.

10. Surveillance procedures are developed which periodically test the fire detection and suppression systems. Testing and inspection of the fire protection system is conducted in accordance with BVPS Administrative Procedures.

11. Control actions to be taken by an individual discovering a fire include immediate notification to the main control room, actuation of local alarms, and if the individual is qualified and trained to perform incipient-type firefighting actions, attempt to extinguish the fire with locally-placed fire

extinguishing equipment:

12. Control actions to be taken by the main control room operating staff include sounding the alarm, announcing the fire location over the plant page system, alerting the fire brigade and the Shift Supervisor, requesting evacuation of the area, placing the plant in a safe condition if the fire warrants, and checking the status of the fire protection

systems.

13. Control action to be taken by the fire brigade, after notification by the main control room operating staff of a fire, includes assembling in the brigade storage change area, receiving directions from the Brigade

Chief, selecting appropriate fire fighting equipment, and reporting to the fire scene.

14. The Brigade Chief is responsible to assess the fire, declare a fire emergency, and request offsite fire

assistance if necessary.

15. Strategies for fighting fires in all safety-related areas, and in areas presenting a hazard to safety related equipment, are defined. These strategies will designate:

a. Fire hazards in each area as identified in that area's prefire plan strategies.

b. The proper extinguishing agent for the type of fire.

c. The line of attack on the fire based on the speed and direction of fire spread, access to fire area, and degree of danger to life and

property.

BVPS-2 UFSAR Rev. 12 9.5-9 d. Vital heat-sensitive system components that need to be kept cool, in particular, hazardous combustibles that need cooling, will be designated.

e. All energized equipment that must be cleared (without losing the ability to safely shut down the plant) which may endanger safe execution of fire fighting activities of brigade personnel or could be damaged as a result of the fire.

f. Organization of the fire brigade and assignment of duties, according to job title, to cover all fire-fighting functions are covered by the shift complement. These duties include: initiating search and rescue operation;

establishing a command post; ensuring any installed fire system is activated; augmenting the brigade with available personnel or off-

site fire departments, if deemed necessary; determining the need to evacuate nonessential personnel; identifying escape routes to be

utilized; and maintaining communication with the main control room.

g. Potential radiological and toxic hazards in the fire area. A radiological control point will be established at the scene, if deemed necessary, to monitor the area to determine if a radiation hazard exists, and to monitor personnel and equipment leaving the area.

h. Ventilation system operation to eliminate spreading smoke to areas necessary for safe shutdown of the plant.

i. Operations requiring main control room operating staff and shift technical advisor coordination or authorization.

j. Instruction for BVPS-2 operating staff and general plant personnel during fires.

9.5.1.4 Fire Brigade The BVPS-2 fire brigade is organized, trained, and equipped in

the following manner:

1. The Emergency Preparedness Plan shall be followed when applicable.

2. A BVPS-2 fire brigade is established, trained, and equipped to execute the necessary actions during an emergency to alleviate or minimize the consequences. A minimum of five qualified brigade members per shift

will be onsite at all times. The Brigade Chief and at least two brigade members shall be operations personnel who have sufficient knowledge of safety-related BVPS-2 UFSAR Rev. 15 9.5-10 systems to understand the effects of a fire on the safe shutdown of the unit. Physical examinations are conducted as a minimum every 3 years to determine their ability to perform strenuous fire fighting. At least one member of the brigade will possess an operator's license. The Shift Supervisor will not be a member of the fire brigade. A deviation has been submitted for 3-year physical examination periods. Refer to Appendix 9.5A for justification.

3. The equipment provided for the brigade shall consist of personal protective equipment such as coats, gloves, boots, helmets, at least 10 approved self-contained breathing apparatus units with two reserve air bottles per unit, emergency communication equipment, portable lights and extinguishers, and portable ventilation units. Extra air bottles will be located onsite to replenish the self-contained breathing units.

4. The Nuclear Training Section is responsible for development, implementation, and revision of the fire training program, as well as coordinating, scheduling, and providing classroom training. The Site Fire Marshal shall assist the Nuclear Training Section in the implementation and assessment of fire protection training. This training will be accomplished in accordance with training manuals and regulations. The program shall consist of an initial classroom instruction program followed by periodic classroom instruction, fire fighting practice, and fire drills.

a. The training program includes instructions to all station personnel regarding immediate

actions to be taken upon discovery of a fire.

b. The fire brigade members are given regular training and practice in fire fighting and rescue routines, including radiological control practices, evacuation procedures, and escape routes to ensure that each member is thoroughly familiar with the steps to be taken in the event of a fire.

c. Fire Marshals are given periodic training in fire fighting and evacuation procedures, and escape routes as appropriate.

d. Classroom instructions, with training aids such as literature and other audio and/or visual aids, are provided to familiarize the members of the fire brigade with fire fighting

techniques and equipment.

e. Instruction shall be provided to all fire brigade members and the Fire Brigade Chief.

BVPS-2 UFSAR Rev. 15 9.5-11 5. Plant fire drills and critiques will be periodically scheduled and conducted in accordance with the fire training program. Each brigade squad will participate in at least four drills per year, which will include the use of fire protection and/or first aid equipment. Each fire brigade member will participate in at least two drills per year. Drills will periodically be held on back-shift, will be unannounced, and will include a critique as well as an assessment of equipment and brigade effectiveness. Unsatisfactory drill performance will be followed by a repeat drill within 30 days. Drills will provide for local fire department participation periodically.

All fire brigade personnel will participate in a retraining program over a 2-year period.

Individual training records for each fire brigade member, including drill critiques, will be maintained

for at least 3 years. The training records will be

used to determine where brigade members are deficient.

9.5.1.5 Augmented Quality Assurance Program

The fire protection procedure ensures that the guidelines for design, procurement, installation, testing, inspection, and administrative controls for the FPP are adequately reviewed and controlled.

9.5.1.5.1 Design and Procurement Document Control Measures have been established to assure that quality standards

and the applicable fire protection codes and standards are incorporated into design and procurement documents, and deviations therefrom are controlled.

9.5.1.5.2 Instructions, Procedures, and Drawings

Measures have been established to assure that inspections, tests, administrative controls, fire drills, and training that affect the FPS are prescribed by documented instructions, procedures, or drawings, and will be accomplished in accordance with these documents.

9.5.1.5.3 Control of Purchased Material, Equipment, and Services Measures have been established to assure that purchased material, equipment, and services are UL or Factory Mutual (FM) listed and/or conform to the requirements of Nuclear Electric Insurance Limited (NEIL) and NFPA Codes and Standards, unless otherwise specified.

BVPS-2 UFSAR Rev. 13 9.5-12 9.5.1.5.4 Inspection Measures have been established to provide for a program of independent inspection of activities affecting the FPS. The

program verifies conformance to documented installation drawings, testing, and procedures.

9.5.1.5.5 Test and Test Control Measures have been established and implemented to assure that testing is performed and verified by inspection to demonstrate conformance with design concepts. The testing and inspection are performed in accordance with BVPS Administrative Procedures. 9.5.1.5.6 Inspection, Test, and Operating Status

Measures have been established to provide for the identification of items that have satisfactorily passed required tests and inspections.

9.5.1.5.7 Nonconforming Items

Measures have been established to assure that the applicable guidelines of the fire protection procedures addressing the control of nonconforming items are included in activities affecting the FPS. 9.5.1.5.8 Corrective Action

Measures have been established to assure that the applicable guidelines of the fire protection procedures addressing corrective action are included in activities affecting the FPS. 9.5.1.5.9 Records

Measures have been established to assure that the applicable guidelines of the fire protection procedures addressing records are maintained and included in activities affecting the FPS. Records for the FPS are segregated from safety related records where so desired.

9.5.1.5.10 Audits

Audits are conducted and documented in a manner consistent with the fire protection procedure addressing audits to verify compliance with the FPP.

BVPS-2 UFSAR Rev. 8 9.5-13 9.5.1.6 General Plant Guidelines 9.5.1.6.1 Building Design

1. Fire barriers have a minimum fire resistance rating of 3 hours or meet the guidelines of BTP CMEB 9.5-1, Section C.5.b, "Safe Shutdown Capability" to:

a. Separate safety-related systems from any potential fires in nonsafety-related areas that could affect their ability to perform their safety function.

b. Separate redundant divisions or trains of safety-related systems from each other so that both are not subject to damage from a single fire.

c. Separate individual units on a multiple-unit site unless the requirements of General Design Criterion 5 are met with respect to fire, which would include the common control room and intake structure.

The structural steel which supports fire-rated walls in TB-1, PA-5, and SB-5 has a fire resistance capability in excess of the fire loading. A deviation

has been documented in Appendix 9.5A.

2. Refer to Appendix 9.5A for locations of fire areas.

3. Openings through fire barriers which separate the fire areas are sealed to provide fire resistance ratings equal to that required of the barrier. In addition, plant specific configurations are evaluated per the guidance provided in NRC Generic Letter 86-10 to demonstrate the acceptability of the barrier relative to the hazards of the area.

Specific internal conduit sealing requirements to control flame spread and propagation of combustible products (smoke and hot gases) have been established. The sealing requirements are similar to SRP guidelines, and justified deviations to the SRP are described in Section 9.5A.2, Item C.5.a(3). Fire barrier penetrations that must maintain environmental isolation or pressure differentials are qualified to maintain the barrier integrity.

Penetration designs utilize materials with fire-resistant or noncombustible properties and are qualified by tests. The penetration qualification tests use the time-temperature exposure curve

specified by ASTM E-119, Fire Test of

BVPS-2 UFSAR Rev. 11 9.5-14 Building Construction and Materials, and an external temperature limit of 325 F on the unaffected side.

4. Penetration openings in ventilation systems are protected by fire dampers having a rating equivalent

to that required of the barrier. This is accomplished by the use of two 1 l/2-hour fire rated dampers in series. Flexible air duct coupling in ventilation and filter systems is of the noncombustible type. A deviation for fire damper modifications has been documented in Appendix 9.5A.

5. Door openings in fire barriers are protected with equivalent fire rated doors, frames, and hardware. The doors are in accordance with UL requirements with the exception of security and other modifications as required for plant operation and door clearances. A deviation has been documented to justify these modifications (Refer to Appendix 9.5A).

The doors are self-closing, or provided with closing mechanisms, and are inspected to verify that automatic

hold-open, release, and closing mechanisms and latches

are operable.

Fire doors are alarmed and locked when they perform a security function. Fire doors are normally kept closed and are inspected to verify that they are in the closed position and that the doorways are free of

obstructions.

Two sliding steel fire doors (one on el 755 ft-6 in. of the auxiliary building and the other on el 718 ft-6 in. of the pipe tunnel) are normally open fire doors which have been provided with automatic releasing mechanisms. These doors are inspected daily to verify that doorways are free of obstructions. The fire brigade will have ready access to keys for any locked fire doors.

Areas protected by automatic total flooding gas suppression systems have self-closing fire doors which have been electrically supervised, locked closed, or maintained closed. A deviation for fire doors has been documented in Appendix 9.5A.

6. Personnel access routes and escape routes are provided for each fire area. Stairwells outside primary containment serving as escape routes, access routes for fire fighting, or access routes to areas containing equipment for safe shutdown are enclosed in masonry or concrete towers with a minimum fire rating of 2 hours except exterior walls and self-closing Class B fire doors.

BVPS-2 UFSAR Rev. 18 9.5-14a 7. All fire exit routes are clearly marked.

8. The BVPS-2 cable spreading room (CB-2) contains redundant safety divisions. Additionally, Fire Areas CB-1 and CT-1 are not separated from CB-2 by 3-hour fire rated barriers. However, postulating a fire in

CB-2, CB-1, and CT-1, BVPS-2 can be safely shut down

from the alternate shutdown panel (ASP) located at el

755 ft-6 in. of the auxiliary building/cable tunnel (Refer to Section 7.4.l.3). Cable spreading rooms are

not shared between units.

9. Interior wall and structural components in safety-related areas are generally steel, concrete, or

concrete block and are noncombustible. All insulation materials, including adhesives and tapes, are in accordance with NFPA 90A-1981. All pipe and duct insulation is listed by UL and has flame

spread and smoke developed ratings of not more than 25 and 50, respectively, in compliance with NFPA 90A-

1981. Interior coatings at BVPS-2 consist of epoxy or alkyd, enamel paint over concrete block, reinforced concrete

walls and slabs, or steel substrate. These coatings, in general, have flame spread ratings of less than 25

based on information available from coating

manufacturers.

10. Metal deck roof construction is made of materials conforming to requirements of Factory Mutual Class I.

BVPS-2 UFSAR Rev. 15 9.5-15 11. The suspended ceilings and metal grid support system are of noncombustible construction. The acoustical tile meets UL Class A requirements. Concealed ceiling spaces are void of combustibles.

12. All transformers located inside buildings are of the dry type.

13. All oil-filled major transformers (main, system, unit) located in the yard are provided with slag-filled sumps for cooling of hot oil. Sumps are of sufficient capacity to retain the total oil inventory associated with each transformer. Additional capacity to drain

the fire protection water is included.

All yard major transformers are protected by water deluge spray fire protection systems. These systems are automatically actuated by rate-compensated heat detectors. The two yard construction transformers are considered minor transformers (less than 2000 gallons insulating oil) and do not pose a significant hazard. Therefore, they are not protected with automatic suppression systems. They are, however, supplied with 9 inch deep

slag pits to aid in containing oil spillage.

The main transformer (TR-MT-2) and the station service transformers (TR-2C and 2D) on BVPS-2 are located less than 50 feet from the turbine building and condensate polishing building. This area of the turbine building is provided with insulated metal siding and 3-ply gypsum board design and the condensate polishing building is provided with a fire rated exterior door. The main transformer is separated from station service transformers TR-2C and 2D by 3-hour rated free standing partial height fire walls. Station service transformer TR-2B is located less than 50 feet west of the fuel building. The walls of the fuel building and cable tunnel in this area are 3-hour fire rated. The exterior doors to the cable tunnel stairwell and fuel building are 3-hour fire rated. Station service transformer TR-2A is located less than 50 feet east of the turbine building, separated by a fire wall. This area of the turbine building is provided with insulated metal siding and a 3-ply gypsum board designed with a 2-hour fire rating and nonrated exterior door. The diesel generator building has a 3-hour fire wall. The exterior door to the diesel generator building in this area is 3-hour fire

rated. BVPS-2 UFSAR Rev. 16 9.5-15a The turbine building houses no safety-related equipment credited as being required for safe shutdown as listed in UFSAR Table 3.2-1, although some equipment may have been procured to that standard or evaluated as such. The isolation provided by the remote location of the transformers from any safety-related equipment or areas precludes any possible effect from a transformer fire on the ability to attain shutdown.

A deviation from the 50 feet distance has been documented and justified (Refer to Appendix 9.5A).

BVPS-2 UFSAR Rev. 0 9.5-16 14. Floor drains are provided to remove fire protection water from all safety-related areas. Floor curbs are provided in some of the cable tray areas to minimize the spread of water. Where gaseous suppression systems are used, floor drains are provided with adequate seals by having the opening of the piping from the floor drains located below the normal water level in the drainage sumps, or the gaseous suppression system is sized to compensate

for the loss of suppressant.

Drains in areas of combustible liquids have provisions for preventing backflow of combustible liquids to safety-related areas through interconnecting drain piping. Water drainage from areas that may contain radioactivity is collected, sampled, and analyzed before discharge to the environment. 9.5.1.6.2 Safe Shutdown Capability BVPS-2 has conducted an analysis to ensure that the plant can

be safely shut down after a fire in any area of the plant.

The plant was divided into fire areas using structural boundaries such as floor, walls and ceiling as fire barriers.

These barriers were analyzed in the Fire Hazards Analysis (Refer to Appendix 9.5A).

Specific systems and equipment were identified as being required

for safe shutdown. The potential for possible loss of this equipment was then analyzed and plant safe shutdown was verified. (Refer to Appendix 9.5A for further discussion, deviations, and justifications).

9.5.1.6.3 Alternative or Dedicated Shutdown Capability Where analysis has indicated that the normal shutdown systems or

equipment can be potentially lost or plant control can be potentially impaired, alternative shutdown capability has been provided. (Refer to Appendix 9.5A for further discussion, deviations, and justifications).

9.5.1.6.4 Control of Combustibles

1. Combustible materials are minimized in all areas. Where combustible materials do exist, provisions are taken to protect safety-related equipment from fire

damage. a. The emergency diesel generator fuel oil day tanks are diked to contain the fuel oil within a confined area. The area is protected by a total flooding automatic heat actuated CO system with hose racks and portable BVPS-2 UFSAR Rev. 0 9.5-17 fire extinguishers as backup. An early warning detection system is provided which uses ultra violet detectors.

b. The turbine-generator oil and hydrogen seal oil pumps and storage tanks are provided with dikes and automatic heat-actuated deluge spray systems.

The turbine generator bearings are protected by

automatic heat-actuated CO systems. The turbine building is protected by general area sprinklers below the operating floor with portable fire

extinguishers and fire hose racks as backup.

c. Each reactor coolant pump lube oil system is provided with an individual oil collection system which is designed to collect and store the total

volume of oil contained in each pump.

2. Bulk flammable gas storage is not permitted inside structures housing safety-related equipment. The only bulk storage of compressed gas is the two 10-ton CO storage tanks in the auxiliary building. The CO is non-combustible and presents no fire hazard.

Flammable gas storage is not located in areas housing safety-related equipment. Hydrogen for the main generator is stored in the yard area south of the turbine building. The isolation provided by the remote location from any safety-related area or

equipment eliminates any concern of possible effect on safety-related equipment. Propane, P-10, methane, acetylene, nitrous oxide, and argon are stored on an outside platform north of the condensate polishing building. The storage location precludes any effect on safety-related equipment. The only remaining significant concentration of hydrogen is the chemical volume control tank and the waste gas surge tank. The chemical volume control tank uses hydrogen to maintain a blanket on the water stored in the tank. The tank is located in its own Seismic Category I, missile-proof, reinforced concrete cubicle. The chemical volume control tank is purged before any maintenance is done on the tank. These features constitute adequate protection for this tank. The waste gas surge tank is continuously exhausted to preclude the buildup of hydrogen. The surge tank is located in a sand-filled, Seismic Category I, missile-proof, reinforced concrete cubicle. These features constitute adequate protection for these tanks.

3. The construction of cables has been chosen with the highest flame retardant and lowest gas generation

properties while still keeping reliable electrical

characteristics. In general, polyvinyl chloride (PVC) will not be used, but if

BVPS-2 UFSAR Rev. 7 9.5-18 needed for special applications and substitute noncombustible materials are not available, PVC cable shall be minimized. PVC cable shall be installed in conduit when feasible. When not feasible, PVC cable shall be installed in a way which minimizes exposure to potential ignition

sources. PVC is used in the cooling tower, and minor amounts are used in electrical panels.

PVC fill is used in the cooling tower since no acceptable alternate fill is reasonably available. Fire barriers are provided within the fill to limit the amount of PVC consumed in the event of a fire. A fire in the cooling tower will not adversely affect equipment or safe shutdown based on the distance from safety-related structures.

4. The storage of flammable liquids at BVPS-2 is in compliance with the requirement of NFPA 30-1973, Flammable Combustible Liquids Code. The only bulk flammable liquid storage within safety-related areas is the diesel generator fuel oil day tanks which are described in the Appendix 9.5A. (Sections 9.5A.l.3.16

& 17). 5. All hydrogen piping in safety-related areas is seismically designed to Seismic Category II requirements, as defined in Section 3.2.1.2, to meet the provisions of BTP CMEB 9.5-1, Section C.5.d, Paragraph 5. This piping is seismically designed and supported to withstand SSE inertia loadings, and the integrity of the pressure boundary is maintained in accordance with ASME III. A deviation has been documented which justifies the Seismic Category II design of the hydrogen piping in safety-related areas (Refer to Appendix 9.5A for details). 9.5.1.6.5 Electrical Cable Construction, Cable Trays and Cable Penetrations

1. Steel and aluminum are the only metals used for cable trays within BVPS-2. Only metallic tubing (steel and aluminum) is used for conduit. Only steel tubing is used in the reactor containment. Electrical metallic tubing is used only for exposed lighting circuits. Flexible metallic tubing is only used in short lengths to connect components to equipment. All other raceways are made from noncombustible materials.

2. Redundant safety-related cables necessary for shutdown are normally separated by one of the following

methods: a. Fire barriers with a 3-hour fire rating, b. Fire barriers with a l-hour fire rating where automatic fire suppression and detection systems

are present, or BVPS-2 UFSAR Rev. 12 9.5-18a In areas where the previous methods of separation are not possible, a system of alternative shutdown capability has been supplied (Refer to Section 9.5.1.6.3) or deviations have been documented and justified (Refer to Appendix 9.5A).

For separation criteria applicable to the balance of safety-related cables, refer to Section 8.3.1.4.

All cables in BVPS-2 raceways are of a design which allows wetting down with fire suppression water without degrading, in

any way, the electrical performance of the cable. The cables have been specified to provide continued, undiminished service during a prolonged period of water immersion.

Cable raceways will not be provided with a continuous line-type heat detection system. A deviation to justify the existing configuration has been documented (Refer to Appendix 9.5A for details).

Automatic sprinkler protection is not provided for safety-related cable trays. Automatic total flooding CO systems with water hose backup is provided in the control building (cable spreading area, relay room, cable tunnel) cable vault and rod control building and El 745'-6" of the service building. A deviation has been documented which justifies the existing configuration and the use of fixed CO vs fixed water suppression for these areas (Refer to Appendix 9.5A for details).

The other areas where safety-related cables are routed, such as containment and auxiliary building are provided with automatic detection and manual water hoses. The containment penetration area, within the containment, is provided with water suppression that is remotely actuated from the control room.

A deviation has been documented which justifies the existing configuration. Refer to Appendix 9.5A for details.

3. The electrical cable system, and the fire protection thereof, has been designed to provide an effective and reliable system of achieving and maintaining shutdown in the event of fire within a single fire area with the following bases:

a. In general, all cables used at BVPS-2 comply with IEEE Standard 383-1974 or similar industry testing for non-safety applications (refer to Section 8.3.3 for further details).

b. All cable raceways within BVPS-2 are used only for cables.

c. Refer to Section 9.5.1.6.4 for information on storage and piping of miscellaneous combustible

liquids and gases.

BVPS-2 UFSAR Rev. 0 9.5-18b 9.5.1.6.6 Ventilation

1. All safety-related areas at BVPS-2 have air-conditioning, ventilation, or exhaust systems within or adjacent to the area that could be utilized for discharging any smoke or gas directly to the atmosphere. Portable exhaust fans provide the capability of removing smoke from the specific fire area where required. These fans will also provide backup smoke removal capability in other areas that

have no potential for radioactive release. There are no exhaust systems specifically provided for the sole purpose of removing smoke and/or corrosive gas from a fire area. The systems that are utilized in removing smoke from areas with the potential for

airborne contamination are the normal ventilation exhaust systems. The systems serving safety-related areas are designed to mitigate the consequences of an accident and are designed for single failure, with redundant equipment powered from separate emergency buses or systems with backup and/or cross connections. Refer to Section 9.4 for additional information.

2. Smoke and gas, when exhausted from potentially contaminated areas, are discharged through the

ventilation vent or elevated release. These release paths, which may be radioactive, are continuously monitored for radioactivity in the main control room. The exhaust fans associated with these release points are capable of remote shutdown from the main control room. The only other areas from which potentially

contaminated smoke or gas may be discharged would be the decontamination building roof fans and the auxiliary building emergency exhaust fans. The release paths for the decontamination building are provided with radiation monitors in the main control room. Shutdown of these fans is automatic. The Auxiliary Building Emergency Exhaust Fans are used to provide emergency cooling ventilation to the charging pumps and component cooling water pumps in the event of loss of the supplementary leak collection system. The areas of the Auxiliary Building ventilated by the exhaust system only have the potential for low level

contamination; therefore, the exhaust system is not monitored for radiation. In the event of a fire in one of the charging pump cubicles or in the area of the component cooling water pumps, portable smoke ejectors will be used for smoke venting.

3. Special protection for ventilation power and control cables is required in some areas. Where practical, power supply and controls for mechanical ventilation systems were run outside the fire area served by the system. The power

BVPS-2 UFSAR Rev. 0 9.5-18c supplies and controls for the redundant ventilation systems provided for the control room are located in the equipment room. A deviation has been documented which justifies the control room ventilation system (Refer to Appendix 9.5A for details).

BVPS-2 UFSAR Rev. 18 9.5-19 4. Charcoal filtration systems at BVPS-2 are as follows:

a. Auxiliary building exhaust and leak collection filtration system, b. Decontamination building filtration and exhaust system,

c. Deleted,

d. Deleted

e. Main control room emergency ventilation system,

f. Condensate polishing building filter exhaust system, and

g. Fuel building exhaust (part of the auxiliary building exhaust filtration system).

All of these filtration systems are supplied with heat detectors which activate an audible visual alarm locally and in the main control room. All the

preceding filtration systems, with the exception of the control room emergency ventilation system are provided with a water spray system.

5. The only fresh air supply intake which is not remotely located from the exhaust air outlet is in the main

control room. However, the BVPS-2 main control room has been designed with a double door arrangement that leads directly to the outside. Portable fans may be

used to remove smoke from the north or south entrance.

6. Stairways are enclosed in masonry or concrete towers, and doors are provided with self-closing mechanisms that would provide automatic closure to minimize smoke entry during a fire. Open stairwells exist in the turbine building and fuel building. These stairwells are provided as a convenient means of travel from one

level to another.

The reactor containment also has one open-type stairwell. Ladders are provided in areas where limited access is required, such as the diesel generator upper level and the condensate polishing building areas. In general, stairwells which serve as escape routes will lead directly to the exterior of

BVPS-2 or through fire passageways. Exit signs have

been provided along all exit routes.

7. Ventilation systems are designed to isolate areas as required to maintain the necessary CO or Halon concentration.

BVPS-2 UFSAR Rev. 16 9.5-20 9.5.1.6.7 Lighting and Communication

1. Fixed fluorescent units are fed from two 8-hour minimum battery-powered inverters in the main control

room. Fixed, self-contained lighting, with individual 8-hour minimum battery power supplies, is installed in areas outside the control room that will be manned for shutdown and for access and egress routes for safe shutdown fire areas. Shutdown areas include those required to be manned if the main control room must be evacuated. Outside, yard-area lighting for access and egress is provided by the security perimeter lighting system, which on loss of offsite power, is

independently supplied from an emergency power source. A deviation has been documented to justify the use of security perimeter lighting and 2-hour rated emergency lighting instead of 8-hour rated lighting for the fire brigade room (refer to Appendix 9.5A for details).

2. Portable hand lights are provided for emergency use by the fire brigade and other operations personnel

required to achieve BVPS-2 post-fire safe shutdown.

3. The intra-plant BVPS-2 communications design is composed of three independent systems. The normal method of intra-plant communications is by means of a five channel page-party address system. Offsite and onsite communication can be achieved by use of the separate private automatic exchange telephone system. The third method of plant communications is the calibration jack system, a two-channel system that utilizes plug-in jacks and head sets with earphones and microphones.

The existence of these three independent plant communications systems will provide a reliable means of emergency communication.

4. A portable radio communications system is provided for use by the fire brigade. This system will not interfere with the communications capabilities of the BVPS-2 security force. Fixed repeaters are not used with the portable radio communication units.

9.5.1.7 Fire Detection and Suppression

9.5.1.7.1 Fire Detection

1. All areas containing safety-related equipment are provided with an early warning detection system installed in accordance with NFPA 72E, "Automatic Fire Detection" except as noted in Section 9.5A.2 in the

deviation from BTP CMEB 9.5.1 Section C.6.a(l). The

detection system consists of ionization type and photo-electric type smoke detectors, and ultra violet

flame detectors.

BVPS-2 UFSAR Rev. 16 9.5-22 of QA Category F in the latest Revision 1 of AQAP (Augmented Quality Assurance Program) Appendix C, Fire Protection, Section 4.0 C.4, the Functional Location equipment mentioned above does not meet the requirements of the Fire Protection Category. Therefore, the portion of the yard fire loop above is outside the boundary of the fire protection program.

2. The loop is provided with an adequate number of UL/FM-approved post indicator valves. If a section of the loop is isolated for maintenance or repair, the supply of water will be maintained in all remaining areas served. 3. All outside hydrants are taken off the main loop and can be isolated for maintenance or repair without

interrupting the water supply in the main fire loop.

4. Main system piping for the FPS at BVPS-2 is exclusively for fire protection purposes and no

sanitary system piping is cross-connected.

5. The BVPS-2 is located close to BVPS-1, and there is a common source of water supply feeding both yard main loops. Sectional control valves are provided to

permit maintenance and independence of each individual

loop. 6. Fire pumps for the BVPS-2 FPS are shared with BVPS-1. These pumps are located in the intake structure and were installed during the construction of BVPS-1. The pumps were reviewed and found acceptable under the

BVPS-1 fire protection review. Basically the system

is described as follows: The source of water for fire protection is the Ohio River. Heated fire pump rooms are located in the intake structure. The fire pumping equipment consists of two 100-percent capacity, 2,500 gpm at 125 psig discharge pressure, UL- approved, vertical turbine type fire

pumps. One pump is electric motor-driven, while the second pump is diesel engine-driven with a minimum 8-hour fuel supply. The pumps are arranged for automatic sequential starting upon a pressure drop in the piping system. The pumps can also be remotely

started from the main control room or from local control panels. Shutdown of fire pumps is manual at the local control panels. The pumps are located in separate Seismic Category I cubicles with walls in

excess of 3-hour fire rating.

BVPS-2 UFSAR Rev. 17 9.5-22a Fire Protection System pressure maintenance is normally provided by a cross-connection to the Unit 1 Filtered Water System. A pressure maintenance system consisting of a 30 gpm jockey pump and 475 gallon hydropneumatic tank with related controls is also provided in the electric motor-driven fire pump room, but is not normally used and is isolated from service.

BVPS-2 UFSAR Rev. 8 9.5-23 Pump characteristic curves developed during shop tests show that each fire pump produces 3,000 gpm at a pressure greater than 109 psig. Separate supply headers to the yard fire main loop are provided.

7. An adequate number of hydrants and hose houses equipped with hose and combination nozzle and auxiliary equipment are provided on the yard fire main loop. Hydrants and hose houses comply with NFPA 24-1973, "Outside Protection," and are located so that effective hose streams will reach any fixed or transient combustibles which could jeopardize any safety-related equipment.

8. Hydrants, hose couplings, and standpipe risers are provided with threads compatible with local fire

departments.

9. The source of water for the FPS is the Ohio River, and the fire pumps are located in independent cubicles in the intake structure as described previously. No water storage tanks are required for FPS because of the adequate and reliable river water

supply source.

10. The water supply system is permanently connected to the fire main piping system. One motor-driven and one engine-driven fire pump are arranged for automatic sequential starting upon a pressure drop in the piping system. These two fire pumps can be started remotely from the main control room (BVPS-1) or from the local control panels.

Each automatic sprinkler system and interior hose standpipe is supplied via two separate connections to the yard main. Cross connections through the BV-2 buildings ensure no single failure in the water supply system will impair both primary and backup fire protection. This primary and backup coverage is provided to the component cooling water pump sprinkler system, the containment penetrations deluge system, residual heat removal pump deluge systems, and hose racks in the auxiliary building, the reactor containment, the control building, the service building, cable vault rod control building, the diesel generator building, the cable tunnel and relay area. Use of either water supply system for the FPS will neither degrade the fire main system nor incapacitate the functions required of other water systems for a BVPS-2 shutdown.

BVPS-2 UFSAR Rev. 8 9.5-24 9.5.1.7.3 Water Sprinkler and Hose Standpipe System

1. The interior manual hose rack systems for the service building, diesel generator building, rod control building, reactor building, auxiliary building, safeguards area, condensate polishing building, and turbine building can be fed from two separate

connections from the yard fire main loop. The fuel building and decontamination building are provided with one connection to the yard fire main loop. All manual hose rack stations for BVPS-2 have a backup FPS from the outside yard fire hydrants.

Piping and fittings of all internal piping in safety-related areas is in compliance with the requirements of ANSI B31.1, Power Piping and is seismically-analyzed and seismically-supported for SSE. Fire protection water supply piping in nonsafety-related areas is sized, spaced, and supported in accordance with NFPA 14-1974, Standpipe and Hose Systems, for a Class II system. Compliance with hose rack spacing

is met. Each sprinkler header and hose rack header is supplied with monitored outside screw and yoke isolation valves. If a hose rack is being used, the

condition would be alarmed (audiovisual) in the main control room. All sprinkler systems are monitored, supervised, and annunciated in the main control room. Shields and baffles are provided over equipment or areas to prevent unacceptable damage by wetting due to sprinkler water discharge.

2. Interior isolation valves in supply lines for the water sprinkler system and the hose rack system are provided with electrically supervised monitor switches or are administratively controlled.

Electrically supervised valves in an abnormal position (that is, not fully open or not fully closed as the system requires) will actuate a local indicating light, and will alarm (audiovisual) in the main control room. Hydrant valves and post-indicating valves in the yard are provided with visual indicators that are sealed and checked for proper positioning. All isolation valves in

BVPS-2 UFSAR Rev. 0 9.5-24a the FPS are periodically checked using appropriate standards such as NFPA 26-1958 as guidelines.

3. Automatic sprinkler systems are designed using appropriate standards such as NFPA 13-1976, "Sprinkler Systems," and NFPA 15-1973, "Water Spray Fixed Systems."

BVPS-2 UFSAR Rev. 12 9.5-25 4. The hose station nozzles are of the adjustable spray, straight-stream type. Fixed fog nozzles are provided in the areas of high-voltage. Fire extinguishing of delicate electronic equipment is not accomplished by water but by portable CO extinguishers. Nozzles with variable gallonage flow are provided at hose stations serving the main control room, switchgear rooms, and instrument relay rooms. All hose nozzles have shutoff capability.

5. Interior standpipe hose and hose stored in outside hose houses will be hydrostatically tested utilizing the guidelines of NFPA 1962-1979, Fire Hose - Care, Use, Maintenance. Hose stored in outside hose cabinets will be tested annually. Interior hoses will be tested every 3 years.

6. Figures 9.5-1 and 9.5-2 show the areas and buildings that receive fire protection from the water system.

9.5.1.7.4 Halon Suppression System BVPS-2 has Halon 1301 fire suppression systems, which are manually or automatically actuated. Halon protection is provided in the computer room and west communications room. The design of the halon system is shown on Figure 9.5-6A. The total flooding Halon 1301 system consists of a supply of Halon connected to fixed distribution piping and nozzles arranged to discharge Halon into the area below the raised floor and in the general area of the west communications room and in the general area of the computer room. Actuation of the Halon system will close fire dampers located in the ventilation supply and exhaust air ducts.

The Halon 1301 system is designed to provide a 7 percent concentration of Halon for a soak time of 10 minutes. The 7 percent concentration level is below the toxicity levels as stated in NFPA-12A. The Halon system is designed to be actuated while a fire is in its incipient stage. Therefore thermal decomposition of Halon 1301 should not occur.

Smoke detectors within the computer room and the communications room are provided for early detection of a fire and will alarm

locally and in the main control room (audiovisual). A smoke detection actuation system will provide for automatic operation of the Halon System.

Halon actuation can be repeated once by use of the manually-operated pushbutton. The Halon system actuation is powered by the non Class 1E 125 V dc power circuit.

BVPS-2 UFSAR Rev. 12 9.5-26 A local lockout switch is provided to inhibit the automatic operation of Halon discharge during maintenance of the system or maintenance activity in the area protected and the key lock is under strict administrative control.

This system is designed in accordance with NFPA 12A-1975/1980, Halon 1301 Systems. Check-weighing or appropriately measuring the level of the Halon cylinders will be performed on a semi-annual basis per NFPA recommendations.

9.5.1.7.5 Carbon Dioxide Suppression System The design of the CO system, as shown on Figure 9.5-5, conforms to the requirements of NFPA 12-1973, Carbon Dioxide Systems. Carbon dioxide is supplied from four refrigerated storage units, one of approximately 7.5-ton capacity (CO supply system No. 1), two of approximately 10-ton capacity each (CO supply system No.

2) and one of approximately 24-ton capacity as reserve.

The 7.5-ton unit is located inside the turbine building and provides CO for purging the main generator and for direct application to bearing areas of the turbine generator unit. The capacity of the storage unit adequately provides two cycles of CO application to the largest single hazard, with sufficient reserve capacity to provide for two complete cycles of purging the generator casing. Each cycle of generator purging consists of displacing the hydrogen with carbon dioxide when venting the hydrogen, and displacing the air with carbon dioxide before

refilling the generator with hydrogen. The two 10-ton units are located inside the auxiliary building and the 24-ton unit is located outside the auxiliary building. These units provide for total CO flooding of the following areas: Control Bldg Instrument and Relay Room, Cable Spreading Room and Cable Tunnel (Zone 1), Cable Vault/Rod Control Bldg el. 735'-6" west (Zone 2), Cable Vault/Rod Control Bldg el. 735'-6" east (Zone 2A), Cable Vault/Rod Control Bldg el. 755'-6" (Zone 3), Service Bldg el. 745'-6" (Zone 4), Orange Diesel Generator Room (Zone 5), Purple Diesel Generator Room (Zone 6) and Cable Vault Relay Room (Zone 7). The capacity of the storage units adequately provides for two cycles of CO flooding of the largest single hazard (Control Building Zone 1).

Each CO zone is provided with a lockout switch located adjacent to, but outside of, the protected zone to prevent the discharge

of COwhen workers are in that zone. The key lock is under strict administrative control. The CO system components such as valves, lockout switch, and cylinder pressure, are monitored and electrically supervised. Normal and abnormal conditions are monitored and annunciated (audiovisual) in the main control room.

BVPS-2 UFSAR Rev. 1 9.5-26a CO Supply System No. 2 is designed to provide 50 percent concentration of CO with a 20 minute soak time in areas with high concentration of cables and 34 percent concentration in the diesel building due to the potential for oil fires.

The BVPS-2 CO system was placed into automatic operation after all of the acceptance tests were successfully performed. This included full CO system discharge and observation of the integrity of the area boundary components.

9.5.1.7.6 Portable Extinguishers All portable fire extinguishers will be installed and maintained utilizing the guidelines of NFPA 10-1981, Portable Fire Extinguishers. In addition, wheeled,

BVPS-2 UFSAR Rev. 18 9.5-27 dry chemical extinguishers are provided in strategic areas of the station.

The application of a particular type of extinguisher is based on the type of potential fire, cleanup problems, as well as

possible adverse effects on equipment.

9.5.1.8 Guidelines for Specific Plant Areas

9.5.1.8.1 Primary and Secondary Containment

1. Normal Operation The primary fire protection concept for the reactor containment is to minimize the use of combustible materials. Portable fire extinguishers and fire hose

stations are provided throughout the containment. Appendix 9.5A describes fire protection provided for all hazards shown in the hazards analysis for the

reactor containment.

Hazards identified in the containment include the reactor coolant pumps (RCPs) lubricating oil, electrical cable penetrations, residual heat removal (RHR) pumps, and general area cabling. Fixed water spray deluge systems are provided for charcoal

filters, electrical cable penetrations, and the RHR pumps. An oil collection facility is provided for

each RCP. The equipment compartmentalization, spatial separation, and remote locations of safety-related equipment from potential fire hazards will prevent the

loss of redundant safety-related equipment.

a. Operation of the FPS does not compromise the integrity of containment or other safety-related systems. Automatic water suppression systems are not installed for area protection in safety-

related areas. Deluge and pre-action systems utilized are manually actuated and only provide water to a confined local area. Consequently, other safety-related equipment in the area is not

affected.

b. Refer to Appendix 9.5A for a detailed evaluation of the BVPS-2 cable system design and also a

detailed description and evaluation of fire areas.

BVPS-2 UFSAR Rev. 18 9.5-28 c. Fire detection systems are used for each identified hazard inside the reactor containment as follows:

1. DELETED

2. Electrical cable penetration areas - heat detectors and photo-electric smoke detectors.

3. The RHR pumps - heat detectors and photo-electric smoke detectors.

Due to the design of the containment (height and size), the fact that fire detection is provided

for specific hazards inside containment, the low combustible loading inside containment, and the

large volume of the containment along with the dilution caused by the ventilation high recirculation flow, no general area fire detection has been provided inside containment. A deviation has been documented which justifies the existing configuration (Refer to Appendix

9.5A).

d. Fire hose rack stations are located throughout the reactor containment on each floor level. The source of fire protection water for the hose rack stations is the two fire pumps. All fire protection piping in the reactor containment is seismically-supported.

The fire protection penetration piping design is

described in Section 6.2.4.

e. Installation of an oil collection system with spray shields and enclosures for the RCP lubricating oil system is provided. The collection facilities are seismically designed and are sized to be capable of collecting lubricating oil from all potential pressurized and unpressurized leakage sites in the

RCP lubricating oil systems.

f. BVPS-2 does not have a secondary containment.

However, the contiguous areas of containment are

provided with fire protection capabilities

commensurate with the fire hazard.

2. Refueling and Maintenance

BVPS-2 has established administrative procedures to ensure adequate fire prevention controls for transient fire loads during refueling and maintenance operations in containment. This, in conjunction with the automatic fire detectors, will provide early detection of any fire

that may develop.

BVPS-2 UFSAR Rev. 0 9.5-28a 9.5.1.8.2 Control Room Complex The main control room is in a reinforced concrete structure. The floors and the walls on all sides of the main control room

are 3-hour fire rated.

BVPS-2 UFSAR Rev. 16 9.5-29 Where combustibles are essential to operations, storage cabinets and approved trash containers are provided. Carpeting is provided in the main control room. The carpeting has a critical radiant flux greater than 0.45 watts/sq cm in accordance with

ASTM E 648. Manual fire fighting capability consists of portable fire extinguishers located in the main control room, and a manual fire hose rack station located in the stairwell. The fire hose nozzles are fully adjustable (fog to full stream). The main

control room is occupied at all times by personnel trained in fire extinguishing procedures. Additional water for fire fighting could be supplied from the outside fire hydrants.

Early warning fire detection in the main control room is provided by area ionization detectors and is alarmed (audiovisual) in the main control room on the fire detection panel. Detectors are also provided in the main vertical board cabinets.

Self-contained breathing apparatus is readily available for main control room personnel.

The BVPS-2 main control room air intake is provided with a smoke detector. If smoke is detected entering the main control room, the operator isolates the outdoor air intake motor-operated dampers (MODs). Externally generated smoke can be vented from the main control room area by manually opening the outdoor air exhaust and intake MODs and closing the recirculation damper. If a particular zone in the main control room air-conditioning system requires smoke purging due to internal smoke generation, the system could be aligned to 100-percent outdoor air by use of the manual smoke venting as discussed previously. These features provide adequate means of smoke control in the main

control room. All cables which enter the main control room terminate in the main control room or in the computer room. A small portion of raised floor exists between the main control vertical board section and the benchboard section. The cables in this raised floor area are located in conduit and are sealed with a fire-resistant material. Raised floor sections are also used for the operator consoles; the cables in this raised floor area are located in steel conduit which meets the requirements of BTP CMEB 9.5-1. Therefore fire protection is not provided. Should a fire occur in the main control room, alternate shutdown capability has been provided. Refer to Appendix 9.5A for a description of the main control room exposure fire.

Deviations have been documented for the peripheral room (shift supervisor's office) not being separated from the control room

by a l-hour fire rated barrier, cabling routed in the control room under the raised floor not meeting separation criteria necessary for fire protection or having fixed automatic suppression, and carpeting being provided in the control room. (Refer to Appendix 9.5A for details.)

BVPS-2 UFSAR Rev. 15 9.5-30 9.5.1.8.3 Cable Spreading Room The BVPS-2 cable spreading room is located at el 725 ft-6 in, in the control building. The primary fire suppression system for this area is a manual or automatic, double capacity, total flooding CO system. The gaseous CO system is a recognized fire suppression agent that pervades the entire volume of the area, and is not subject to deflection or shielding by trays, tray covers, or

other partial separation barriers. If the early warning smoke detection alarms are not acted upon, the initial shot is actuated by a cross-zoned smoke detection system. The system can also be activated by deliberate manual action as a fire fighting measure. The second shot can only be actuated manually. Lockout switches, as well as CO pre-discharge alarms and odorizers, are provided for personnel protection. An alarmed fire display is provided in the main control room for the cable spreading area. A trouble alarm (audiovisual) is provided in the main control room for the cable spreading area in the event of

loss of the electrical integrity in the detector and release circuits or upon lockout of the system. An alarmed display (audiovisual) for CO discharge is provided in the main control room for the area. Alarmed displays also exist in the main control room for low level, high or low pressure in the storage tank, and compressor electric motor trip.

Portable fire extinguishers are provided in the cable spreading room and in adjacent areas. Manual fire hose rack stations have been provided as a backup for the CO system. These hose rack stations are located in the stairwell adjacent to the cable spreading room. The normal fire

suppression water supply is from the yard FPS. The fire suppression system is considered adequate due to the existence of an effective gas extinguishing system, available fire hose rack stations, portable extinguishers, and the fire detection system.

The BVPS-2 cable spreading room is accessible to the fire brigade from three remote and separate entrances. Sufficient aisle separation between cable tray stacks is provided for adequate accessibility for fire fighting except in the northwest corner of the cable spreading area. Special fire fighting equipment such as Navy applicators have been provided to ensure access to the fire. Hose stations are located at each end of the cable spreading room and at the cable tunnel interface, and are capable of providing hose stream coverage to the entire room, thereby enhancing manual fire fighting capability.

BVPS-2 UFSAR Rev. 0 9.5-30a Floor drains are provided in the cable spreading room at elevation 725 ft.-6 in. in the control building. Floor drains do not have CO seals; however, the floor drains are piped to a sump within the discharge area thereby containing the CO within the area. All floor drains from the 725 ft-6 in and 712 ft-6 in

elevations are directed to a single sump, located within the CO protected area. The sump water is pumped out of the area by one of two sump pumps. The cable spreading room walls, floor, and ceiling consist of

reinforced concrete with at least a 3-hour fire rating.

BVPS-2 UFSAR Rev. 12 9.5-31 Stairwells for the cable spreading area consist of 3-hour rated walls with 3-hour rated doors. Since the 707 ft-6 in. and 725 ft elevations are a part of a single fire area, ventilation penetrations in the floor of the cable spreading room do not have fire dampers. The areas on both sides of the penetrations are protected by total flooding CO systems.

Mechanical pressure-release devices, activated by CO pressure, close dampers that would allow the escape of CO into the communication room in the control building. The supply and return fans associated with the cable spreading room in the control building will automatically shut down upon discharge of CO. Smoke venting of the cable spreading area can be manually accomplished by utilizing its exhaust fan. Portable exhaust fans may also be utilized for smoke removal.

Should a fire occur in the cable spreading room area, alternate shutdown capability has been provided. BVPS-2 can be shut down safely from the ASP located in the cable tunnel of the auxiliary building. (Refer to Appendix 9.5A for details).

A deviation has been documented for the cable spreading room concerning use of CO vs water, aisle separation less than 3 ft x 8 ft, and lack of continuous line-type heat detectors in trays (Refer to Appendix 9.5A for details). 9.5.1.8.4 Plant Computer Room

The computer room is located in the control building. The room is enclosed with reinforced concrete walls and has a 3-hour fire

rating. The computer room and the computer are not safety-related. The computer room is provided with a fixed Halon fire protection system.

Where combustibles are essential to operations, storage cabinets and approved trash containers are provided.

Fire detection is provided by ionization detectors with a local audible alarm and an audiovisual fire alarm in the main control

room. Portable fire extinguishers for the computer room will be located outside the room's entrance. The adjacent main control room contains readily available portable fire extinguishers. Manual fire hose stations are provided in both stairwells.

9.5.1.8.5 Switchgear Rooms

Switchgear rooms are located in the service building at el 730 ft-6 in. and are separated from the remainder of BVPS-2 by 3-

hour fire rated barriers. The perimeter walls of two emergency switchgear areas are of reinforced concrete having a minimum 3-hour barrier.

BVPS-2 UFSAR Rev. 0 9.5-32 The ceiling of the emergency switchgear areas is a 3-hour fire rated barrier. The four station safety-related emergency battery rooms are

located as follows: two emergency battery rooms, 2-1 and 2-3, are located adjacent to the orange switchgear room, and two emergency battery rooms, 2-2 and 2-4, are located in the perimeter of the purple switchgear room. Doors separating the emergency switchgear rooms from the four battery rooms and other areas of BVPS-2 are 3-hour fire rated.

The battery rooms associated with the respective safety-related divisions are located within the perimeter of their emergency switchgear area and maintain physical separation. This arrangement is adequate due to the complete separation of the redundant emergency electrical supply systems.

Area ionization smoke detector coverage, with local audiovisual alarms and main control room alarms (audiovisual), are provided

for all these areas. In general, all cables entering the area are terminated there.

Limited deviation from this practice is a direct result of cable routing requirements.

Portable fire extinguishers and backup manual fire hose rack stations will be provided for the switchgear rooms. These hose rack stations are located in the stairwells adjacent to the switchgear rooms. Audiovisual annunciation is provided in the main control room for hose rack system trouble.

Drains are provided in the area of the switchgear rooms to facilitate water drainage resulting from fire fighting activities.

Smoke venting of the emergency switchgear areas can be manually accomplished by the use of area exhaust fans located in an

adjacent building, the cable vault and rod control area at el 773 ft-6 in.

9.5.1.8.6 Remote Safety-Related Panels Redundant safety-related panels remote from the main control

room will be separated by barriers having a minimum fire rating of 3 hours.

Remote shutdown capability is provided at the ASP (located in the auxiliary building/cable tunnel at el 755 ft-6 in). The ASP is in its own 3-hour fire rated area.

The ASP is electrically isolated from the control room complex so that a fire in the area will not to affect shutdown capability. (Refer to Appendix 9.5A for further discussion and analysis on various operating conditions of the ASP, and main control room).

BVPS-2 UFSAR Rev. 0 9.5-33 Automatic smoke detectors are located in areas of major safety-related panels and provide local audible alarms and audiovisual annunciation in the main control room.

The ASP room has ionization type smoke detectors, which alarm locally and provide audiovisual annunciation in the main control room. Combustible materials in the ASP room are controlled and limited to those required for operation. Where combustibles are required for operation, approved storage cabinets and trash containers are provided.

Portable fire extinguishers are provided in the general area of all safety-related electric panels. Manual fire hose stations are provided in stairwells adjacent to all safety-related cable

areas. 9.5.1.8.7 Safety-Related Battery Rooms

Safety-related battery rooms in BVPS-2 are protected against fires and explosions. All battery room walls, floors, ceilings, and doors have a 3-hour fire rating. DC switchgear and inverters are not located in the battery

rooms. Automatic fire detection with area ionization detectors is provided in all safety-related battery rooms (2-1, 2-2, 2-3, 2-4). These fire detectors provide local audible alarms and audiovisual annunciators in the main control room.

The ventilation system air flow rates for the safety-related battery rooms provide for a battery room purging rate greater

than the maximum rate of hydrogen generation. This ensures that hydrogen concentrations will be well below the explosive limit (less than 2 percent by volume).

Failures of this ventilation system will be alarmed (audiovisual) in the main control room.

Portable fire extinguishers are located directly outside of the battery rooms, as are additional readily available portable fire extinguishers in the adjacent emergency switchgear rooms. Manual fire hose stations are provided and located adjacent to the stairwell of the service building and the enclosed personnel

passageway. 9.5.1.8.8 Turbine Building

The turbine building is separated from those adjacent structures that contain safety-related equipment by fire barriers with 3-hour rating. The barriers are designed to preclude fire propagation between areas. In the event of a collapse of the turbine building, the 3-hour fire rated barriers will remain in

place. BVPS-2 UFSAR Rev. 0 9.5-34 9.5.1.8.9 Diesel Generator Areas The emergency diesel generator units in BVPS-2 are in individual rooms and are separated from each other and from other areas of

BVPS-2 by fire barriers having a fire rating of 3 hours. The primary fire suppression system for these cubicles are individual, automatic, double capacity, fixed flooding CO systems. Early warning flame detectors (ultra violet) and heat detectors, which have audible alarms locally and audiovisual annunciators in the main control room, are provided in the emergency diesel

generator rooms. Portable fire extinguishers are located within each room and

within each entryway. Manual fire hose stations are located at the entrance to each room and are provided as a backup to the CO system. Each diesel generator cubicle has a floor-mounted, 1,100-gallon fuel oil day tank located within a suitable curbed area. An oil

sump pit with a drain, provided within the curbed area, is sufficient to contain 1,100 gallons and is connected to an underground oil separator.

9.5.1.8.10 Diesel Fuel Oil Storage Areas

The BVPS-2 diesel generator fuel oil storage tanks are encased in reinforced concrete underground vaults covered with a reinforced concrete slab. These storage tanks are located below

the diesel generator cubicles. 9.5.1.8.11 Safety-Related Pumps

The following safety-related pumps are required for safe shutdown:

1. Charging Pumps (2CHS*P21A, B, and C)

The charging pumps are located in three cubicles adjacent to each other. The communicating walls

between the cubicles are 2-foot thick concrete walls with all penetrations sealed with 3-hour fire seals. The west wall of each cubicle is composed of a 2-foot thick concrete block wall with a small opening at the top for the crane rail to pass through. The wall is built up of removable concrete section to facilitate removal of a charging pump for maintenance. The east wall of each cubicle is a 2-foot thick concrete wall and has a labyrinth-type opening for missile and radiation scatter protection. The horizontal travel distance between redundant charging pumps "A" and "B" is over 20 feet. Charging pumps are arranged such that the "A" pump is separate from the "B" pump by

the "C" pump (swing pump). All walls extend from a 3-hour rated floor to a 3-hour rated

BVPS-2 UFSAR Rev. 13 9.5-35 roof. A curb is provided across each personnel access opening to contain any oil spills within the cubicle. Each cubicle is provided with a drain to prevent accumulation of spilled oil. Additionally, the entire area of the auxiliary building el 735'-6" (PA-3) including the cubicles is protected by an early warning smoke detection system. The total combustible loading for the PA-3 area in which the three cubicles are located has a fire severity of less than one hour duration (80,000 Btu/sq ft = 1 hour). Each charging pump contains 51 gallons of lube oil which equates to a fire loading of less than 1/2-hour fire duration. This assumes a total burnout of the entire inventory of oil which could only be coincident with a total failure of the cubicle drainage system. Cable insulation composes 95 percent of the fire loading in PA-3. All cables not in conduit are IEEE-383-1974 rated, or have similar industry testing for non-safety applications (Refer to Section 8.3.3 for further details) which inhibits fire spread. This cable will not propagate fire even if its outer covering and insulation have been destroyed in the area of flame impingement. BVPS-2 postulates the worst possible fire in this area to be a slow-developing cable type of fire. This type of fire would be detected in its incipient stages by the early warning smoke detection system and responded to by the plant fire crew prior to the development of any major fire involvement. (Refer to Section 9.5A.1.3.23 for the discussion on electrical separation). Hose stations and portable extinguishers are readily available. The ventilation arrangement ensures adequate smoke removal during a fire. Floor drains are provided for fire suppression water drainage. (Refer to Appendix 9.5A for deviation due to lack of separation).

2. Component Cooling Water Pumps (2CCP*P21A,B, and C)

The component cooling water pumps supply cooling water to various primary plant components such as the reactor coolant pumps, residual heat removal heat exchangers, non-regenerative heat exchanger, shield tank coolers, CRDM shroud cooling coils and primary plant sampling system coolers. The only appreciable combustible loading within 20 feet of the coolant pumps are the pumps themselves (1/2 gal of lube oil and the motor insulation for each pump). The component cooling water pumps are arranged so that the "A" pump is separated from the "B" pump by a distance of 24 ft with the "C" pump (swing pump) in between. The component cooling water pumps are protected by a preaction spray system. The system is actuated by heat detectors and the pipe is air supervised for reliability. Thus, there is sufficient protection

for these pumps from any postulated fire in the area.

BVPS-2 UFSAR Rev. 12 9.5-36 Additional fire detection is provided by ionization smoke detectors located in the area. The backup fire suppression equipment consists of hose rack stations and portable fire extinguishers. Floor drains are available for water drainage to prevent damage from accumulating water. The ventilation arrangement allows for smoke exhaust. (Refer to Appendix 9.5A for

deviation due to lack of separation).

3. Auxiliary Feedwater Pumps (2FWE*P22 and P23A&B)

A 3-hour fire rated wall separates the two redundant motor-driven auxiliary feedwater pumps. Pump 2FWE*P23B is located in the north safeguards area. The steam-drain auxiliary feedwater pump (2FWE*P22) and the motor-driven feedwater pump (2FWE*P23A) are located in the south safeguards area. Pumps 2FWE*P23A and 2FWE*P22 are separated by approximately 18 feet distance and partial separation is provided by a stairwell. An automatically operated water spray fire suppression system is provided for all three pumps. The backup fire suppression system consists of the safeguards area hose rack stations and fire extinguishers. Ionization type detection is provided for each pump, which has audible alarms locally and

audiovisual annunciation in the main control room. Floor drains are available for water drainage to prevent damage from accumulating water. The arrangement of the ventilation will allow for smoke exhaust.

4. Boric Acid Transfer Pumps (2CHS*P22A and B)

The boric acid transfer pumps are located in adjacent cubicles with openings for personnel entrance. A

wall separates these pumps. The boric acid transfer pumps do not constitute a fire hazard. Primary suppression consists of portable fire extinguishers and hose rack stations in the immediate area. Ionization detectors exist in the pump cubicles and have audible alarms locally, and audiovisual

annunciation in the main control room. Floor drains are available for water drainage to prevent damage from accumulating water. The ventilation arrangement will allow for smoke exhaust. (Refer to Appendix 9.5A for deviation due to lack of separation).

BVPS-2 UFSAR Rev. 0 9.5-36a 5. Service Water Pumps (2SWS*P21A, B, and C) Each service water pump is located in a separate 3-hour fire rated area. Primary fire suppression is provided by hose rack stations with portable fire extinguishers as backup. Detection is accomplished by use of ionization or heat detectors, which have

audible alarms locally and audiovisual annunciation in the main control room. Sump pumps are available to prevent damage from accumulating water. The ventilation arrangement will allow for smoke exhaust. 6. Diesel Generator Fuel Oil Transfer Pumps (2EFG*P21A, B, C, and D) Diesel generator fuel oil transfer pumps (2EGF*P21A and B) which supply the No. 1 diesel generator, are located in the south diesel generator building. Pumps 2EGF*P21C and D which supply the No. 2 diesel generator are located in the north diesel generator building. Each building is separated by a 3-hour fire rated barrier. Suppression for these pumps are afforded by the building CO fire suppression system. Fire detection in provided by the early warning system (flame detectors) and CO system (heat detectors). Floor drains are available for water drainage to prevent damage from accumulating water.

7. Residual Heat Removal Pumps (2RHS*P21A and B)

The RHR pumps are required for achieving cold shutdown. A water deluge suppression system is provided for each RHR pump. Heat detectors and photo-electric smoke detectors, which have audible alarms

locally and audiovisual annunciation in the main control room, are provided for each pump. Hose stations and portable extinguishers are readily accessible. There are floor drains for fire suppression water drainage to prevent damage from accumulating water. Refer to Appendix 9.5A for

deviation due to lack of separation.

BVPS-2 UFSAR Rev. 0 9.5-37 The ventilation arrangement will allow for smoke exhaust. The following safety-related pumps are not required for safe shutdown. The fire hazards analysis has demonstrated that a fire in these areas housing these safety-related pumps will not endanger other safety-related equipment required for safe shutdown. Therefore, automatic suppression has not been provided.

1. Fuel Pool Cooling Pumps (2FNC*P21A and B)

The fuel pool cooling pumps are not required for safe shutdown. Fire detection is accomplished by the use of ionization detectors, which have audible alarms

locally and audiovisual annunciation in the main control room. Portable fire extinguishers and hose rack stations are available for fire suppression. Floor drains remove excess water and prevent damage from accumulating water.

The ventilation arrangement will allow for smoke removal. (Refer to Appendix 9.5A for deviation due to lack of separation).

2. Quench Spray Pumps (2QSS*P21A and B)

The quench spray pumps are not required for safe shutdown. The pumps are located in individual rooms in the safeguards building. The existing horizontal separation (approximately 25 feet) and a concrete wall between the pumps are sufficient to preclude the possibility of fire resulting in the loss of both pumps. Fire detection is provided by ionization detectors, which have audible alarms locally and audiovisual annunciation in the main control room. Portable fire extinguishers and hose rack stations are available for fire suppression. Floor drains are available for water draining to prevent damage from accumulating water.

The ventilation arrangement will allow for smoke removal.

3. Recirculation Spray Pumps (2RSS*P21A, B, C, and D)

The recirculation spray pumps are not required for safe shutdown. These pumps are located within individual, remote, reinforced concrete cubicles in the safeguards building. This design feature precludes the possibility of loss of more than one pump from a fire in any one cubicle.

BVPS-2 UFSAR Rev. 0 9.5-38 Portable fire extinguishers and hose rack stations are available for fire suppression. Floor drains are available for water drainage to prevent damage from accumulating water. The ventilation arrangement will allow for smoke removal. 4. Low Head Safety Injection Pumps (2SIS*P21A and B) The low head safety injection pumps are not required for safe shutdown. The pumps are separated by a 3-hour fire rated reinforced concrete wall, which precludes the possibility of loss of both pumps from a fire in either pump cubicle. Fire detection is provided by the use of ionization detectors, which have audible alarms locally and audiovisual annunication in the main control room. Portable fire extinguishers and hose rack stations are available for fire suppression. Floor drains are available for water drainage to prevent damage from accumulating water. The ventilation arrangement will allow for smoke removal. 9.5.1.8.12 New Fuel Area

The new fuel storage room is located in a completely enclosed cubicle inside the fuel building where no combustibles are stored. Due to the extremely low fire loading in the fuel

building, no fire detection is required for this area. Interior hose racks and portable fire extinguishers are provided in the fuel building. The new fuel storage room is provided with portable fire extinguishers and floor drains. The storage configuration of new fuel elements is addressed in Section 9.1.1. A deviation has been documented for the configuration (Refer to Appendix 9.5A for details).

9.5.1.8.13 Spent Fuel Pool Area The spent fuel pool area is void of any concentration of combustibles, and for this reason automatic fire detection is not required. Partial area coverage over the fuel pool cooling pumps is provided by the detection system. Portable fire extinguishers and hose stations are located throughout the fuel building.

BVPS-2 UFSAR Rev. 16 9.5-39 A deviation has been documented for this configuration (Refer to Appendix 9.5A for details). 9.5.1.8.14 Radwaste and Decontamination Areas

Radwaste areas are: the waste handling building, decontamination building, and the condensate polishing building. These buildings have been designed to maintain 3-hour fire separation from adjacent buildings.

a. Condensate Polishing Building Portable fire extinguishers and hose racks are provided throughout the condensate polishing building.

The combustible contents of the condensate polishing building are confined to specific areas that are protected by automatic sprinkler systems or to non-radiological areas that do not create an exposure hazard to radioactive materials. The only exception is the ventilation system charcoal

filter. This filter is provided with a heat detector which alarms in the control room and a manually operated water spray system. For these reasons, general area automatic fire detection is not provided.

A deviation has been documented on the lack of general area automatic fire detection. (Refer to Appendix 9.5A for details.)

b. Waste Handling Building Portable fire extinguishers and hose racks are provided throughout the waste handling building.

All floor drains in the waste handling building are directed to the liquid radwaste system. The radwaste baler area is the only area with

potentially appreciable combustible contents and has been provided with an automatic sprinkler system. For these reasons, general area automatic

fire detection is not provided.

A deviation has been documented on the lack of general area automatic fire detection. (Refer to Appendix 9.5A for details.)

d. Decontamination Building

Portable fire extinguishers and hose racks are provided in the decontamination building.

BVPS-2 UFSAR Rev. 16 9.5-40 The decontamination filter is the only real combustible loading in the building. The filter is provided with a heat detector which alarms in the control room and a manually operated water spray system. For these reasons, general area automatic fire detection is not provided. A deviation has been documented on the lack of general area automatic fire detection. (Refer to Appendix

9.5A for details.) 9.5.1.8.15 Safety-Related Water Tanks

The following tanks are required for safe shutdown:

1. Primary plant demineralized water storage tank (PPDWST) (2FWE*TK210), 2. Refueling water storage tank (RWST) (2QSS*TK21),

3. Boric acid tanks (2CHS*TK21A and B), and

4. Demineralized water storage tank (2WTD-TK23).

Both the PPDWST and the RWST are located in the northeast yard approximately 10 feet from the safeguards area. Fire protection water coverage is provided by a yard fire hydrant in close proximity to both tanks. Portable extinguishers (water, dry chemical, and CO) are available in various nearby buildings. The PPDWST is completely enclosed in a Category I, missile-protected structure of 2-foot reinforced concrete. The RWST is surrounded by a radiation protection shield of reinforced concrete to a height of 16 feet, with a minimum thickness of 1 foot. The boric acid tanks are located in individual separate cubicles in the auxiliary building. There are no combustibles in the general area that threaten the integrity of these tanks. Fire hose racks are available in the general area as well as portable fire extinguishers. The demineralized water storage tank is located in the northeast yard approximately 50 feet from any building. Fire protection is provided by yard fire hydrants

with hose houses in proximity to the tank. The demineralized water storage tank is used to augment the PPDWST as a source of auxiliary feedwater. Service water is also provided as backup, if required. Refer to Appendix 9.5A for details. 9.5.1.8.16 Records Storage Areas

Records storage areas will be located and protected such that a fire in these areas does not affect safety-related systems or

equipment.

BVPS-2 UFSAR Rev. 0 9.5-41 9.5.1.8.17 Cooling Tower The BVPS-2 cooling tower is located such that a fire would not adversely affect any safety-related systems or equipment.

The BVPS-2 cooling tower is built of noncombustible material with the exception of the distribution pipes, fill material, and cable coatings within the tower, which are made of PVC and fiber reinforced plastic.

9.5.1.8.18 Miscellaneous Areas Miscellaneous areas such as warehouses, shops, auxiliary boilers, auxiliary boiler fuel oil storage tanks, and flammable and combustible liquid storage areas are located and protected such that a fire in these areas does not affect safety-related

systems or equipment. 9.5.1.9 Special Protection Guidelines

9.5.1.9.1 Storage of Acetylene - Oxygen Fuel Gases

The bulk storage location is outside and adjacent to a fire hydrant and hose cart house. There is no bulk storage of flammable gases in the station. Welding and cutting machines

are stored in the BVPS-1 machine shops that are provided with sprinkler systems, hose stations, and portable extinguishers.

9.5.1.9.2 Storage Areas for Ion Exchange Resins Dry ion storage resins will be stored in the condensate

polishing building. This building does not house safety-related equipment. Primary fire suppression will be a sprinkler system with fire hose stations as a backup. Adequate floor drains are

available to drain water to the liquid radwaste sump. 9.5.1.9.3 Hazardous Chemicals

There are no hazardous chemicals stored on BVPS-2 in areas which expose or contain safety-related equipment or systems.

9.5.1.9.4 Materials Containing Radioactivity

Spent ion exchange head resin beds are flushed to a spent resin holding tank or to a decanting tank located in the condensate polishing building of BVPS-2. Spent powdered resins from the condensate polishing system, if radioactive, are collected by the clamshell filters and directed to a sludge tank located in the condensate polishing building of BVPS-2. Filters are removed to the waste handling area and placed in metal containers. Resins and filters are eventually solidified with cement in 55-gallon capacity drums, and eventually shipped to an

offsite facility.

BVPS-2 UFSAR Rev. 14 9.5-42 9.5.2 Communications Systems 9.5.2.1 Design Bases

The communications systems provide reliable, effective communications during normal operating and emergency conditions between essential areas of BVPS-2 (including the control room) and locations remote from BVPS-2. The communications systems are designed such that a failure of one system does not impair the reliability of any other system. This capability is accomplished by providing diverse types of communication systems. 9.5.2.2 System Description 9.5.2.2.1 Intra-plant Communications

The intra-plant communications consist of the following systems:

1. A page party system, 2. A calibration jack system,

3. A radio system, and

4. A private automatic exchange telephone system.

9.5.2.2.1.1 Page Party System

The five channel page party system (PPS) system provides communications from the main control room to all buildings and control areas within BVPS-2, and from one building or control area to any other. The PPS, powered from a reliable power source, is normally used during daily plant operation to allow individuals to communicate between PPS stations and to provide for public address within the plant.

In an emergency, the system is used to alert personnel on the site and to communicate messages between individuals. The evacuation/standby alarms are manually initiated from the communication console in the main control room or from the auxiliary communications station adjacent to the emergency shutdown panel (ESP). The alarms are carried on the PPS loud-speakers to ensure audibility throughout the plant. The main plant PPS obtains its power from the essential bus. Outlying buildings, such as the cooling tower pumphouse, obtain power for

the PPS from normal ac distribution panels.

BVPS-2 UFSAR Rev. 19 9.5-42a 9.5.2.2.1.2 Calibration Jack System

A calibration jack system is installed in the plant. It is a two-channel system with a network of plug-in jacks. Headsets, consisting of earphones and a microphone, are connected through

the plug-in jacks to permit direct communication between persons

in different areas. The system obtains its power from a

reliable source of ac power.

This system is normally used for maintenance, during instrument and equipment calibration, and during construction and start-up.

During an emergency, the system can be used as an alternate means of communication between two or more areas of the plant.

9.5.2.2.1.3 Radio System

Hand-held portable radios are available for use during normal

and emergency conditions. The radios operate on two VHF band frequencies and two 450 MHz band frequencies. The hand-held radios are powered by rechargeable batteries and, once charged, are not dependent on any electrical system until recharging is necessary. The VHF frequencies are used for normal maintenance and operating communications and can be used as an alternate

means of relaying messages between areas of the plant during an emergency. The 450 MHz band frequencies will also be used by

security for both normal and emergency operations.

The base stations are capable of communicating with hand-held

portable radios within BVPS-2. Two VHF remote consoles for high band and one for low band operation are located in the plant.

These consoles operate two base radios located in a remote radio building at a high point just off the site. The remote control consoles are powered from the essential bus. The base radios are powered from a 48 V dc battery/charger supply at the radio

building.

High band VHF radio transceivers are available for use in

vehicles by radiation monitoring teams.

Dedicated hand-held portable radios are provided to support post fire safe shutdown at BVPS-1 and BVPS-2.

9.5.2.2.1.4 Private Automatic Exchange Telephone System

A private automatic exchange (PAX) telephone system is installed in BVPS-2. Commercial-type telephone handsets are installed in

various

BVPS-2 UFSAR Rev. 12 9.5-43 areas that may be continuously or frequently manned. The power supply for the system is from an independent communications battery/charger system (shared with BVPS-1).

This system is tied to commercial telephone lines to allow for calls outside the plant but does not depend on them for intra-plant use.

9.5.2.2.1.5 Cable and Circuit Routing

Cables in the PPS, calibration jack system, and PAX communications systems are independent from those of other systems, and are isolated from power cables of other systems and

any other sources of line noise which could adversely affect the audibility of the systems. The PPS, the calibration jack system, and the PAX telephone system are normally run in separate raceways. The PPS and the PAX telephone system are sometimes run in the same raceway in the yard area where a fire or other event would not threaten any safe shutdown systems. Loss of all communications in the yard area would have no impact on a safe shutdown.

All communications systems wiring in general plant areas is routed in rigid metal conduit, underground duct, or electrical metallic tubing (EMT), or meets the flame testing requirements specified in Section 8.3.3. 9.5.2.2.2 Plant-to-Offsite Communications

The plant-to-offsite communications consist of the following separate, independent, and diverse systems adaptable to in-plant

and offsite locations:

1. Commercial telephone land line system, 2. Plant-to-offsite radio systems, 3. Microwave system, and 4. System operator telephone.

9.5.2.2.2.1 Commercial Telephone Land Line System

Telephone company voice circuits are provided from the plant to the telephone control office in the area. This enables appropriately designated telephone instruments within the plant to contact any outside telephone number. In addition, telephone tie lines connect the plant to the DLC telephone network. Diverse physical routing is provided to preclude a total

interruption of service that might result from a single failure. 9.5.2.2.2.2 Plant-to-Offsite Radio System

Two VHF base radio stations provide communication with the local and state law enforcement authorities and other offsite facilities. The stations are also used for plant communications via fixed or portable units. BVPS-2 UFSAR Rev. 12 9.5-44 The radio transceivers are located in the radio building, adjacent to the site, with remote control consoles in the main control room and with a remote handset provided at the ESP. In addition, two mobile radio transceivers are provided in the plant. The system is designed to provide reliable radio

communications. 9.5.2.3 Design Evaluation A failure of one communication system does not affect the

operation of the other types of communications systems since they are of diverse types and are independent of one another.

9.5.2.3.1 Intra-plant Communications A loss of electric power does not cause a common code failure of intra-plant communications. The PPS and PAX systems are powered from separate reliable power supplies that ultimately derive power from the station or from communication batteries. The portable radio system is battery-powered and independent of plant electric power except for recharging of batteries. The calibration jack, PPS, and PAX systems generally do not share

common raceways. 9.5.2.3.2 Plant-to-Offsite Communications

The plant-to-offsite communications systems provided use a diverse mix of the major types of approaches which are available (commercial telephone, radio, and system operator telephone) to ensure that under the most adverse circumstances, communications will be maintained.

9.5.2.4 Inspection and Testing Requirements

The design of the communications systems permits routine testing and inspection without disrupting normal communications. Degradation of any systems which are in daily use can be

identified and corrected.

BVPS-2 UFSAR Rev. 12 9.5-45 Periodic tests of the required unused circuits, plus tests of the associated handsets and headsets, prove their availability. The evacuation alarm system is tested periodically in accordance with plant procedure. Preoperational tests are made to ensure adequate design sound pressure levels, in the case of audible evacuation alarms, or visibility of lights for visual evacuation

alarms. The communications systems (except for Bell Telephone equipment)

are fully maintained by the licensee staff:

Preventative maintenance and operability checks are periodically performed. These checks are to ensure that essential equipment is operating properly, and to insure that the systems will operate when called upon.

9.5.3 Lighting

Systems

The lighting system provides adequate illumination during all operating conditions, including transients, accident conditions, and the effect of the loss of normal and offsite power.

9.5.3.1 Design Bases

The system provides, as a minimum, lighting intensities at levels recommended by the Illuminating Engineering Society and state regulatory agencies, where applicable. The backup lighting system provides adequate illumination in all access areas and in all areas required for control of safety-related equipment. Power is supplied from normal ac and dc sources.

Backup lighting units, each with a minimum 8-hour individual battery power supply, is provided in all areas needed for operation of safe shutdown equipment, and in access and egress routes thereto.

Within the reactor containment, decontamination building, and fuel building, only incandescent lamps are used to prevent potential contamination from lighting elements containing

mercury. Fluorescent lamps are used for general lighting within the

plant. High intensity discharge (HID) lamps are used for high bay lighting, medium height lighting, and for roadways and parking lots. Auxiliary lighting is provided in the indoor HID fixtures to provide a safe level of illumination during the time necessary for a restrike function to occur following a power interruption.

BVPS-2 UFSAR Rev. 2B 9.5-46 Lighting circuits are designed to avoid overloading and the subsequent tripping of breakers, which would affect lighting reliability. To prevent faults in one lighting system from rendering another system inoperative, separate conduits are used to feed lighting systems derived from different sources. Normal lighting circuit conductors and backup lighting circuit conductors are run in separate raceways to prevent a common mode

failure. The lighting in the main control room can be systematically switched for different illumination levels to suit the requirements of the operating staff.

Underwater lighting in the fuel pool provides sufficient illumination to enable the crane operator to accurately see the material being handled in the fuel pool. Additional underwater illumination is provided for use with closed circuit television. All fixture materials used are stainless steel.

Lighting wire used is type XHHW, which is radiation- and flame-resistant and is entirely enclosed in conduit.

Seismic conditions are considered in the placement of lighting equipment and the selection and installation of supports. Lighting transformers, panelboards, and light fixtures are

seismically- supported in seismically designed areas. 9.5.3.2 System Description

Normal ac lighting is used throughout the plant. Backup dc lighting is used for exit and egress lighting and illumination as needed for safe shutdown operations. Backup ac lighting will be confined to the following areas:

1. Control room, 2. Emergency shutdown panel area,

3. Alternate shutdown panel area,

4. Class 1E switchgear rooms, and

5. Essential bus inverter and rectifier area in the rod control/cable vault building.

The backup ac lighting in the five listed areas will also be supplemented by sealed beam or fluorescent lamps, each with an individual battery pack rated at a minimum 8 hours of operation, to allow safe shutdown operations, to illuminate the means of

egress, and to aid in providing lighting for the fighting of fires.

BVPS-2 UFSAR Rev. 0 9.5-47 9.5.3.2.1 Normal AC Lighting Normal ac lighting for the plant is supplied from the 480 V station service system through single-phase, 480-120/240 V, 3-

wire grounded, dry-type transformers. In most areas of the plant, normal ac lighting is provided from two different sources to enhance reliability. Alternating rows of fluorescent fixtures are supplied from different lighting panels and transformers which, in turn, are supplied from separate 480 V motor control centers (MCCs) on separate 480 V unit substation buses.

Indoor areas illuminated primarily with mercury vapor (MV) sources have an auxiliary lighting system to provide illumination during the cooling and restrike time of MV lamps. This auxiliary lighting is fed from the same ac circuit as the MV lamp and is a quartz lamp built into the luminaire.

9.5.3.2.2 Backup DC Lighting Backup dc lighting consists of 125 V dc incandescent fixtures

supplied from the non-Class 1E station batteries. These fixtures are normally energized from nonsafety-related, diesel backed, 480 V unit substation through 480 V MCC and 480-120 V dry-type transformers. Automatic transfer switches connect the backup dc lighting to the station batteries upon a loss of normal ac supply and will then re-transfer back to the 120 V ac

power when the diesel generator is supplying load or normal ac power returns. These switches have a 3-second time delay on transfer from normal to backup sources to prevent nuisance operation caused by momentary voltage dips. These switches have also been sized to withstand expected levels of fault current. Separate circuit-breaker-type panel boards are used for this

lighting system. 9.5.3.2.3 Backup AC Lighting

The backup ac lighting subsystem is connected to non-Class lE 480 V MCCs through 480-120/240 V dry-type transformers. In the

event of a loss of normal ac power, this subsystem receives power from the onsite, nonsafety diesel generator (Section 8.3.1.1.1). All lighting fixtures connected to this lighting

subsystem are 120 V or 240 V fluorescent and are continuously energized.

The backup ac lighting subsystem supplements the backup dc lighting subsystem in the following areas: main control room, ESP area in the control building, Class lE switchgear areas in the service building, and essential bus inverter and rectifier equipment areas in the rod control and cable vault building. Separate ac circuit breaker-type panelboards are used for this

lighting subsystem.

BVPS-2 UFSAR Rev. 0 9.5-48 The backup ac lighting subsystem is connected to a single non-Class lE 480 V unit substation through a non-Class lE, 480 V MCC and 480 - 120/240 V dry type transformers. In the event of a loss of normal ac power, this 480 V unit substation is automatically loaded onto the onsite, nonsafety diesel generator (Section 8.3.1.1.1).

9.5.3.2.4 Main Control Room Lighting The main control room lighting is supplied from the normal ac buses. Alternating rows of fixtures are supplied from two separate MCC sources.

General lighting is from a louvered ceiling of the aluminum egg-crate type. Fixtures are fluorescent strips seismically-mounted above the louvers.

The system is capable of controlled illumination by use of switching from the panelboard circuit breakers. Lighting for

the face of the main control board can also be switched. The main control room also has backup dc incandescent fixtures powered from the non-Class lE dc buses. Fixtures are located to provide adequate illumination for safe shutdown operation and egress. Approximately 20 percent of the fluorescent fixtures in the main control room are connected to the backup ac lighting subsystem

as a supplement to backup dc illumination during loss of normal ac power. This subsystem can also provide operation for long periods of time without offsite power, since it is powered from the onsite, nonsafety diesel generator upon loss of normal ac power. 9.5.3.2.5 Egress Lighting and Exit Signs In order to comply with the rules and regulations of OSHA concerning exit signs and egress lighting, the following is provided:

1. Externally-illuminated Exit signs at all exits.

2. Adequate and reliable illumination for both vertical and horizontal exit facilities for clearly visible egress routes.

The external illumination for Exit signs, Direction to Exit signs, and egress lighting receives power from normal ac sources. During loss of normal ac power, these fixtures are fed

from the non-Class lE station batteries which are designed for a 2-hour duty cycle.

Backup lighting required for personnel safety in some areas is provided by local, self-contained, battery-powered, backup lighting units with a 1.5-hour minimum operation rating.

BVPS-2 UFSAR Rev. 0 9.5-48a 9.5.3.2.6 Safety-Related Areas The safety-related area lighting is generally supplied from the normal ac buses. However, lighting required for the control of safety-related equipment, such as the Class 1E switchgear and the ESP, has sufficient fixtures powered from the backup ac and/or dc subsystems to operate them during loss of normal ac

lighting. 9.5.3.2.7 Individual Sealed Beam or Fluorescent 8-hour Battery Pack Lighting

The lamp in a sealed beam/battery pack unit and the

fluorescent/battery pack fixtures will not normally be illuminated and will be activated upon a loss of normal ac power. The units will receive the necessary power to trickle charge the battery packs and to provide indication of available normal ac power from local normal ac lighting circuits. A sealed beam/battery pack unit will therefore be activated upon the loss of normal ac lighting power in the area serviced by the unit. The individual power supplies assure that the failure of any one component will not affect the balance of the units.

BVPS-2 UFSAR Rev. 12 9.5-49 9.5.3.3 Seismic Design The installation of all lighting subsystems in safety-related areas, including lighting transformers, panelboards, raceway, and all support structures, is designed to meet the seismic requirements of the area in which they are located.

9.5.3.4 Safety Analysis During normal plant operation, lighting is provided from normal buses. Upon loss of normal power, the backup dc and ac lighting subsystems automatically operate through sensing and controlling equipment. Each backup subsystem is backed up with

power from the onsite, nonsafety diesel generator or station batteries and has separate panels, conduit, wiring, controls, and fixtures. This separation of lighting systems protects

against a common mode failure. 9.5.3.5 Inspection and Testing Requirements

Design of the lighting system permits routine surveillance and testing without disrupting normal service. Proper functioning of normal ac lighting is verified by surveillance and inspection. All backup dc and ac lighting fixtures will operate from normal ac power, thus allowing for surveillance of all

lamps for proper operation. The automatic transfer switches on the backup dc lighting subsystem are provided with test switches to simulate loss of normal ac power. All automatic transfer switches on the backup dc subsystem are provided with main control room annunciation for loss of the dc backup source and for transfer to the backup source. All self-contained backup dc units are provided with local test switches to simulate loss of normal ac power.

9.5.4 Emergency

Diesel Generator Fuel Oil Storage and Transfer

System The emergency diesel generator fuel oil storage and transfer system is a safety-related system which stores fuel oil for the emergency diesel generators during normal operation and supplies fuel oil to the diesel generator fuel oil pumps when they are required to operate.

9.5.4.1 Design Bases

The emergency diesel generator fuel oil storage and transfer system is designed in accordance with the following criteria:

BVPS-2 UFSAR Rev. 0 9.5-50 1. General Design Criterion 2, as it relates to the ability of structures housing the system and the system itself to withstand the effects of natural phenomena (for example, earthquakes, tornadoes, hurricanes, and floods) as established in Chapters 2, 3, and Appendix Position 13 of Regulatory Guide 1.117.

2. General Design Criterion 4, with respect to structures housing the system, and the system itself, being capable of withstanding the effects of external

missiles and internally-generated missiles, pipe whip, and jet impingement forces associated with pipe breaks, and Position C.1 of Regulatory Guide 1.115.

3. General Design Criterion 5, as it relates to the capability of shared systems and components important to safety to perform required safety functions.

4. General Design Criterion 17, as it relates to the capability of the fuel oil system to meet independence and redundancy criteria. Beaver Valley Power Station - Unit 2 has redundant emergency diesel generators which satisfy the single failure criterion for essential power. Each emergency diesel generator is provided with its own separate fuel oil storage and

transfer system.

5. Regulatory Guide 1.54, as it relates to protective coatings applied to diesel fuel oil storage tanks.

6. Regulatory Guide 1.75, as it relates to physical independence of electrical systems.

7. Regulatory Guide 1.137, as it relates to the emergency diesel generator fuel oil systems, their design, fuel oil quality, and required tests.

8. ANSI Standard N195, with the exception of Section 6.3 which requires a duplex strainer for the transfer line from the storage tank to the day tank. Due to the unavailability of ASME Section III, Class 3, duplex strainers, redundant ASME Section III, Class 3, 'Y' type strainers are provided instead.

9. NUREG/CR-0660 (USNRC 1979), Enhancement of Onsite Emergency Diesel Generator Reliability.

10. Diesel Engine Manufacturers Association (DEMA), as it relates to the design of the diesel fuel oil system.

BVPS-2 UFSAR Rev. 12 9.5-51 11. The storage capacity of the system provides sufficient fuel oil for each diesel generator to operate continuously at maximum load for 7 days.

12. The system is designed in accordance with ASME Section III, Class 3.

13. The system is designed to operate at an ambient temperature between 55 and 120F and at ambient atmospheric pressure.

9.5.4.2 System Description

The emergency diesel generator fuel oil storage and transfer system (Figure 9.5-7) supplies fuel oil to th e emergency diesel generators. Table 9.5-1 lists the design parameters of the components in this system. Figure 3.8-43 shows the general arrangement of the system.

BVPS-2 UFSAR Rev. 0 9.5-52 The fuel oil accumulator tank, located on the diesel engine, ensures that the fuel headers are full at the time of initiating engine start. The tank capacity is approximately 0.9 gallons and is fabricated to the diesel engine manufacturer's standard

design. A separate, independent, emergency diesel generator fuel oil storage and transfer system is provided for each of the two emergency diesel generators. Each emergency diesel generator fuel oil storage and transfer system consists of a storage tank, a stick gauge, two transfer pumps, three strainers, a day tank, necessary piping, and valves.

The emergency diesel generator fuel oil storage tanks are sized to store sufficient fuel oil for 7 days of continuous operation of the associated diesel generator under maximum load conditions. Two full capacity, motor-driven, diesel generator fuel oil transfer pumps are used for each storage tank to transfer fuel oil to the fuel oil day tanks. The diesel generator building is a Seismic Category I designed tornado and missile-protected structure that is flood-protected to ground grade (Section 3.4). Each of the redundant fuel oil systems is located in a separate room within the diesel generator building. The fuel oil storage tanks are embedded in concrete below the diesel generator building (below grade elevation) where the fuel

oil can be maintained at a fairly constant temperature. Upon a loss of offsite power (LOOP), power is provided to each fuel oil transfer pump by its associated emergency diesel generator. The pumps operate in a lead-follow arrangement. On a low level signal from the day tank, the first pump starts. If this pump fails to maintain the level in the day tank, the second pump starts on a low-low level signal.

An orificed recirculation line in each pump discharge line back to the storage tank provides minimum flow through the pump. A 'Y' type strainer is installed in each pump discharge line to

minimize the transfer of solids to the day tanks. The system also provides protection against fuel oil overflowing from the day tank in the event that the transfer pump does not trip on a high level. This is accomplished by means of an overflow line from the top of the day tank to the storage tank. The integral accumulator tank also has a return line to the day tank for excess fuel.

The day tanks are sized to store a maximum of 1,100 gallons of fuel oil in accordance with NFPA Standard 37, Stationary Combustion Engines and Gas Turbines. The fuel oil day tank and fuel oil piping are located clear of any source of ignition such as open flames or hot surfaces. Open flames are not permitted in the diesel generator building except when associated with

maintenance activities. During

BVPS-2 UFSAR Rev. 12 9.5-53 these maintenance activities the appropriate station operating procedures will be followed. The fuel oil day tank and connecting piping are located a minimum distance of 10 feet from the emergency diesel generator engine, 10 feet from the emergency generator starting air compressors and insulated discharge piping, and 10 feet from the insulated diesel exhaust piping to preclude contact with these hot surfaces. Fuel oil piping to the diesel generator fuel oil pumps is directed to the opposite end of the diesel engine, away from the insulated exhaust piping. The day tanks are located in the diesel generator building at an elevation that will assure a positive pressure at the engine-driven fuel oil pumps. Each fuel oil day tank is mounted in a diked area. Within this area is a sump with a level switch and outlet drain piping. The volume of the dike area and sump is equal to the fuel oil day tank volume.

The outlet piping is used to remove oil and to ensure significant amounts of fluids will not remain in the dike or sump areas. Excess fuel oil is gravity-fed through the drainage

system directly to the waste oil system. The level switch indicates a high level within the sump and alarms in the main control room. At that time appropriate station operating

procedures will be followed. Both the storage tanks and the day tanks are separately vented

to the atmosphere and equipped with flame arresters. The vents are terminated outside the building in missile-protected areas. The storage tank vent terminates at approximately el 740 feet-6

inches. The fill connection terminates outdoors 3 feet-6 inches above

grade at elevation 736 feet-0 inches. This connection is provided with a locked closed valve and a threaded cap to prevent entrance of water into the fuel oil storage tank.

The fuel oil storage tank fill connection terminates at the bottom of the fuel oil storage tank. The fill connections are located a sufficient distance from the fuel oil transfer pump suction bells to enhance settling of sediment away from the fuel oil transfer pump suction bells.

To preclude the need for cathodic protection, all fuel oil storage tanks, day tanks, and piping are adequately protected from external corrosion by their enclosure in a heated building or by encasement in concrete. Interior and exterior surfaces of the fuel oil storage tanks are protected by coatings applied in accordance with Regulatory Guide 1.54, as described in Section 1.8, and in accordance with Steel Structures Painting Council Standards PA1, Paint Application Guide for Shop, Field, and Maintenance Painting. The interior surfaces of the fuel oil storage tanks are coated with a prime and finish coat of a high build epoxy paint. The exterior surfaces of the fuel oil

storage tanks are coated with a zinc-rich epoxy polyamide.

BVPS-2 UFSAR Rev. 10 9.5-54 Strainers are placed in the fill lines of the storage tanks and in the discharge piping of the fuel oil transfer pumps. The strainers, storage tanks, and day tanks have drain lines and provisions for periodic checks for water, sediment, etc., to minimize the possibility of contamination or deterioration of the fuel oil supply. Provisions are available on each tank for removal of excess water.

9.5.4.3 Safety Evaluation

The emergency diesel generator fuel oil storage and transfer system is designed to remain operable assuming a single failure during a LOOP. This system is safety-related, QA Category I, and is designed in accordance with ASME Section III, Class 3, and Seismic Category I requirements.

Each of the emergency diesel generator fuel oil systems is capable of providing for 7 days of operation at rated load per Regulatory Guide 1.137 and ANSI N-195. Sufficient additional capacity is also available to allow approximately 10 hours of diesel generator running time for test purposes before the fuel oil tanks must be topped off to maintain capacity. Each diesel

generator fuel oil transfer pump receives power from its associated diesel generator.

There are five major oil distributors within 40 miles of the site. Their normal diesel fuel stocks on hand and their delivery capabilities are presented in Table 9.5-2. A failure modes and effects analysis (FMEA) to determine if the instrumentation and controls (I & C) and electrical portions meet the single failure criterion, and to dem onstrate and verify how the General Design Criteria and IEEE Std 279-1971 requirements are satisfied, has been performed on the emergency

diesel generator fuel oil storage and transfer system. The FMEA methodology is discussed in Section 7.3.2. The results of this analysis can be found in the separate FMEA document (Section

1.7). 9.5.4.4 Inspection and Testing Requirements

The emergency diesel generator fuel oil supply piping is pressure-tested during construction and all active system components are functionally tested during start-up, as described in Section 14.2.12. The fuel oil for the diesel generator is monitored for water accumulation, and periodic samples are analyzed. Fuel oil used in the engines will meet the standards stated in the BVPS-2 Technical Specifications.

The fuel oil transfer pumps and all system valves will be in-service tested, as specified in Section 6.6. A manhole is provided for the inspection of the fuel oil storage tanks.

BVPS-2 UFSAR Rev. 0 9.5-54a 9.5.4.5 Instrumentation Requirements Each diesel generator fuel oil day tank is provided with two transfer pumps that have local selector switches with indicating lights for manual or automatic control. Each of the two lead pumps, when in auto, start on a low level in the day tank. The two standby pumps, when in auto, start on a low-low level in the day tank. The four pumps take their suction from the fuel oil storage tanks. The pumps stop on a high level in the day tank.

Local alarms are provided for fuel oil transfer pump discharge strainer differential pressure high, diesel generator fuel oil day tank level high and low, diesel generator fuel oil storage tank level high and low, and day tank fuel oil sump level high. These all annunciate on a common alarm in the main control room. These conditions are also monitored by the BVPS-2 computer.

9.5.5 Emergency

Diesel Generator Cooling Water System

9.5.5.1 Design Bases The emergency diesel generator cooling water system is designed

in accordance with the following criteria:

1. General Design Criterion 2, as it relates to structures housing the system and the system itself being capable of withstanding the effects of natural phenomena (earthquakes, tornadoes, hurricanes, and floods) as established in Chapters 2 and 3, and defined in Regulatory Guide 1.102 and 1.117.

2. General Design Criterion 4, with respect to structures housing the system and the system itself being capable

of withstanding the effects of external and internally

BVPS-2 UFSAR Rev. 0 9.5-55 generated missiles, pipe whip, and jet impingement forces associated with pipe breaks.

3. General Design Criterion 5, as it relates to the capability of shared systems and components important to safety being capable of performing required safety functions. Each emergency diesel generator is

provided with its own separate cooling water system.

4. General Design Criterion 17, as it relates to the capability of the cooling water system to meet independence and redundancy criteria, and General Design Criterion 44 to assure:

a. The system is capable of transferring heat from essential diesel generator components to a heat

sink under transient or accident conditions,

b. Redundant emergency diesel generators are provided, which satisfy the single failure criterion for standby onsite ac power sources, and

c. Separate cooling water lines are provided for each emergency diesel generator which satisfies the

capability to isolate components of a system or

piping to maintain system safety function.

5. General Design Criterion 45, as it relates to design provisions to permit periodic inspection of safety-related components and equipment of the system.

6. General Design Criterion 46, as it relates to design provisions to permit appropriate functional testing of

safety-related systems or components to assure structural integrity and leaktightness, operability and performance of active components, and the capability of the system to function as intended under

accident conditions.

7. IEEE Standard 387-1972 and Regulatory Guide 1.9, as they relate to the design of the emergency diesel generator cooling water system for qualification to a mild environment as referenced in Section 3.11.

8. Regulatory Guide 1.26, as it relates to the quality group classification of system components. This system is QA Category I, Safety Class 3. The engine-driven circulating pumps, the keep-warm pumps, and the engine itself are built to the manufacturer's

standards. All components such as piping, fittings, tanks, valves, pumps, etc up to the engine, conform to all the requirements of ASME Section III, Class 3.

BVPS-2 UFSAR Rev. 15 9.5-56 9. Regulatory Guide 1.29, as it relates to the seismic design classification of system components. This system is designed in accordance with Seismic Category I requirements.

10. Branch Technical Position ICSB-17 (PSB), as it relates to engine cooling water protective interlocks during accident conditions.

11. Diesel Engine Manufacturers Association Standard, as it relates to the design of the engine Cooling Water System. 12. NUREG/CR-0660 (USNRC 1979), Enhancement of Onsite Emergency Diesel Generator Reliability, as it relates

to the design of the cooling water system.

13. The emergency diesel generator cooling water heat exchangers are designed for a service water temperature of 90 F. 9.5.5.2 System Description The emergency diesel generator cooling water system, Figures 9.5-8 and 9.5-9 and Table 9.5-3, is an integral part of the diesel generator package.

Each diesel engine cooling system consists of a jacket water cooling system and an intercooler water system. The jacket water cooling system consists of an engine-driven jacket water circulating pump, water temperature regulating valve, water expansion tank, electric heater, ac motor-driven keep-warm circulating pump, and jacket water cooling heat exchanger. The intercooler water system consists of a direct engine-driven circulating pump, water temperature regulating valve, water expansion tank (both the intercooler system and the jacket water

system share the same expansion tank and a three-way thermostatic mixing valve), and heat exchanger. With the exception of the engine-driven circulating pumps and keep-warm pumps, all piping, fittings, tanks, valves, pumps, etc up to the

engine, conform to all the requirements of ASME III, Class 3. The jacket water cooling system provides cooling to the cylinder lines, cylinder heads, lube oil cooler, governor oil cooler, and

turbo charger cooling spaces. The system is designed and tested by the diesel engine manufacturer to ensure proper cooling. The heat rejection and capacity of the jacket water cooling system

is shown on Table 9.5-3. BVPS-2 UFSAR Rev. 15 9.5-56a The intercooler water system provides cooling to the turbo charged air intercooler and the alternator outboard bearing. The system is designed and tested by the diesel engine manufacturer to ensure proper cooling. The heat rejection and

capacity of the intercooler water system is shown on Table 9.5-3.

The emergency diesel generator cooling water system heat exchangers are cooled with water from the SWS (Section 9.2.1). Each diesel generator is supplied with service water from a service water pump powered from the emergency buses associated

with that generator. The motor-operated service water inlet valves to the diesel generator cooling system heat exchangers are opened on a safety injection signal or diesel generator running signal. The service water pumps are started on Start Step 3 of the diesel generator loading sequence (refer to Table

8.3-3). The service water inlet gate valves to the emergency diesel generators are started on Start Step 2 of the diesel generator loading sequence (refer to Table 8.3-3), and cycle to full open in 60 seconds to insure adequate cooling to the diesel generators. The portion of the SWS for the diesel generator appears on Figure 9.2-1.

The cooling water system maintains water in the diesel engine jacket within the manufacturer's specified limits of 95F to 170F for average temperature and temperature rise through the jacket. The cooling water can bypass the heat exchanger for

fast engine warmup. The jacket water expansion tank is located to ensure the required NPSH is provided on the circulating pumps, in accordance with the diesel engine manufacturer's recommended location. The jacket water expansion tank is sized by the diesel engine manufacturer to accommodate predicted system-leakage (Tables 9.5-3 and 9.5-7) and to maintain the required NPSH on the circulation pumps for 7 days of engine operation.

BVPS-2 UFSAR Rev. 16 9.5-57 The thermostatically-controlled electric water heater is suitable for maintaining the engine jacket cooling water at

125F in a minimum ambient temperature of 10F when the engine is not running. An ac motor-driven cooling water circulating pump is provided for moving the water through the jacket water

cooling system when the engine is not running. Each emergency diesel generator cooling water system provides cooling to the respective Diesel Generator lubrication oil cooler (Section 9.5.7).

Table 9.5-3 delineates design parameters of the emergency diesel generator cooling water system.

Makeup water to the cooling water system is added to the jacket water expansion tank from the nonsafety-related demineralized water system, which is normally isolated from the cooling water system. The 100-gallon jacket water expansion tank is the highest point of the emergency diesel generator cooling system to ensure that all components and piping are filled with water. Vent valves are provided to insure adequate draining and filling of the system.

A corrosion inhibitor is added to the system via a chemical addition connection. This inhibitor is compatible with the materials of the system and maintains water chemistry in conformance with the engine manufacturer's recommendations. Chemical addition is provided on the service water side of the heat exchangers to allow wet layup of the cooling system. A biodegradable chemical will be used so as not to adversely affect the service water chemistry requirements.

The engine coolers are designed to reject the engine heat loads with an inlet service water temperature of 90F. Maximum expected service water temperature is 89 F. 9.5.5.3 Safety Evaluation

The emergency diesel generator cooling water system is designed to remain operable during a LOOP. Each emergency diesel

generator cooling water system is independent, and is an integral part of the diesel engine.

There is no sharing of cooling water subsystems or components between the two emergency diesel generators. Each diesel generator has its own cooling water subsystems which are cooled by redundant service water trains. Section 9.2.1 and Figure 9.2-1 describe the interface to, and the analysis of, the service water system.

No single failure or piping interconnections between the eng ine water jacket, lube oil cooler, governor lube oil cooler, and the engine air

BVPS-2 UFSAR Rev. 0 9.5-58 intercooler can cause degradation of both emergency diesel generator engines. This system is safety-related, QA Category I, is designed in accordance with Seismic Category I requirements, and is protected from pipe break effects, as described in Section 3.6. A failure modes and effects analysis (FMEA) to determine if the

instrumentation and controls (I & C) and electrical portions meet the single failure criterion, and to demonstrate and verify how the General Design Criteria and IEEE Standard 279-1971 requirements are satisfied, has been performed on the emergency diesel generator cooling water system. The FMEA methodology is discussed in Section 7.3.2. The results of this analysis, can

be found in the separate FMEA document (Section 1.7). 9.5.5.4 Inspection and Testing Requirements

The emergency diesel generator cooling water system piping is pressure tested during construction, and system components, pumps, valves, and controls are tested and operationally checked when the diesel generator is tested (Section 8.3). Pre-operational tests are performed as described in Section 14.2.12. After operating the diesel engine for extended periods of time (over 24 hours) from no-load up to 20 percent of rated load, the diesel generator will be run at above 50 percent load for at

least 1 hour for each 24 hour period no-load operation, as recommended by the diesel engine manufacturer. The diesel generator can be run at loads greater than 20 percent of rated

load continuously with no adverse affect on any of the operating parameters.

9.5.5.5 Instrumentation Requirements Selector switches with indicating lights are provided locally for the diesel generator jacket water keep-warm pumps. These pumps may be operated manually or automatically. Automatic operation is available to start the pumps when the diesel generator engine speed is below synchronous speed and the diesel generator jacket cooling water pressure is below a predetermined set-point, and the pumps will stop when the diesel generator engine speed is above synchronous speed or the diesel generator jacket cooling water pressure is above a predetermined set-point. Selector switches with indicating lights are provided for the diesel generator jacket water heaters. These heaters may be operated manually or automatically. When these heaters are in the automatic mode, the respective keep-warm pump running in conjunction with its respective diesel generator jacket cooling water temperature (below a predetermined point) will energize the water heater.

Jacket cooling water temperature control valves are provided for each diesel generator. These valves are automatically operated by means

BVPS-2 UFSAR Rev. 0 9.5-59 of a temperature controller. These valves will modulate when their respective diesel generator engine speed is above a predetermined point or when their respective diesel generator jacket cooling water pressure is above a predetermined point.

Control switches with indicating lights are provided for the diesel generator heat exchanger service water header valves. Refer to Section 9.2.1.1.5 for additional control information for these valves.

Annunciation is provided locally for the jacket water expansion tanks low water levels. Demineralized water may be added manually to the jacket water expansion tanks if a low water level exists. Alarms are also provided locally for high and low cooling water temperature and cooling water low pressure. These local annunciators are monitored in the main control room by a

common trouble alarm. They are also monitored by the BVPS-2 computer system.

9.5.6 Emergency

Diesel Generator Air-Starting System Each emergency diesel generator is air-started by a dedicated

air-starting system. Redundant components are provided for each emergency diesel generator to enhance starting reliability. Each air compressor in a system has sufficient capacity to

recharge the air storage system in 30 minutes from minimum to maximum starting air pressure.

9.5.6.1 Design Bases The emergency diesel generator air-starting system is designed

in accordance with the following criteria:

1. General Design Criterion No. 2, as it relates to the ability of structures housing the system to withstand the effects of natural phenomena (for example, earthquakes, tornadoes, hurricanes, and floods) as

established in Chapters 2 and 3.

2. General Design Criterion No. 4, with respect to structures housing the system and the system itself being capable of withstanding the effects of external missiles and internally-generated missiles, pipe whip, and jet impingement forces associated with pipe breaks. 3. General Design Criterion No. 5, as it relates to the capability of shared systems and components important to safety to perform required safety functions. Each emergency diesel generator is provided with its own separate redundant air-starting system.

4. General Design Criterion 17, as it relates to the capability of the emergency diesel generator air-

starting system to

BVPS-2 UFSAR Rev. 19 9.5-60 meet the independence and redundancy criteria. Specific criteria and guidance necessary to meet these requirements are addressed in the Diesel Engine Manufacturers Association Standard, as it relates to

the emergency diesel generator air-starting system.

5. Regulatory Guide 1.9, as it relates to the design of the emergency diesel generator air-starting system.

6. Regulatory Guide 1.26, as it relates to quality group classification of the system components. This system

is QA Category I, Safety Class 3.

7. Regulatory Guide 1.29, as it relates to seismic design classification. This system is designed in accordance

with Seismic Category I requirements.

8. Regulatory Guide 1.68, as it relates to preoperational and start-up testing of the air-starting system.

9. IEEE Standard 387-1972, as it relates to the design of the emergency diesel generator air-starting system for

qualification to a mild environment as referenced in

Section 3.11.

10. Branch Technical Position ICSB-17, as it relates to emergency diesel generator protective trips.

11. The emergency diesel generator air-starting system also meets the following specific criteria:

a. Each emergency diesel generator is provided with a dedicated starting system, each consisting of two air compressors, two air receivers, an air dryer, injection lines and valves, and devices to crank the engine. Redundant components are provided for

each emergency diesel generator to enhance

starting reliability.

b. Each of the redundant air-starting systems is designed to provide the manufacturer's requirement for five starting cycles from an initial pressure

of 425 psig without recharging the starting air

receivers. Table 9.5-11 shows the manufacturer's test data, which demonstrated the capability of the starting air system to start the engine five times, each attempt within 10 seconds, without recharging of the receiver.

c. Periodic surveillance testing is performed on the emergency diesel generator air start system. In accordance with Technical Specification 3.8.3, the emergency diesel generator air start system's capability is verified by determining that at least one air start receiver is at the minimum pressure to support five starting cycles. This periodic verification determines that sufficient air volume is available to support five engine start cycles without recharging.

BVPS-2 UFSAR Rev. 19 9.5-60a The emergency diesel generator start system (including the air start subsystem and supporting electronic circuitry) is designed to crank the diesel engine to the manufacturer's recommended rpm to support the generator's design capability to reach its rated voltage and frequency, and to begin load sequencing within 10 seconds. The Technical Specification 3.8.1 surveillance requirements demonstrate the ability of each emergency diesel generator to reach its rated voltage and frequency and to begin load sequencing within 10 seconds for one start demand (as required by accident analyses).

d. Alarms are provided which will alert operating personnel if the air receiver pressure falls below

the minimum allowable value.

e. Refrigerant air dryers and filters are provided to remove moisture and any foreign material from the

starting air.

9.5.6.2 System Description

The emergency diesel generator engine starting system is shown

on Figure 9.5-10 and the principal components are listed in

Table 9.5-10. The system is located in the diesel generator building, which is a Seismic Category I, tornado and missile-protected structure. Each emergency diesel generator is provided with a dedicated starting system, which is capable of starting the engine without offsite power. Each starting system includes two ac motor-driven air compressors, two air storage tanks, an air dryer, all necessary valves and fittings, and complete instrumentation and control systems. All system components downstream of the inline plug valve between the dryer and receiver are designed in accordance with ASME Section III, Class 3.

All piping and components from the dryer discharge plug valves to the diesel engine air start solenoid, inclusive, are designed in accordance with ASME III. Engine-mounted components and the

starting air compressors which are not covered in the rules of

ASME III, Code Class 3, are designed in accordance with the diesel manufacturer's latest standards for reliability. These

components include the following:

1. Engine-mounted air start distributors,

2. Engine-mounted air start valves,

3. Engine-mounted starting booster air valve, and

4. Engine-mounted fuel rack shutdown and starting booster servo.

A skid-mounted, 450-psig design pressure, 0.2-cubic foot, ASME

III Class 3 air tank is provided in the air supply line to the servo fuel rack shutdown and fuel rack booster sources. A check valve isolates the tank from the starting air system. The air

tank is designed by the diesel manufacturer to ensure a source

of air for positive fuel shutoff in the event of a loss of all

starting air pressure in the

BVPS-2 UFSAR Rev. 2B 9.5-61 main starting air system. Approximately five such stops can be achieved with the tank volume provided. The air start system is not required to control engine operation

after an emergency start. The air start solenoid valves, 2EGA*SOV202-1, 2 and 2EGA-SOV203-1, 2, are normally closed and both valves are opened on a diesel start signal to admit air to the air admission valves in each of the inlet lines to the engine. The air admission valves allow the starting air to enter the engine under control of the air start distributor.

During an engine start, air pressure from the air start header is applied to the auxiliary start control device of the fuel

rack booster, which forces the piston in the device to move inward. This action causes the control linkage and the fuel injector pump racks to move to the starting fuel position. Energization of the shutdown solenoid valve, 2EGA*SOV201-1, 2, opens the valve to allow starting air pressure to be applied to the opposite side of the piston in the auxiliary start control

device, forcing the piston to move outward. This suction causes the control linkage and the fuel injection pump rack to move to the "no fuel" position.

Four shuttle valves in series are incorporated to control the rack boost function of the fuel rack servo cylinder. The

operation of each valve is as follows:

1. The first shuttle valve in the series selects the starting air header that will supply the rack boost pressure. The B header is ordinarily selected unless the pressure falls such that it cannot overcome the shuttle valve spring, in which case the valve selects the other header.

2. The second shuttle valve in series vents the boost pressure in case of overspeed governor actuation due

to cranking.

3. The third shuttle valve vents the boost pressure if a shutdown signal from any source other than the overspeed governor and actuates the shutdown solenoid during cranking.

4. The fourth shuttle valve vents the boost pressure when the engine has built up sufficient lube oil to move

the shuttle against the spring pressure. Each diesel engine is equipped with a 3-way shutdown solenoid valve that is normally closed. Opening this valve will actuate

the fuel BVPS-2 UFSAR Rev. 9 9.5-62 rack servo shutdown cylinder to shut down the engine. It will remain open until after the engine has come to a complete rest. A check valve upstream of the tank is installed to ensure a source of air for positive shutdown in the event of a loss of

starting air pressure in the main air receiver. Air compressor cross-connect lines are provided between redundant diesel generators. Cross-connect valves, which are normally closed, permit the supply air compressor from one emergency diesel generator to be used to restore air pressure in the second emergency diesel generator air starting system air receiver tanks (Figure 9.5-10). The air receivers between the two emergency diesel generator trains are prevented from being cross-connected due to check valves in the inlet lines; only the air compressor discharge can be cro ss-connected. These cross-connect valves will be controlled by existing BVPS-2 administrative procedures. Appropriate precautions will be included in the operating manual for the diesel generators to permit their use only as described in Section 9.5.6.2. When both compressors for the same train are inoperable, a compressor will be used to supply air pressure as required.

The refrigerant air dryers are cycling, heat sink type dryers. They are thermostatically controlled and have automatic water separators and drains. A high heat sink temperature alarm is

provided to alert operating personnel of a high dew point temperature.

Included with the air dryers is an aftercooler, two coalescing filters, a particulate filter and pressure and temperature gauges. A flow switch on the aftercooler is provided to give a permissive for the compressor to start if there is adequate cooling air flow through the aftercooler.

The air storage tanks are equipped with pressure gauges, pressure relief valves, and other fittings for connection of the air-starting systems to the emergency diesel generators. Tank bottom drains are provided for periodic blowdown of accumulated moisture.

BVPS-2 UFSAR Rev. 0 9.5-62a The design pressure and the normal operating supply pressure of the air storage tanks are specified by the emergency diesel generator manufacturer. The ac compressor motor is furnished with automatic and manual start and stop control.

9.5.6.3 Safety Evaluation

The emergency diesel generator starting system is designed to remain operable during a loss of offsite power. Redundant components are provided to enhance the starting reliability of

each emergency diesel generator. Without the air compressor operating, the air receivers in each train of each diesel engine air-starting system are capable of supplying five starting cycles per train. The manual feature of the emergency diesel generator starting system is provided in addition to the automatic starting mode, in compliance with IEEE Standard 387-1972. The system is QA Category I, Safety Class 3, and is protected from pipe break effects, as described in

Section 3.6. A failure modes and effects analysis (FMEA) to determine if the

instrumentation and controls (I & C) and electrical portions meet the single failure criterion, and to demonstrate and verify how the General Design Criteria and IEEE Standard 279-1971 requirements are satisfied, has been performed on the emergency diesel generator air-starting system. The FMEA methodology is discussed in Section 7.3.2. The results of this analysis can be

found in the separate FMEA document (Section 1.7). 9.5.6.4 Inspection and Testing Requirements

The emergency diesel generator air-starting system is inspected during construction to ensure the quality of the air-starting system, and to ensure that all components of the system operate properly. Periodic blowdown of the air receivers is performed to check for any moisture or foreign material. The system is routinely observed during periodic testing as prescribed in the Technical Specifications (Chapter 16). Preoperational tests are performed as described in Section 14.2.12.

9.5.6.5 Instrumentation Requirements

Selector switches with indicating lights are provided locally for the emergency diesel generator air-starting air compressors and the air dryers. The air-starting air compressors can be operated manually or automatically. Automatic actuation of the air compressors is governed by the air receiver pressure. Low air-starting air receiver pressure is annunciated locally, and

is also monitored by the BVPS-2 computer. The local annunciator actuates a common diesel generator trouble alarm in the main control room.

BVPS-2 UFSAR Rev. 0 9.5-62b A temperature switch maintains the proper heat sink temperature in the diesel air dryers. High heat sink temperature is annunciated locally and monitored by the BVPS-2 computer. The local annunciator actuates a common diesel generator trouble alarm in the control room. A flow switch on the aftercoolers gives a permissive for the compressors to start on a positive cooling air flow signal.

Diesel generator air start solenoids are provided for each diesel generator. The air start solenoids will energize to open on a diesel generator start signal or on a diesel generator low speed signal provided all of the following conditions exist: diesel generator barring device No. 1 and No. 2 have been disengaged, diesel generator engine trouble signal has been reset, and the diesel generator electrical protection signal has been reset. The air start solenoids will be de-energized to

close provided any of the above conditions do not exist.

9.5.7 Emergency

Diesel Generator Lubrication System

9.5.7.1 Design Bases

The emergency diesel generator lubrication system is designed in accordance with the following criteria:

1. General Design Criterion 2 and Regulatory Guides 1.117 and 1.102, as they relate to structures housing the

system and the system itself being capable of

withstanding the effects of natural phenomena (earthquakes, tornadoes, hurricanes, and floods) as established in Chapters 2 and 3.

2. General Design Criterion 4, with respect to structures housing the system and the system itself being capable of withstanding the effects of external missiles and internally-generated missiles, pipe whip, and jet impingement forces associated with pipe breaks.

3. General Design Criterion 5, as it relates to shared systems and components important to safety being capable of performing required safety functions. Each emergency diesel generator provided with its own separate lubrication system.

4. General Design Criterion 17, as it relates to the emergency diesel generator lubrication system to meet independence and redundancy criteria.

5. Regulatory Guide 1.9, as it relates to selection, design, and qualification of emergency diesel generator units.

6. Regulatory Guide 1.26, as it relates to quality group classification of system components. This system is

QA Category I, Safety Class 3.

BVPS-2 UFSAR Rev. 0 9.5-62c 1. General Design Criterion 2 and Regulatory Guides 1.117 and 1.102, as they relate to structures housing the system and the system itself being capable of withstanding the effects of natural phenomena (earthquakes, tornadoes, hurricanes, and floods) as established in Chapters 2 and 3.

2. General Design Criterion 4, with respect to structures housing the system and the system itself being capable

of withstanding the effects of external missiles and

internally-generated missiles, pipe whip, and jet impingement forces associated with pipe breaks.

3. General Design Criterion 5, as it relates to shared systems and components important to safety being capable of performing required safety functions. Each

emergency diesel generator provided with its own separate lubrication system.

4. General Design Criterion 17, as it relates to the emergency diesel generator lubrication system to meet

independence and redundancy criteria.

5. Regulatory Guide 1.9, as it relates to selection, design, and qualification of emergency diesel generator units.

BVPS-2 UFSAR Rev. 0 9.5-63 7. IEEE Standard 387-1972, as it relates to the emergency diesel generator lubrication system for qualification to a mild environment as referenced in Section 3.11.

8. NUREG/CR-0660 (USNRC 1979), as it relates to the design of the emergency diesel generator lubrication

system. 9. Regulatory Guide 1.29, as it relates to the seismic design classification of system components. This system is designed in accordance with Seismic Category I requirements.

10. Diesel Engine Manufacturers Association Standard, as it relates to the design of the emergency diesel

generator lubrication system.

11. The emergency diesel generator lubrication system also meets the following specific criteria:

a. The operating pressure, temperature differentials, flow rate of the engine-driven lubricating oil, and heat removal rate for the cooler of this system are in accordance with recommendations of the emergency diesel generator manufacturer.

b. The temperature of the lubricating oil is automatically maintained above a minimum value by means of an independent recirculation loop, including its own pump and heater, to enhance the first try starting reliability of the emergency

diesel generator when in the standby condition.

c. The system is equipped with filters and strainers to remove impurities from the oil during engine operation.

d. The diesel engine is equipped with a vapor extraction system and crankcase blow-out pots to

mitigate the consequences of a crankcase

explosion. 9.5.7.2 System Description

The emergency diesel generator lubrication system (Figure 9.5-11) provides essential lubrication to the components of the emergency diesel generator. The engine lubrication system is integral with the engine. Included in the lubrication oil system for each engine is an engine-driven lube oil pump, an ac

motor-driven keep-warm and pre-lube pump, an electric lube oil keep-warm heater, a separate rocker arm lube oil system with an ac motor-driven rocker arm pre-lube pump and engine-driven

rocker arm lube pump, a crankcase vapor extraction

BVPS-2 UFSAR Rev. 0 9.5-64 system with an oil separator (Figure 9.5-12), filters and strainers, heat exchangers, thermostatic control valves, piping, and fittings.

The crankcase vacuum system (Figure 9.5-12) includes a crankcase vacuum pump, oil separator, piping and fittings. Table 9.5-9 lists the design parameters for the crankcase vacuum system. The crankcase vacuum system removes oil vapors from the diesel engine crankcase. The operation of the crankcase vacuum system is either manual or automatic. The vacuum pump is powered from the Class lE source of power. The crankcase vacuum system operates during all modes of diesel operation, however, it is not essential to the safe, reliable operation of the diesel engine and therefore the system is designated nonnuclear safety-related (NNS). The diesel crankcase is provided with relief ports to mitigate the

consequences of a crankcase explosion. The engine-driven lubricating oil pump has sufficient capacity

to ensure adequate lubrication of the main bearings, crank pins, camshaft bearings, and other oil-lubricated wearing parts, as required. The engine-driven rocker arm lube oil pump ensures adequate lubrication of the rocker arms and valve gear while the emergency diesel generator is operating.

Operation of the rocker arm and pre-lube system, as recommended by the diesel engine manufacturer , will establish a sufficient oil film and on the rocker arm wearing parts to preclude the requirement for operation of the electric-driven rocker arm and pre-lube pump during emergency engine start.

The keep-warm and pre-lube pump operates continuously during the standby condition of operation to circulate oil through the electric keep-warm heater to the bearings, rods, and other essential parts, except the rocker arm assembly. The rocker arm pre-lube pump is manually operated on an as-needed basis to provide oil to the rocker arm assembly. The lubricating oil filters and strainers are multiple element, bypass type, capable of filtering out 5 micron size particles. The three lubrication oil strainers per engine are of the continuous, full-flow type utilizing suitable filtering and straining media to filter out 35 micron size particles.

Operation of the diesel engine keep-warm and pre-lube system is continuous in accordance with the diesel engine manufacturer recommendations. Lube oil from parts supplied by

the keep-warm and pre-lube system drain back to the engine oil sump and therefore will not result in dangerous accumulations of lube oil that could ignite.

Manual operation of the diesel engine rocker arm pre-lube system is in accordance with the manufacturer's recommendation of 5 to 30 minutes of pump operation prior to all starts except emergency starts. The unlikely accumulation of lube oil that could ignite is eliminated by operation of

the systems in accordance with

BVPS-2 UFSAR Rev. 0 9.5-64a manufacturer recommendations coincident with proper maintenance and surveillance of the lube oil system. The diesel engine keep-warm and pre-lube pump, rocker arm pre-lube pump, rocker arm lube oil pump, keep-warm heater, and engine driven lube oil pump design parameters are shown in Table 9.5-8. The lubricating oil cooler is a shell and tube type (Figures 9.5-8 , 9.5-9 , and 9.5-11) and is suitable for the temperatures and pressures encountered in service. The oil cooler is capable of controlling the lubricating oil temperature at the required values by using the emergency diesel generator cooling water. The coolers are designed in accordance with the mechanical standards for Tubular Exchanger Manufacturers Association (TEMA) Class R coolers, and conform to the ASME Boiler and Pressure Vessel Code, Section III, Class 3. The total heat removal rates and system parameters for lube oil cooling are shown on Table 9.5-3 and are in accordance with manufacturer recommendations.

Oil pressure is monitored by four pressure switches, which will trip the emergency diesel generator upon receipt of a low

pressure signal (approximately 60 psig) by any two of the four switches. Trip will occur during testing mode only, not during emergency mode. Operation of any lube oil pressure switch will sound an alarm during test or emergency mode of operation. The lubricating oil level in the engine oil sump is monitored for low and high level. Actuation of either the low or high level switch will sound an alarm. The rocker arm lube oil reservoir level is monitored for high level, and the level is maintained by a level control valve.

Addition of lube oil to the engine lube oil sump, if required, shall be via the sump fill connection. The rise in sump oil level shall be verified by comparing the amount of oil added and the indicated rise in level as shown on the sump dip stick. The point of lube oil addition is clearly identified on the

emergency diesel engine. 9.5.7.3 Safety Evaluation

The emergency diesel generator lubrication system provides a completely separate and independent engine lubrication system

for each diesel generator. The lube oil keep-warm and pre-lube pump runs continuously to ensure that the lubricating oil is maintained at the desired temperature, even while the engine is not running. Lubrication oil is kept warm

BVPS-2 UFSAR Rev. 0 9.5-65 by using a thermostatically-controlled electric heater. The lubricating oil pump discharge is constantly monitored for pressure.

The system is QA Category I, is designed in accordance with Seismic Category I requirements, and is protected from pipe break effects, as described in Section 3.6. A locked-closed

administratively-controlled valve at the fill connection prevents deleterious material from entering the system. Qualified personnel will add lubricating oil to the system using procedures developed and proven satisfactory during the preoperational and start-up testing program.

A failure modes and effects analysis (FMEA) to determine if the instrumentation and controls (I & C) and electrical portions meet the single failure criterion, and to demonstrate and verify

how the General Design Criteria and IEEE Standard 279-1971 requirements are satisfied, has been performed on the emergency diesel generator lubrication system. The FMEA methodology is discussed in Section 7.3.2. The results of this analysis can be found in the separate FMEA document (Section 1.7).

9.5.7.4 Inspection and Testing Requirements The emergency diesel generator lubrication system piping is

inspected during construction. Pre-operational tests are performed in accordance with Section 14.2.12. All system components are tested when the diesel generator is tested (Section 8.3). The system is checked periodically for leakage, lube oil deterioration, and water accumulation.

9.5.7.5 Instrumentation Requirements Control switches with indication are provided locally for the

desired operation of the emergency diesel generator rocker arm pre-lube pump, keep-warm and pre-lube pump, and pre-lube oil heater. The rocker arm pre-lube pump can be run manually or automatically. The automatic operation is controlled by a emergency diesel generator speed interlock start of pump on low speed, and stopping of pump on high speed diesel generator. The keep-warm and pre-lube pump can be run continuously (manually) and will be shunt tripped upon energizing diesel generator start circuit 1 or 2. The pre-lube oil heater is a thermostatically-

controlled heater that can be energized manually if the keep-warm and pre-lube pump is running. The heater can be operated automatically and is energized provided the keep-warm and pre-lube pump is running, the emergency diesel generator lube oil temperature is not high, and the emergency diesel generator speed is not high.

Annunciation is provided locally and actuates a common trouble annunciator in the main control room for the following

conditions: lube oil pressure low, low-low, and extreme low, lube oil temperature high and low, rocker arm lube oil reservoir level high, lube oil sump level high and low, and emergency

diesel generator crank case

BVPS-2 UFSAR Rev. 0 9.5-66 pressure high. The previously mentioned conditions are also monitored by the BVPS-2 computer. Lube oil temperature and pressure interlocks will automatically shut down the emergency diesel generator only during the test mode of operation. The other conditions mentioned are for annunciation only and are not associated with the emergency diesel generator trip circuit in any mode of operation.

9.5.8 Emergency

Diesel Generator Combustion Air Intake and Exhaust System

9.5.8.1 Design Bases

The emergency diesel generator combustion air intake and exhaust system is designed in accordance with the following criteria:

1. General Design Criterion 2, as it relates to the ability of structures housing the system and system components to withstand the effects of natural phenomena (for example, earthquakes, tornadoes, hurricanes, and floods).

2. General Design Criterion 4, with respect to structures housing the systems and the system components being capable of withstanding the effects of external

missiles and internally-generated missiles, pipe whip, and jet impingement forces associated with pipe breaks. 3. General Design Criterion 5, as it relates to shared systems and components important to safety being capable of performing required safety functions.

4. General Design Criterion 17, as it relates to the capability of the emergency diesel generator combustion air intake and exhaust system to meet independence and redundancy criteria.

5. Regulatory Guide 1.26, as it relates to quality group classification of the system components. This system is QA Category I, Safety Class 3.

6. Regulatory Guide 1.29, as it relates to the seismic design classification of system components. This system is designed in accordance with Seismic Category I requirements.

7. IEEE Standard 387-1972, as it relates to the design of the emergency diesel generator combustion air intake and exhaust system for qualification to a mild environment as referenced in Section 3.11.

8. Regulatory Guide 1.9, as it relates to the design of the emergency diesel generator combustion air intake

and exhaust system.

BVPS-2 UFSAR Rev. 0 9.5-67 9. Regulatory Guide 1.115, as it relates to the protection of structures, systems, and components important to safety from the effects of turbine missiles.

10. Regulatory Guide 1.117, as it relates to the protection of structures, systems, and components important to safety from the effects of tornado missiles.

11. Branch Technical Position ASB 3-1 and MEB 3-1, as they relate to protection against postulated piping failures, breaks, and leakage locations inside and

outside the containment.

12. Each emergency diesel generator is provided with an independent and reliable combustion air intake and exhaust system. The system is sized and physically arranged such that no degradation of engine function is experienced when the diesel generator set is required to operate continuously at the maximum power output. 13. The combustion air intake system is provided with an air filter capable of reducing airborne particulate material over the entire time period that emergency power is required. The combustion air is taken directly from outside the building with the air inlet

27 feet above ground level.

14. Suitable design precautions are taken to preclude degradation of the diesel engine power output due to exhaust gases and other diluents that could reduce the oxygen content below acceptable levels.

15. The total air intake and exhaust system pressure losses shall not exceed the maximum pressure losses specified by the diesel generator manufacturer.

16. NUREG/CR-0660 (USNRC 1979), Enhancement of Onsite Emergency Diesel Generator Reliability.

17. Diesel Engine Manufacturers Association (DEMA) Standards, as it relates to the design of the combustion air intake and exhaust system.

9.5.8.2 System Description The emergency diesel generator combustion air intake and exhaust

system is shown on Figure 9.5-12. The emergency diesel generator combustion air intake and exhaust

system is located in the diesel generator building, as shown on Figure 3.8-43. The building is Seismic Category I, mis sile-protected, and above the probable maximum flood level.

BVPS-2 UFSAR Rev. 0 9.5-68 Each emergency diesel generator is provided with an air filter of the dry type, an air intake silencer (of the in-line type), and an exhaust silencer. The pressure losses through the emergency diesel generator combustion air intake and exhaust system do not exceed the manufacturer's recommendation, taking into consideration the piping, silencers, and intake and exhaust structures. Combustion air intake for each diesel engine is

from outside the diesel engine generator building and is separated from the exhaust such that intake air will not be diluted or contaminated by exhaust products (Figure 3.8-43). This arrangement precludes the potential of fire extinguishing gases and combustion products from being drawn into the combustion air intake system. The emergency diesel generator combustion air intake is provided with a downward oriented low velocity air inlet plenum equipped with a screened opening. This precludes direct entrainment of precipitation into the combustion air intake during either standby or operating conditions. Dust is prevented from accumulating within the combustion air intake during standby conditions by the same oriented intake plenum. During diesel operation under conditions of high atmospheric dust

concentrations, the dry media intake filter intercepts particulate matter before it reaches the diesel combustion chambers. Surveillance will be performed during diesel monthly availability testing (Section 8.3) to ensure diesel generator availability on demand.

The emergency diesel generator exhaust is equipped with a normally open low point drain. The exhaust outlet is at the roof level of the diesel generator building and is protected by

a concrete hood (Figure 3.8-43). This design will protect the exhaust from abnormal climatic conditions. Running of the diesel generator for availability testing will blow collected

dust out of the exhaust. 9.5.8.3 Safety Evaluation

The emergency diesel generator combustion air intake and exhaust system provides the required air to the diesel engine for

combustion and an acceptable method of expelling the gaseous exhaust products to the atmosphere.

The emergency diesel generator will be operated in accordance with the recommendations of NUREG/CR-0660 (USNRC 1979) as it pertains to the combustion air intake and exhaust system.

The emergency diesel generator exhaust ductwork terminates outside the diesel generator building in a missile-protected area. The piping which is exposed to atmospheric conditions is protected from clogging due to ice and snow.

The emergency diesel generator combustion air intake and exhaust system is designed to remain operable during a LOOP (Section 8.3). The system is QA Category I and is designed in accordance

with BVPS-2 UFSAR Rev. 0 9.5-68a Seismic Category I requirements. There are no active components in the system. The emergency diesel generator combustion air intake and exhaust system is designed so that failure of any one component will not result in the loss of function of more than one diesel generator. The loss of one diesel generator and its associated

load group does not prevent safe shutdown of the plant (Section 8.3). Thus, failure of any one component of the emergency diesel generator combustion air intake and exhaust system does not preclude safe shutdown of the plant following a LOCA and a LOOP. 9.5.8.4 Inspection and Testing Requirements The emergency diesel generator combustion air intake and exhaust system is inspected for leaks and blockage during construction, with pre-operational testing and periodical testing thereafter to ensure that components of the system operate properly. These inspections are normally accomplished during test runs for the diesel engines. Air filters are replaced periodically. Details of in-service inspections are given in Section 6.6. Pre-

operational tests are performed as described in Section 14.2.12. 9.5.8.5 Instrumentation Requirements

A pyrometer with a selector switch is provided at the engine to indicate cylinder and turbocharger exhaust temperatures. In addition, a manometer is supplied in the intake system downstream of the air filter to enable periodic monitoring of filter pressure drop.

BVPS-2 UFSAR Rev. 16 9.5-69 9.5.9 Reactor Plant Gas Supply System The reactor plant gas supply system consists of a high pressure and a low pressure nitrogen supply system.

9.5.9.1 Design Bases

The reactor plant gas supply system (Table 9.5-4) design is based on the following:

1. To supply nitrogen to plant systems for the purpose of pressurization, gas content control, or providing a purge and/or diluent medium. The BVPS-2 plant

requirements are shown in Table 9.5-5.

2. The portion of the high pressure nitrogen header from and including the outer containment penetration isolation valve to the safety injection accumulators is designed to ASME Section III, Class 2. The portion of the high pressure header from the BVPS-1 connection to the outer containment penetration isolating valve and the entire low pressure Nheader are designed as NNS class.

9.5.9.2 System Description

Nitrogen is supplied to manifolds that distribute the gas to the components described as follows. Nitrogen is supplied from a nitrogen tank truck located at any tube trailer station. Stations are provided at both BVPS-1 and BVPS-2. The nitrogen tank truck which can supply high pressure gaseous nitrogen to both BVPS-1 and BVPS-2 also provides low pressure gaseous nitrogen through a pressure regulating valve.

The nitrogen system is comprised of two subsystems, a high pressure system and a low pressure system. They are designed to provide an adequate supply of nitrogen, of suitable quality and pressure, for normal nitrogen requirements to various components (Table 9.5-5). High pressure nitrogen is supplied at approximately 1,500 psig from the nitrogen tank tr uck. A pressure control valve in the BVPS-2 header maintains downstream system pressure at 640 psig. The nitrogen is supplied at this pressure to the safety injection accumulators to maintain the pressure necessary for accumulator operation. Two redundant, Class lE solenoid-operated isolation valves are located in the high pressure header. These valves are remotely operable for pressurizing the accumulators, as required. Redundant venting capability is also

provided for the accumulators by use of safety grade valves and piping, as described in Sections 9.5.9.3 and 6.3, which are used during safety grade cold shutdown conditions. The high

BVPS-2 UFSAR Rev. 20 9.5-70 pressure nitrogen line penetrating the containment structure contains an air-operated containment isolation valve outside and inside the containment structure. The system Safety Class 2 boundary begins at the outer containment isolation valve. This portion of the system meets the containment isolation

requirements of Section 6.2.4 and is described in detail in that

section.

The low pressure nitrogen header is supplied through a pressure regulating valve from the high pressure nitrogen header at 150

psig. Low pressure nitrogen is supplied to the steam generators via the blowdown lines through a flow measuring instrument for

the purpose of chemical mixing during wet layup. Nitrogen is

also supplied at low pressure to the steam generators to provide a nitrogen blanket during dry layup conditions. A steam

generator evacuation pump is provided to produce a vacuum in the

steam generators before the nitrogen injection. Nitrogen is also supplied to the volume control tank, the pressurizer relief tank, and the primary drains transfer tank for pressure control.

In addition, low pressure nitrogen is supplied to BVPS-1.

9.5.9.3 Safety Evaluation

All nitrogen gas storage is located at the tube trailer stations, with the gas being provided via piping connections. The only safety-related portions of the system are the

containment penetration piping and valves, which are designed in

accordance with Safety Class 2, Seismic Category I requirements, and the nitrogen piping connecting to the safety injection accumulators, which are used for supply during normal operation and safety grade venting for cold shutdown capability. The supply lines to the accumulators are Safety Class 2, Seismic

Category I, from the containment isolation valves to the accumulators. There are redundant, normally closed valves on the supply line to each accumulator plus two redundant vent lines to the containment atmosphere with fail closed valves. These valves are normally closed to protect and maintain the pressure in the accumulators for emergency core cooling system injection. The valves are safety grade, Class lE, and environmentally qualified, as described in Section 3.11, to allow opening of the supply line and vent path for

depressurizing the accumulators prior to cold shutdown

operations. The piping and valve arrangement is such that all

three accumulators can be vented following any postulated single

failure.

All other portions of the nitrogen system are NNS class. Relief

valves are provided in the high and low pressure headers with

set pressure below the design pressure of the system.

9.5.9.4 Inspection and Testing Requirements

Pressure indication on the gas supply system and periodic checks of the gas available ensure adequacy and availability of these gases to the required systems. Pre-operational tests are

performed as described in Chapter 14.

BVPS-2 UFSAR Rev. 20 9.5-71 9.5.9.5 Instrumentation Requirements

Pressure regulating valves, pressure indicators, and relief

valves are provided locally for the nitrogen system.

Annunciation is provided in the main control room for low pressure in the high pressure nitrogen supply header and this

alarm is monitored by the BVPS-2 computer system.

9.5.10 Containment Vacuum System

The containment vacuum system establishes and maintains the reactor containment internal pressure during normal operations. The system is nonsafety-related, except for the suction lines inside containment, the piping and valves required for

containment isolation, and the piping related to the containment

atmosphere radiation monitor (Section 11.5).

9.5.10.1 Design Bases

The containment vacuum system is designed to perform the

following functions:

1. Reduction of the containment atmosphere pressure prior to plant start up (Mode 4 entry).

2. Removal of air from the containment atmosphere, which compensates for containment structure air inleakage

during normal operation.

3. Provide piping connections to the containment for the containment atmosphere radioactivity monitor and the combustible gas control system.

Portions of the containment vacuum system which are safety-related (piping, valves, and controls for inside containment suction, containment penetrations, and the radiation monitor) are designed to Safety Class 2 or 3 and Seismic Category I requirements. The balance of the system, which is designated

NNS class and located in Seismic Category I areas, is designed

to Seismic Category II requirements.

9.5.10.2 System Description

The containment vacuum system consists of a containment vacuum ejector, two containment vacuum pumps, a containment atmosphere radiation monitor (Section 12.3), piping, valves, and

instrumentation. The design parameters for the principal system

components are described in Table 9.5-6.

BVPS-2 UFSAR Rev. 16 9.5-72 The containment vacuum ejector removes air from the containment structure prior to initial plant operation and after subsequent refueling operations. Operation of the ejector continues until the desired containment operating pressure is reached, as indicated in the control room on the main board. The motive

medium for the ejector is 150 psig saturated steam, which is supplied at 5,700 lb/hr from the auxiliary steam system (Section

10.4.10). The containment vacuum ejector discharges directly to the atmosphere. No discharge radiation monitoring is required as air ejector containment isolation valves will be closed during power operation. The containment vacuum ejector will be

secured with administratively controlled, locked closed, manual valves prior to raising the reactor cooling system temperature

above 200 F. During normal operation the containment pressure is maintained by periodically operating one of the containment vacuum pumps, each of which has a capacity of approximately 45 SCFM. The

vacuum pumps are manually operated from the main control room by control switches with indicating lights from the main control

room. The common discharge of the two containment vacuum pumps is directed to the BVPS-1 gaseous waste disposal (GWD) system via the BVPS-2 GWD sweep gas subsystem discharge header. Redundant charcoal and high efficiency particulate air (HEPA) filters and GWD blowers vent to the atmosphere through the

process vent on top of the BVPS-1 cooling tower. Each

containment vacuum pump is capable of removing containment structure air inleakage during normal operation and of

maintaining containment atmosphere pressure in the operating

range (Section 6.2.1).

The suction piping inside the containment, and the containment penetration piping and isolation valves up to the second valve

outside containment, are also used as part of the post-accident combustible gas control system (Section 6.2.5). The design of the containment penetration piping and valves is described in Section 6.2.4. The containment atmosphere radiation monitor is

described in Section 11.5.

9.5.10.3 Safety Evaluation

The maximum and minimum containment atmosphere pressures achieved during plant operation varies as a function of service

water temperature and ambient air temperature in the containment structure. The containment vacuum pumps are operated, remote-

manually from the main control room, to maintain containment atmosphere pressure within the Technical Specifications, as set

by the post-accident containment analysis described in

Chapter 6.

Excessive depressurization of the containment structure by misoperation or failure of the containment vacuum system is not considered credible. The containment vacuum pumps have a

relatively small capacity when compared to the containment

structure free volume. Uninterrupted operation of a containment

vacuum pump for greater than 4 days would be required to lower

BVPS-2 UFSAR Rev. 16 9.5-73 the containment atmosphere pressure to the minimum design pressure of 8.0 psia, assuming no air temperature change. A low suction pressure signal will stop the pumps by 9.0 psia. Continuous containment pressure monitoring is available in the

main control room using pressure transmitters.

The air ejector is used for reducing the containment atmosphere pressure during start-up operations. Plant start-up is performed in accordance with detailed written procedures, which include operation of the steam ejector system. The establishment of containment pressure is governed by administrative procedures and is closely supervised by personnel

responsible for plant start-up.

This close supervision and monitoring assures that the normal operating pressure is not reduced below that permitted by the Technical Specifications (Chapter 16). In the unlikely event containment pressure is reduced below the value defined by the Technical Specifications, a low pressure alarm will annunciate

in the main control room, notifying the operator that the low pressure condition exists. Because of the slow rate of

depressurizing the containment, there will be sufficient time to

take corrective action (take the ejector out of service). When the normal containment operating pressure is reached, the steam

jet ejector will be secured with locked-closed manual valves under administrative control and will not be used during normal

plant operation.

The containment vacuum ejector is shut down when the containment

atmosphere pressure operating range is reached and a containment

vacuum pump is started. At this time, the inside containment isolation valve on the containment vacuum ejector suction line

and the outside containment isolation valve will be locked closed. Excessive depressurization during initial operating of the ejector and inadvertent ejector operation during normal plant operation would be possible only with a violation of

operation procedures, disregard of the low containment air atmosphere pressure alarm, and removal of the locking devices on

the ejector suction valves. In addition, a long period of inadvertent operation is required before any significant pressure reduction is seen. The discharge of the containment vacuum pumps is directed to BVPS-1, where redundant pumps and

filters are used such that no single failure of BVPS-1 equipment

will prevent the use of the BVPS-2 containment vacuum system.

9.5.10.4 Inspection and Testing Requirements

The containment vacuum ejector is not required during plant

operation. Because it is a passive mechanical device having no

moving parts, periodic testing of the ejector is not required.

The containment vacuum pumps are operated prior to fuel loading to demonstrate adequate capacity to remove inleakage. During normal plant operation, routine surveillance is performed to ensure operability of the pumps on the applicable start signal.

Testing of the containment penetration isolation valves is

discussed in Section 6.2.4. Pre-operational tests are performed

as described in Chapter 14.

BVPS-2 UFSAR Rev. 0 9.5-74 9.5.10.5 Instrumentation Requirements Control switches with indicating lights are provided in the main control room for the manual operation of the containment vacuum

pumps. These pumps stop automatically from a low suction pressure signal.

Control switches with indicating lights are provided in the main control room for the containment vacuum system isolation valves. These valves close automatically on a containment isolation

signal phase A (CIA). A control switch with indicating lights is provided in the main control room for the steam isolation valve to the containment vacuum ejector.

Indication is provided in the main control room for reactor containment pressure, reactor containment moisture, and reactor containment temperature.

A flow totalizer indicator is provided in the main control room for the containment vacuum pumps discharge flow. This indicator

is used in the containment structure leakage rate monitoring system. Annunciation is provided in the main control room for the containment vacuum pumps auto-stop, containment air pressure high/low, and containment air temperature high/low. These are

also monitored by the BVPS-2 computer system. Control switches with indicating lights are provided in the main control room for the reactor containment pressure isolation valves. A pressure recorder is provided in the main control room for the reactor containment pressure.

BVPS-2 UFSAR Tables for Section 9.5

BVPS-2 UFSAR Rev. 0 1 of 2 TABLE 9.5-1 EMERGENCY DIESEL GENERATOR FUEL OIL STORAGE AND TRANSFER SYSTEM COMPONENT DESIGN PARAMETERS Component Design Parameters Storage Tank Quantity Capacity (gal) 1 58,000 Day Tank Quantity Capacity (gal.) 1 1,100 Fuel Transfer Pumps Quantity Head (ft) Flow (gpm) 2 40 40 "Y" Type Strainers

Quantity Mesh Size 2 200 mesh per ASTM E437 0.0021 dia wire 0.0029 average opening plain square weave Engine-Mounted Fuel Oil Pumps Engine-Driven Quantity Per Engine Mark Numbers Capacity (gpm) System Pressure (psig)

1 2EGF*P23A,B Approximately 13.4

Approximately 30

BVPS-2 UFSAR Rev. 0 2 of 2 TABLE 9.5-1 (Cont) Component Design Parameters

Motor-Driven Quantity Per Engine Mark Numbers Capacity (gpm) System Pressure (psig) Motor Characteristics Source of Power

1 2EGF*P22A,B Approximately 13

Approximately 30 2 HP 125 V dc 2EGF*P22A, PNL*DC2-07

2EGF*P22B, PNL*DC2-06

BVPS-2 UFSAR Rev. 0 1 of 1 TABLE 9.5-2 EMERGENCY DIESEL GENERATOR FUEL OIL STORAGE AND TRANSFER SYSTEM MAJOR OIL DISTRIBUTORS WITHIN 40 MILES OF SITE

Supplier Distance from Site

 (mi)

Normal Supply on Hand (gal)

Tank Truck Capacity (gal) Time Required To Make Initial Delivery (hr) Ashland 8 200,000 to 2,000,000 8,000 to 9,200 (6,800 max

due to weight limit) 1 Texaco 18 945,000 (min) 7,300 1-1/4 Gulf 40 6,000,000 (min) 7,200 2 Universal 25 50,000 8,000 (7,300 max

due to weight limit) 8 to 10 Mobil 4 1,300,000 (min) 7,000 3/4

BVPS-2 UFSAR Rev. 14 1 of 2 TABLE 9.5-3 EMERGENCY DIESEL GENERATOR INTERCOOLER AND JACKET WATER COOLING SYSTEMS PRINCIPAL COMPONENTS AND DESIGN PARAMETERS Component Design Parameter Cooling water system capacity (gal) 600 Expansion tank capacity (gal) 100 Heat exchangers per engine: Jacket water heat exchanger Intercooler water heat exchanger 1 1 Cooling water system temperature: Maximum ( F) Minimum ( F) 170 95 Service water Minimum raw water flow required at 89 F water temperature to each engine (gpm) 625 Service water temperature rise at 625 gpm Jacket water ( F) Intercooler water ( F) Total rise ( F) 15.5 7.3 22.8 Intercooler water cooling system Engine-driven cooling water pump capacity (gpm) 950 Intercooler water heat exchanger Inlet temperature ( F) Outlet temperature( F) 112.6 103.0 Heat exchanger design capacity (Btu/hr) 4,545,000 Heat exchanger operating capacity (Btu/hr)* 3,359,000 Jacket water cooling system

Engine-driven cooling water pump capacity (gpm)

850 BVPS-2 UFSAR Rev. 14 2 of 2 TABLE 9.5-3 (Cont) Component Design Parameter Jacket water heat exchanger Inlet temperature ( F) Outlet temperature ( F) 152.7 135.0 Heat exchanger design capacity (Btu/hr) 7,365,000 Heat exchanger operating capacity* (Btu/hr) 6,518,000 Jacket water keep-warm system Keep-warm pump capacity (gpm) 50 Keep-warm electric heater capacity 30 kW, 460 V, 3 phase Keep-warm pump motor 1 1/2 hp, 60 Hz, 460 V, 3 phase Lube oil heat exchanger Flow (gpm) 400 Shell side Lube oil temperature in ( F) Lube oil temperature out ( F) 160.0 143.5 Tube side Jacket water temperature in ( F) Jacket water temperature in ( F) 135 138.5 Heat exchanger design capacity (Btu/hr) 1,395,000 Heat exchanger operating capacity* (Btu/hr) 1,268,000 Governor lube oil cooler Negligible NOTE: *With engine operating at rated load

BVPS-2 UFSAR Rev. 0 1 of 1 TABLE 9.5-4 REACTOR PLANT GAS SUPPLY SYSTEM PRINCIPAL COMPONENTS AND DESIGN PARAMETERS

Component Design Parameters Steam generator evacuation pump Capacity 150 scfm at 2.0 psia and 60 F Discharge temperature 80 F Motor 460 V, 3-phase, 60 Hz, totally enclosed, fan-

cooled

BVPS-2 UFSAR Rev. 20 1 of 1 TABLE 9.5-5 REACTOR PLANT GAS SUPPLY SYSTEM

SUMMARY

OF NITROGEN REQUIREMENTS Nitrogen Header Pressure Supplied to Supply Requirements (scf)

Requirement Basis Low Steam generator blanketing - dry layup 8,350 Placing one steam generator in dry

layup at 5 psig (does

not include

subsequent leakage) Low Auxiliary building hose connections - gas

waste system purge 600 One purge of gaseous system performed

approximatley once

each year. One purge

= 3 volumes (system volume = 200 ft) Low Primary drains transfer tank 120 Floating tank with nitrogen blanket at 1/2 full level to a

pressure of 15 psi Low Pressurizer relief tank 964 Purge and fill tank Low Volume control tank 780 Refueling operation Low Steam generator blowdown for chemical

mixing 1,344 Mixing of chemicals in one steam

generator wet layup Low Hydrogen analyers 100 Monthly purge for calibration High Safety injection accumulators 120,000 Initial charge of three accumulators

and any subsequent

charge 544 Makeup at low level alarm BVPS-2 UFSAR Rev. 16 1 of 1 TABLE 9.5-6 CONTAINMENT VACUUM SYSTEM PRINCIPAL COMPONENTS AND DESIGN PARAMETERS

Component Design Parameters Containment Vacuum Pumps Quantity

Capacity (each)

2 45 cfm Operating pressure

12.8 - 14.2 psia

Design pressure

Operating temperature

Design temperature 14.7 psia (maximum)

8.0 psia (maximum) 65 - 104 F 140 F Containment Vacuum Ejector Quantity

Capacity

1 15,000 cfm at 14.7 psia

Operating pressure (air

suction) 12.8 - 14.7 psia

Operating pressure (steam)

Design pressure

Operating temperature (air) Operating temperature (steam)

140 psig 150 psig 65 - 104 F 360 F BVPS-2 UFSAR Rev. 0 1 of 1 TABLE 9.5-7 EMERGENCY DIESEL GENERATOR COOLING WATER SYSTEM LEAKAGE

SUMMARY

PER DIESEL ENGINE*

Jacket Water System gph gal/7 days Piping and valves 0.02 3.36 Pump seals 0.06 10.08 Orifices, gasket (both sides) 0.00 0.00 Instrumentation 0.00 0.00 Turbocharger and piping 0.01 1.68 Subtotals 0.09 15.12

Intercooler Water System gph gal/7 days Piping and valves 0.03 5.04 Pump seal 0.06 10.08 Injectors and flow gauges 0.02 3.36 Instrumentation 0.00 0.00 Subtotals 0.11 18.48 Total Leakage 0.20 33.6

NOTE:

• Leakages provided by diesel engine manufacturer.

BVPS-2 UFSAR Rev. 0 1 of 1 TABLE 9.5-8 EMERGENCY DIESEL GENERATOR LUBE OIL SYSTEM PRINCIPAL COMPONENTS AND DESIGN PARAMETERS

Component Design Parameter Rocker Arm Lube Oil System Engine-Driven Pump Capacity

2.2 gpm at 20 psi Motor-Driven Pump Capacity (Approx.)

2-3 gpm at 20 psi Motor 1/2 hp, 3-phase, 60 Hz 460 V ac Class 1E Power

Keep-Warm and Pre-Lube System Motor Driven Pump

Capacity

50 gpm with built-in relief at 120 psi Motor 7 1/2 hp, 3-phase, 60 Hz 460 V ac Class 1E Power

Keep-Warm Heater 15 kW, 3-phase, 60 Hz 460 V ac Class 1E Power

Engine-Driven Lube Oil Pump Capacity

50-55 gpm with relief set at 110/115 psi

BVPS-2 UFSAR Rev. 0 1 of 1 TABLE 9.5-9 CRANKCASE VACUUM PUMPS DESIGN PARAMETERS

Component Design Parameters

Quantity 2 Capacity (each) 600 cfm @ 3" HO Motor 1 hp, 3 phase, 60 Hz, 460 volts, Class 1E power

Mark Numbers 2EDG*P21A&B

BVPS-2 UFSAR Rev. 20 1 of 2 TABLE 9.5-10 EMERGENCY DIESEL GENERATOR AIR STARTING SYSTEM PRINCIPAL COMPONENTS AND DESIGN PARAMETERS

Components Design Parameters

Air Compressors Quantity per diesel Start pressure (psig) Stop pressure (psig) Capacity, free air (cfm) Motor (hp)

Power 2 395 425 26.5 15 460 V, 3 phase, 60 Hz Class 1E power Air Tanks Quantity per diesel Design pressure (psig) Volume (each, ft) 2 450 74.2 Relief Valves Compressor discharge (psig) Air tank (psig)

450 450 Alarms High air temperature alarm ( F) 50 BVPS-2 UFSAR Rev. 0 2 of 2 TABLE 9.5-10 (Cont) Components Design Parameters

Dryers Quantity per diesel Dew point temperature Capacity, free air (cfm)

1 40 F 50 Aftercooler Quantity per diesel Capacity, free air (cfm) 1 Later Filters Aftercooler discharge, particulate Aftercooler discharge, coalescing Dryer discharge, particulate

3 micron .7 micron .3 micron

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tf,{C)z c@ ;n { -Tl Tm :!m T\OD T1 -)F? ffim -l Y-rm :"n m +m;U ,-m T #cf 11 z I r'l-n; Df; f -o t-r l- 2 ..-'- G- H ul i; oq ,!, Il -q A; -u N 9?T - T3o 5 o il=:) 'iom^cD D -{Z; =E 3= = z-62 'n u)6- g T=m-{ (, m T(r7 az I -\=P D rv;fiF3*l:D-12 Z nAb_l t -Tl-i;N Cl 'iJ O;U(^3a rn n O m r C Ct m fv r\)rr) --r-J C)AN)-B (,..b ...A cDT=f3-..F r =t=o==-;ilr=i s?2-a=:Jz > rn (./) t'm C); '{CO tO AA O N)N)O@L^J rJ)0{n N)-t{rO o.l-J (o (,-l (o (Jl:tr(3 Q r-r N)-r(/tfl o)(O-fnU1'(T)- Ir urff;o-c)l;i> r*-rfi61CF bf' 'x, r- Ul (/)cl or rQ tt1 Cf _r:tr-E T-{.-\mE'nmc-F-J-nFrn ozo>wH f:lxO-{-. l-';Ol-V-2.'rl u)m ztr" r C) '*:f, N 0n -{rn c)t-a-t]J\)6)c)LN T1 rrl 6)n (f a td ff of n m cl a rn;o f);\a n m s N)rv-rl rE rrl tll-l-oc o ruK ru-u>(-\--(n ><lt0 -B '-, r;pr{ .-. r-.l\7 txr-Ur Fr) pr1 uf]ptt I' rn Lnm ru -( C)r-r(/}*={}" frm{l =m T(n;o N)t, (p v1=3.'- t- .-.. r-ql fl#7-t-.t r.-'r t- f a7i'r=lrt ;D ,...*u] -l l.\) N)tt ul r$Nu f\) (}o\(o qE{cf N) f-\)t^)b-+ZC cf:E ED flr-Cf,Z 7m tf ,-a I-{C r-. EE cfm z mcf;U '-'r a 3:CI prn* (t1 7m A;D r no p r*r mro N)N)(.rl N)(, bJ Rt {#'-'3c;T>n A--rt-@ZzZ*^r,-, cl z, j (/) ulmCJ s?il*+>>r is=o It 3>r^dd (,os.-u t ,t\3f;;;<n JN)lv.\O{@N)o-{n N)(,tl-rDtl.{m Tz=DT DO:nTl r- fn'z r-+2 3AC) -. (-Ha w )J m!bP Pb P.b f'\)()a rOto-bN)r$ (, AO co: ul co (rq\o lJl I l.J ir.q3;l\)E b p 5 TO DISCHARGE NOZZLES IN AUXILIARY BUILDING CABLE TUNNEL AND FAN ROOM ZONE 1 TO DUCT DAMPERS AND AIR OPERATED VALVES 203 PRESSURE REGULATING VALVE REFRIGERATION SYSTEM F ILL ------1 CONNECTION REFRIGERATION SYSTEM 205B FILL CONNECTION CARBON DIOXIDE RESERVE STORAGE UNIT 638B CARBON DIOXIDE STORAGE UN IT 221 211 TO DISCHARGE NOZZLES IN CABLE TUNNEL. ZONE 1 TO DISCHARGE NOZZLES IN CONTROL BUILDING CABLE SPREADING ROOM AND INSTRUMENT AND RELAY ROOM. ZONE 1 TO DUCT DAMPERS TO DISCHARGE NOZZLES AND DUCT DAMPERS IN CABLE VAULT RELAY ROOM, ZONE 7 TO DUCT DAMPERS TO DISCHARGE NOZZLES IN CABLE VAULT AND ROD CONTROL AREA. ZONE 3 TO DUCT DAMPERS TO DISCHARGE NOZZLES IN CABLE VAULT BUILDING CABLE VAULT AREA, ZONE 3 TO DISCHARGE NOZZLES IN SERVICE BUILDING CABLE TRAY AREA. ZONE 4 TO DUCT DAMPERS TO DISCHARGE NOZZLES AND DUCT DAMPERS IN CABLE VAULT CABLE TUNNEL, ZONE 2 TO DISCHARGE NOZZLES AND DUCT DAMPERS IN WEST CABLE VAULT, ZONE 2 TO DUCT DAMPERS TO DISCHARGE NOZZLES IN EAST CABLE VAULT, ZONE 2A TO DISCHARGE NOZZLES IN EMERGENCY DIESEL GENERATOR (EDGl ROOM 2-1 , ZONE 5 TO DISCHARGE NOZZLES IN EMERGENCY DIESEL GENERATOR (EDGl ROOM 2-2. ZONE 6 FILL -----i CONNECTION 441 TO DISCHARGE NOZZLE FOR GENERATOR EXCITER ENCLOSURE TO DISCHARGE NOZZLE FOR BEARING ENCLOSURE BETWEEN LOW PRESSURE TURBINE AND GENERATOR TO DISCHARGE NOZZLE FOR BEARING ENCLOSURE BETWEEN LOW PRESSURE TURBINES TO DISCHARGE NOZZLE LOCATED BELOW OPERATING FLOOR IN HIGH PRESSURE TURBINE ENCLOSURE 1 2 205 TO HOSE REELS TO MAIN GENERATOR PURGE ALL VALVE AND EQUIPMENT IDENTIFICATION NUMBERS ON THIS FIGURE ARE PRECEDED BY THE SYSTEM DESIGNATOR "2FPD" UNLESS OTHERWISE INDICATED. FIGURE 9.5-5 C02-FIRE PROTECTION SYSTEM

REFERENCE:

STATION DRAWINGS OM 33-2A AND 28 BEAVER VALLEY POWER STATION UNIT NO. 2 UPDATED FINAL SAFETY ANALYSIS REPORT 2 RESERVE EXTENDED DISCHARGE NOZZLE MAIN MAIN INITIAL DISCHARGE NOZZLES TO DUCT DAMPERS RESERVE RESERVE EXTENDED DISCHARGE NOZZLES MAIN MAIN INITIAL DISCHARGE NOZZLES RESERVE COMPUTER ROOM HALON PROTECTION SYSTEM CONTROL BUILDING C EL 735'6" J REV. 1 2 ALL VALVE AND EQUIPMENT IDENTIFICATION NUMBERS ON THIS FIGURE ARE PRECEDED BY THE SYSTEM DESIGNATOR "ZFPG" UNLESS OTHERWISE INDICATED. WEST COMMUNICATIONS ROOM HALON PROTECTION SYSTEM CONTROL BUILDING ( EL 707'6" l FIGURE 9.5-6A HALON FIRE PROTECTION SYSTEM

REFERENCE:

STATION DRAWING OM 33-3 BEAVER VALLEY POWER STATION UNIT NO. 2 UPDATED FINAL SAFETY ANALYSIS REPORT Clmn.a fJzNn:9 H\rr\ z.Zm lrJ L,J\)o'()-n(JTr_cf-l r- T -rl{rNlll Frl a:o><>--rt -{ (n cfoc,;o Tl'-p g1 zr-(-n rfl-<c)r r {rn*o>znqJ (f rn rnT;o iDC /r,4< /r, l-al lJ F rrl a a C F N r"l (7 O;o: z I rn o rrl n-fl c rn r.It c-u C}ft-{(f n z J.rn O rrl:D'rl n O=t^) -O al-<cr r<o--UI za Cla rn -r1 z f,}OL (n:om (-)cn -{c]r I I I I I t I I I I l-t ,-roz tE C-l-H l-{l(f {f lI-tZC l(f<'m!l;o (/, Itn lz lEl l-'z tL I rrl at l-r rCJ In l(^Q=cJ t't m*Ztt-ra-r--ufnny \=li-.?-<D-1 Drr X Zrm xmcn rm_r.]-rr1-\I cil C), rn ct Z r-*.rn rn n(n> rrl-{ f-t=z f,)f\)I rn z f,)z rn l-tr tc ts lse I N$s tNc IN INE tNt IN;lN+lNs I I l 1., rc, i*{rr!,f;t\)/1l n rrl tt/1 a E 3 r!rn cf c7;o 7;C-rn a)--{-l t3 C):-i C];D: z tl='tt T 11{*<z-u qf-pl il a;1)D ()c)c C r{o A,)ta c"lJ T r rl-rn Cf, rfl E rn-{n A o OFN ,-, C) ?rmfi-GA.-{n+i-I O D'Z ,4. :U + ii NDO<'An-rr ts-{Crn DmLO Z-n xr T m.<N m z{rn z-t cf, m n T-l r C){cf m n-rl Cf{CI;0:-l C],U I>z c)1l Cf* frl tc to q d 0 o o z C-rn c)-l o n{: D n (^)3-{o F a-t?t--rn O rn E z w A N)o)rv no-r1 Hl- I r-T{{r\)Frl fO -;UX@( Trcl j I CDZrr>I rn-C)(rl , i(-@lr.lz I TZrl'tG t<'-It I t I I'r -{ rn ooc n1,*"!6\Zl-L r-) rrl-<(^)r r--lm-CJF z]IJa q]m m-un:uC tr.=ll (n C, f,l:-{Cf AJ z rfi ,*l m;o-n=, tf ,r)l<r-l7 v rr ta I I I I I i\\----T'l -QZ;CIL m o)O-{OO g?z.c O<rnT;Dl'n VI z z C.rn C)-{c)4 U', I t I FzI 2 cl r-n a T A (, a D.L A u)N c-)c)z r-l= 5 D ll.lDz UC]-rz 5 z a v-s tu c)c)z z m c-)O z-rl N.J tf a-{n r-AJ r.O v1{n A--r{tl D z 1'l mc rm-Dt'rl t- N n-r c]>T-Er t, ta fl Za1 (n C'_T1 rq um rl\)toi l)-T a c-{mD z-xr rrn(-)r mm (, rn -u -u az -{=,-t v\. , F-l=22=frn-uu'!e=g 6-g=m26'2at6 cf i.FB =p-{ -m m=- 1-t v t-l c@z>z<.cr r 3r frt -t cp a-.m<(nmlD uD t-O(,-{-<6lrl TAzrn-{ D nm 1Z{3;go 6,-,,6 m:Hre z=c) T cfYc?Fi d2 rCf^.-rq tu fi ,_, Y 'mcl-Nm mnz CT]UT-nm=.lF\ rl i'i =oat Itl-{Cf '-.cf z c@ lu C)m rl Tm m Hz OD T1 I_= C)DnB il a,d =UZImrrl f P rn P6 p 3-- a 5- ?r-l ; mu !R: = Dfi1= 9 za mfr z- um=T cf l-<'n RCD D ]CG)5= { Dm F3 r,-; - (rm aa \r' Tn 2zgmt a c s' n-r nZ (, cl m-{ o, An-ol. z u)Tl 3P ilF N 3--0:D -n<F zl c)^))v\7P\)rc Nr T1 e z.mr-r1 ZT(n c)>rn r-z.a rn;u o r z n z!c-CM gc)-t -l cf;0-l\J c) .r omffi-Ztl rra Jo#ry Cq+fr ii-?*tD -1 Drr Ii zcm 7\mc, rm OFN'-t c) :z rgfr-,fid rH12 NDoY 6Rn -IX-{c m Dm('Z- tl i\ t-e, 6 o O-l m 0 0 o-l=m g 0 o g o cf m a cl z I 6-n r m o I a 1l m (-)T1 c')D-t (f, z th 6 0e\o ttl 8-J ir q3 N)\o t-)E\o v i-, FROM DEMINERAL !ZED WATER JACKET WATER EXPANSION TANK ENGINE DRIVEN JACKET WATER PUMP P22A 23 ELECTRIC KEEP WARM HEATER E23A JACKET WATER KEEP WARM PUMP P23A GENERATOR BEARING COOLER GOVERNOR OIL COOLER FROM SERVICE WATER (SWl INTERCOOLER HEAT EXCHANGER E21A ENGINE DRIVEN INTER COOLER P21 A PUMP TURBOCHARGER COOLER CYLINDER CODLING CYLINDER COOLING TURBOCHARGER COOLER LUBE OIL HEAT EXCHANGER 2EGO-E21A FROM/TO [NTAKE AIR FOLD REV. 1 !5 JACKET WATER HEAT EXCHANGER FROM/TO INTAKE AIR MAINFOLO ALL VALVE AND EQUIPMENT IDENTIFICATION NUMBERS ON THIS FIGURE ARE PRECEDED BY THE SYSTEM DESIGNATOR

• 2EGS" UNLESS OTHERWISE INDICATED.

FIGURE 9.5-8 EMERGENCY DIESEL GENERATOR COOLING WATER SYSTEM

REFERENCE:

STATION DRAWING OM 36-4A BEAVER VALLEY POWER STATION UNIT NO. 2 UPDATED FINAL SAFETY ANALYSIS REPORT FROM OEM!NERALIZEO WATER JACKET WATER EXPANSION TANK ENGINE DRIVEN JACKET WATER PUMP P22B 24 ELECTRIC KEEP WARM HEATER E23B JACKET WATER KEEP WARM PUMP P238 GENERATOR BEARING COOLER GOVERNOR OIL COOLER FROM SERVICE WATER (SWl INTERCOOLER HEAT EXCHANGER ENGINE DRIVEN INTER COOLER P21 8 PUMP TURBOCHARGER COOLER CYLINDER COOLING CYLINDER CODLING TURBOCHARGER COOLER LUBE OIL HEAT EXCHANGER 2EGO-E21B FROM/TO INTAKE A!R FOLD REV. 15 JACKET WATER HEAT EXCHANGER FROM/TO INTAKE AIR MAINFOLD ALL VALVE AND EQUIPMENT lDENT!F!CAT!ON NUMBERS ON THIS FIGURE ARE PRECEDED BY THE SYSTEM DESIGNATOR

• zEGS* UNLESS OTHERWISE INDICATED.

FIGURE 9.5-9 EMERGENCY DIESEL GENERATOR COOLING WATER SYSTEM

REFERENCE:

STATION DRAWING OM 36-48 BEAVER VALLEY POWER STATION UNIT NO. 2 UPDATED FINAL SAFETY ANALYSIS REPORT TO LEFT BANK MAIN AIR START VALVE, AIR DISTRIBUTOR AND CYLINDERS TO AIR SOURCE SELECTOR AND LEFT BANK MAIN AIR START VALVE 202-1 VENT TO LEFT BANK MAIN AIR START VALVE. AIR DISTRIBUTOR AND CYLINDERS TO AIR SOURCE, SELECTOR AND LEFT BANK MAIN AIR START VALVE MECHANICAL LINKAGE (TYP. BARRING DEVICE INTERLOCK FROM LUBE 0 I L'r----1.,..._---' RIGHT BANK AIR DISTRIBUTOR <TYPICAL OF 2> MECHANICAL LINKAGE (TYP. FROM LUBE BARRING DEVICE INTERLOCK SOURCE MAfN AIRj START VALVE, TARTI NG OURCE STARTING AIR TANK TK22A MAIN AIR START VALVE I ACR TANK TK21A STR1 LUBE OIL FROM OVER SPEED GOVERNOR AND SHUTDOWN CYLINDER REV. 12 FROM STARTING AIR HEADERS STR2 TO FUEL R A C K ,.__-t---t SERVO. FUEL RACK SHUTDOWN CYLINDER LUBE OIL FROM OVER SPEED GOVERNOR AND SHUTDOWN CYLINDER FROM STARTING AIR HEADERS TO FUEL RACK SERVO. FUEL RACK SHUTDOWN CYLINDER 148 AIR TANK VENT VENT ALL VALVE AND EQUIPMENT IDENTIFICATION NUMBERS ON THIS FIGURE ARE PRECEDED BY THE SYSTEM DESIGNATOR u2EGAu UNLESS OTHERWISE INDICATED. FIGURE 9.5-10 L--....,_- __ ___, EMERGENCY 0 I ESEL GENERATOR AIR START SYSTEM

REFERENCE:

STATION DRAWING OM 36-3 BEAVER VALLEY POWER STATION UNIT NO. 2 UPDATED FINAL SAFETY ANALYSIS REPORT ROCKER ARM L.O. SUPPLY HEADER 't f' + + .. ROCKER ARM L.Q. RETURN HEADER ROCKER ARM L.a. RETURN HEADER ROCKER ARM L.Q. SUPPLY HEADER FROM JACKET WATER COOLING E21A LUBE OIL HEAT XCHANGE FILL CONN. P21A TO JACKET MAIN LUBE WATER COOLING OIL PUMP ENGINE DRIVEN LEGEND L.a. LUBE OIL WTR WATER P23A MOTOR DRIVEN ROCKER ARM PRE-LUBE PUMP REV. 12 ROCKER ARM L.O. SUPPLY HEADER t ' + + t + ROCKER ARM L.O. RETURN HEADER ROCKER ARM L.Q. RETURN HEADER ROCKER ARM L.O. SUPPLY HEADER FROM JACKET WATER COOLING E21B LUBE OIL HEAT X CHANGE FfLL CONN. P21B TO JACKET MAIN LUBE WATER COOLING OIL PUMP ENGINE DRIVEN P23B MOTOR DRIVEN ROCKER ARM PRE-LUBE PUMP ALL VALVE AND EQUIPMENT IDENTIFICATION NUMBERS ON THIS FIGURE ARE PRECEDED BY THE SYSTEM "2EGOu UNLESS OTHERWISE INDICATED. F I GURE 9. 5-11 EMERGENCY DIESEL GENERATOR LUBRICATION SYSTEM

REFERENCE:

STATION DRAWINGS OM 36-5A AND B BEAVER VALLEY POWER STATION UNIT NO. 2 UPDATED FINAL SAFETY ANALYSIS REPORT SIL1A AIR INTAKE FILTER FLTA-1A INTAKE SILENCERS TO EMERGENCY DIESEL GENERATOR(EQG) 2EGS-EG2-1 RIGHT BANK TURBOCHARGER BLOWER SUCTION EMERGENCY DIESEL GENERATOR ENGINE TO EDG 2EGS-EG2-1 LEFT BANK TURBOCHARGER BLOWER SUCTION TO ATMOSPHERE EXHAUST SILENCER FROM FROM EDG 2EGS-EG2-1 RIGHT BANK TURBOCHARGER TURBINE EXHAUST EDG 2EGS-EG2-1 LEFT BANK TURBOCHARGER TURBINE EXHAUST TO ATMOSPHERE SIL28 AIR INTAKE FILTER FLTA-18 INTAKE SILENCERS TO EDG 2EGS-EG2-2 LEFT BANK TURBOCHARGER BLOWER SUCTION TO EMERGENCY DIESEL GENERATOR(EDGJ 2EGS-EG2-2 RIGHT BANK TURBOCHARGER BLOWER SUCTION EMERGENCY DIESEL GENERATOR ENGINE TO ATMOSPHERE EXHAUST REV. 12 SILENCER FROM FROM EDG 2EGS-EG2-2 RIGHT BANK TURBOCHARGER TURBINE EXHAUST OIL SEPARATOR SP21B EDG 2EGS-EG2-2 LEFT BANK TURBOCHARGER TURBINE EXHAUST TO ATMOSPHERE ALL VALVE AND EQUIPMENT IDENTIFICATION NUMBERS ON THIS FIGURE ARE PRECEDED BY THE SYSTEM DESIGNATOR "2EDGu UNLESS OTHERWISE INDICATED. FIGURE 9.5-12 EMERGENCY DIESEL GENERATOR COMBUSTION AIR INTAKE. EXHAUST AND VACUUM SYSTEM

REFERENCE:

STATION DRAWING OM 36-2 BEAVER VALLEY POWER STATION UNIT N0.2 UPDATED FINAL SAFETY ANALYSIS REPORT BVPS-2 UFSAR Rev. 0 9.5A-i APPENDIX 9.5A FIRE PROTECTION EVALUATION REPORT FSAR Amendment 14 incorporated the Fire Protection Evaluation Report (FPER) into the FSAR as Appendix 9.5A. This Appendix replaced the FPER through FPER Amendment 2 which had been

provided to the NRC in a separate submittal. The updated version of the FPER provided in Appendix 9.5A includes the previous version of the FPER through FPER Amendment 2 and the

revisions that would have been provided in FPER Amendment 3.

BVPS-2 UFSAR Rev. 8 9.5A-iii APPENDIX 9.5A FIRE PROTECTION EVALUATION REPORT TABLE OF CONTENTS 9.5A.1 Fire Hazards Analysis 9.5A-1 9.5A.1.1 Methodology 9.5A-1 9.5A.1.2 Safe Plant Shutdown 9.5A-2 9.5A.1.2.1 Safe Shutdown Evaluation 9.5A-2 9.5A.1.2.2 Safe Shutdown Summary 9.5A-9 9.5A.1.2.3 System Description and Identification 9.5A-10

9.5A.1.2.4 Alternate Shutdown Panel 9.5A-17 9.5A.1.3 Fire Hazards Analysis by Fire Area 9.5A-20 9.5A.2 Deviations from Branch Technical Position CMEB 9.5-1 9.5A-118 9.5A.3 References for Section 9.5A 9.5A-165 BVPS-2 UFSAR Rev. 12 9.5A-v APPENDIX 9.5A LIST OF TABLES 9.5A-1 Deleted

9.5A-2 Fire Doors with Security Modifications

9.5A-3 Areas Containing Safety-Related Piping Required for Safe Shutdown which Do Not Contain or Present a Fire Hazard (Fire Detection Not Provided)

BVPS-2 UFSAR Rev. 12 9.5A-1 APPENDIX 9.5A 9.5A.1 Fire Hazards Analysis

9.5A.1.1 Methodology The following describes the general approach, assumptions, and methods utilized in performing the fire hazards analysis as recommended by Branch Technical Position (BTP) - CMEB 9.5-1.

1. The plant was divided into fire areas and subfire area zones.

2. A detailed fire hazard analysis as required by BTP CMEB 9.5-1 was performed in all fire areas and fire zones that housed safety-related equipment powered

from the station emergency buses, contained Class 1E circuits, or contained the potential of significant radioactive release. Fire areas and zones that housed nonsafety-related equipment were also similarly evaluated and addressed. These area evaluations assessed the possible propagation of a fire into vital areas.

3. The fire analysis, unless otherwise stated, assumed the total combustion of all combustibles within the

area. This basis has been used for the evaluation of

all fire barriers.

4. Combustibles were identified and fire severities were developed for each fire area. In developing the fire severities the following assumptions and methods were

used: a. The calorific heat values of materials as presented in the National Fire Protection

Association (NFPA) Handbook or NFPA Codes are used. Manufacturer-supplied data for cables was used to calculate the weight of combustible cable

materials.

b. Cable fire loading for a given fire area or zone was obtained by use of a computer program. The program calculated the total cable combustible load in Btu's based on data supplied by cable manufacturers. Cables run in conduits are not considered to contribute to the combustible loading. The cable combustible loadings were based on the scheduled total amount of cables per cable tray. A safety factor of 20 percent was added to account for any future cables.

BVPS-2 UFSAR Rev. 0 9.5A-2 c. Pipe insulation was not included in the fire loading since the materials utilized have little fuel contribution.

d. Insulation associated with metal siding structures was not included in the fire loading due to its construction. All insulated metal siding and liner panels are made of 22 gauge or thicker sheet steel, with the insulation enclosed between the liner panel and exterior metal siding.

e. Where liquid combustibles were present and the possibility of localized concentrated fires also existed, an additional calculation using a surface burning rate was performed.

5. The results of the fire loading (Btu/sq ft) were compared with the equivalency presented in the NFPA Handbook (14th edition), Section 6, to determine fire severity and if adequate barriers exist. Equivalency under the standard time-temperature curve provided in the same section of the above-referenced NFPA Handbook

was assumed.

9.5A.1.2 Safe Plant Shutdown

9.5A.1.2.1 Safe Shutdown Evaluation

9.5A.1.2.1.1 Introduction BTP CMEB 9.5-1 states that fire protection features should be provided for structures, systems, and components necessary for

cold shutdown. Cold shutdown is defined as the reactor being subcritical and reactor coolant system (RCS) as having temperatures less than 200 F. To ensure that cold shutdown capability exists, it is necessary to protect from damage at least one of each redundant components required to achieve the shutdown function. Redundant components are defined as duplicate

equipment or systems which perform the same shutdown function. There are several acceptable ways to accomplish the required fire protection according to Sections C.5.b and C.5.c of BTP CMEB 9.5-1:

1. The preferred approach is to separate redundant components by 3-hour fire resistance-rated barriers.

This can be accomplished by either constructing a 3-hour fire barrier between redundant equipment and/or cables (protection in place) or by rerouting the redundant cabling and relocating equipment outside of the existing fire area.

2. Another means of providing fire protection for redundant components/cables is to utilize a horizontal distance of 20 feet or more with no intervening

combustibles. This approach

BVPS-2 UFSAR Rev. 8 9.5A-3 to protection also requires the use of automatic fire detection and suppression.

3. Enclosing redundant cabling and equipment in a l-hour fire-rated barrier is also an acceptable means of protection. This also requires automatic fire detection and suppression.

4. Another option is to provide alternative or dedicated shutdown capability. Refer to Section 9.5A.1.2.4 for additional information on alternate shutdown capability.

The Beaver Valley Power Station - Unit 2 (BVPS-2) fire protection evaluation has utilized the above methods in achieving compliance with BTP CMEB 9.5-1 to ensure that a loss of any designated fire area of BVPS-2 due to fire would not affect the ability to attain cold shutdown. Where differences exist, deviations have been documented to justify existing

configuration. (Refer to Section 9.5A.2.) Shutdown is to be accomplished within 72 hours and assumes a loss of offsite power (LOOP) for this period. In addition, no concurrent accident or single failure is assumed in this study.

9.5A.1.2.1.2 Assumptions An exposure fire in a designated fire area, bounded by 3-hour fire resistance-rated barriers, which renders all unprotected electrical equipment and cabling in the area inoperable, does not adversely affect the capability of BVPS-2 to achieve and maintain cold shutdown conditions based on the following assumptions.

Assumptions and Conditions:

1. The unit is operating at full power when the postulated fire occurs.

2. The unit must achieve and maintain cold shutdown conditions within 72 hours.

3. A LOOP condition exists at the time of the fire and continues for 72 hours after ignition of the fire, unless it can be demonstrated by analysis that a LOOP induced event does not occur for a fire in a

particular fire area.

4. All equipment and power sources necessary to accomplish shutdown must be onsite.

5. No equipment failures outside of the affected fire area will occur unless directly caused by the effects of the fire itself.

6. Any equipment needed for system repair or operation necessary to achieve cold shutdown conditions within

72 hours must be onsite. BVPS-2 UFSAR Rev. 14 9.5A-4 7. No additional event or incident will occur simultaneously with the fire, except LOOP. 8. If manual actions are required these actions must be performed by onsite personnel within the necessary time interval without adversely affecting safe

shutdown. 9. Equipment required for safe shutdown will be available and not out of service for maintenance or repair at

the time of the fire.

9.5A.1.2.1.3 Alternative Shutdown Approach

Alternate shutdown capability is provided independent of specific fire areas because redundant systems in these areas do not meet the separation criteria for safe shutdown capability as defined in Section C.5.b of BTP CMEB 9.5-1. In these areas, it is not possible to provide total protection against the adverse effects of an equipment disabling exposure fire since redundant divisions are located in close proximity to each other and

sufficient space for inplace protection does not exist.

BVPS-2 uses the alternative shutdown capability approach in the event of an exposure fire in the following fire areas of the

main control building and the cable tunnel. These fire areas

are identified as follows:

CB-1 El 707 ft-6 in Instrumentation and relay room CB-2 El 725 ft-6 in Cable spreading room CB-3 El 735 ft-6 in Main control room CB-6 El 707 ft-6 in West communication room (Emergency shutdown panel (ESP) station) CT- 1 El 712 ft-6 in Cable tunnel

CB-3 is actually one fire area consisting of both the BVPS-1

Control Room (CR-1) and the BVPS-2 Control Room (CB-3).

(CB-1, CB-2, and CT-1 are actually one fire area but for

analysis purposes are described as three different sub-areas.)

An exposure fire in any of these five areas would require the control function to be shifted from the main control room to the

alternate shutdown panel (ASP), located in its own room at el

755 ft-6 in of the auxiliary building/cable tunnel. A detailed discussion of the alternative shutdown capability is presented

in Section 9.5A.1.2.4.

Key components were identified for utilization from the Alternate Shutdown Panel. Risk-significant components associated with fire events were identified as part of the fire PRA modeling efforts of BVPS Unit 2. Provisions of the Maintenance Rule (10 CFR 50.65) will ensure that the risk-significant components are maintained in a high state of availability.

In addition, the ASP is relied upon for transfer of controls for the No. 1 EDG for a fire in SB-3 to isolate voltage regulator

and tachometer circuits routed in SB-3, and in SB-4 for monitoring of certain instrumentation and ventilation control

for the No. 1 EDG Room.

BVPS-2 UFSAR Rev. 14 9.5A-5 9.5A.1.2.1.4 Associated Circuit Analyses - General The associated circuit analyses were developed by reviewing the equipment and cabling of BVPS-2 for compliance with the definition of associated cables in Section C.5.c to BTP CMEB 9.5-1. The associated circuits in a fire area are defined as safety-related and nonsafety-related cables required for safe shutdown, which have a separation from their alternative shutdown

equipment, or cables that are less than that required by Section C.5.c to BTP CMEB 9.5-1, and that have one of the following:

1. A common power source with shutdown equipment (redundant or alternative) in which the power source is not electrically protected from post-fire shutdown circuitry by coordinated circuit breakers, fuses, or similar devices.

2. A connection to circuits of equipment whose spurious operation will adversely affect the shutdown

capability (for example, residual heat removal

isolation valves, reactor coolant system isolation valves, or steam generator atmospheric dump valves).

3. A common enclosure (for example, the raceway, panel, or junction box) with shutdown cables (redundant and alternative) that is not electrically protected from the post-fire shutdown circuits of concern by circuit breakers, fuses, and similar devices.

9.5A.1.2.1.5 Common Power Source with the Alternative or Redundant Shutdown Equipment

Fire areas CB-1, CB-2, CB-3, CB-6, and CT-1 are in accordance with Section C.5.c to BTP CMEB 9.5-1, and utilize the alternative shutdown approach as described in Section

9.5A.1.2.4. Other considerations are:

1. A coincident LOOP was assumed and shutdown would be ensured by using the standby power sources; that is, the emergency and standby diesel generators.

2. A review of the power sources that are common to alternative and redundant shutdown equipment showed that 4,160 V ac, 480 V ac, 120 V ac vital bus, and 125 V dc power circuits all have circuit breakers. Coordination studies have been performed to prove positive coordination of all 4,160 V ac and 480 V ac

motor control centers (MCC) and their protective relaying. A coordination study has been performed for all molded case breakers and fuses (480 V ac, 125 V dc, and 120 V ac voltage levels). Necessary fault current for sufficient time to ensure the proper coordination without loss of shutdown load function

has been reviewed. Coordination studies were performed to demonstrate proper coordination between downstream and upstream buses in order to isolate all

types of faults.

BVPS-2 UFSAR Rev. 14 9.5A-6 In addition, the control circuitry for the 4,160 V ac switchgear and 480 V ac MCCs is protected by circuit breakers. Therefore, the integrity of these power supplies (buses), which are required to support the

operation of alternative and redundant shutdown equipment, is preserved and the circuits connected to them are not considered associated. All interrupting devices (power-operated switchgear, molded case circuit breakers, and fuses) are designed in accordance with applicable Underwriter Laboratories Incorporated, American National Standards Institute), or National Electrical Manufacturers Association

standards.

3. All individual circuits, including external field contacts, that are supplied on the Westinghouse Nuclear Steam Supply System process racks have in-line fuses that adequately protect each circuit and isolate the faulted downstream system. In addition, the main control room annunciator and BVPS-2 computer system have isolating devices.

Typical equipment used for isolating purposes includes voltage regulating isolation type transformers, relays, and circuit breakers tripped on an accident signal, as well as the use of double protective devices to provide an equivalent level of protection.

Therefore, the above protection removes these circuits from being considered associated.

4. 480/120 V ac Control Power Transformers (CPT) provided in the 480 V ac MCCs are of the encapsulated type.

For Class 1E MCCs, the CPT 120 V secondary circuit is

protected by a fuse. For non-Class 1E MCCs, the CPT 120 V secondary circuit is protected either by a fuse or the fault current is limited by CPT design so as

not to cause control cable ignition due to a fault.

9.5A.1.2.1.6 Connection to Control Circuits/Spurious Operation

With the exception of fire areas CB-1, CB-2, CB-3, CB-6, and CT-1, all cables and equipment in BVPS-2 that are used for safe shutdown have been properly protected or separated in accordance with Section C.5.c of BTP CMEB 9.5-1. The ASP for the above five fire areas, as described in Section 9.5A.1.2.4, provides

for an alternate means of shutdown. For each fire area, spurious operations were evaluated under the

following assumptions:

a. The safe shutdown capability should not be adversely affected by any one spurious actuation or signal resulting from a fire in any plant area.

b. The safe shutdown capability should not be adversely affected by a fire in any plant area which results in the loss of all automatic functions from the circuits located in the area in conjunction with one worst case spurious actuation or signal from the fire.

BVPS-2 UFSAR Rev. 14 9.5A-7 c. The safe shutdown capability should not be adversely affected by a fire in any plant area which results in

spurious actuation of the redundant valves in any one

high-low pressure interface line.

Opens, grounds, or hot shorts on the ammeter circuits in the

control room (fire area CB-3) associated with the 4,160 V ac switchgear breakers were analyzed and found not to cause spurious operation of these associated breakers for the necessary shutdown orange and purple train circuits since double protective devices are provided. Current transformer secondary signals (0-5 amperes) are reduced to very low output

signals (0-lma) from the transducers to the ammeters. Several redundant instrument circuits are susceptible to damage by fire. Therefore, alternative means for the basic instrument requirements are discussed in Section 9.5A.1.2.4 which provides for an alternate power supply and cabling for critical instrumentation, thereby allowing the operators to be fully informed on specific process functions in order to complete a cold shutdown.

Manual operator action is available from unaffected control stations and local manual valve operation is available to

provide control of necessary shutdown equipment. With the protection described in Section 9.5A.1.3 for the individual fire area that complies with Sections C.5.b and C.5.c of BTP CMEB 9.5-1, this report demonstrates that effective physical separation, protection, manual valve operation, repairs for safe shutdown equipment, or alternate means are provided to ensure

shutdown with no adverse effects from spurious signals. 9.5A.1.2.1.7 Associated Cables for Common Enclosures

A review of common enclosures (for example, raceways, panels, and junction boxes) with the shutdown cables (redundant and

alternative) was performed. Circuits for common enclosures with potential association are limited to switchgear and unit substations, MCC compartments, control and distribution panels

or boards, and relay panels or cabinets in which shutdown circuitry exists. Cables in common raceways with the cables of shutdown circuits are not considered for the following reasons:

1. The raceways and all the cables in them were considered lost to a fire in any given fire area if not protected by any of the methods allowed by Section C.5.b to BTP CMEB 9.5-1.

2. The loss of cables in one fire area will not affect cabling in other plant areas for the following

reasons: BVPS-2 UFSAR Rev. 12 9.5A-8 a. Breaker and fuse protection has been demonstrated on all circuits except for 120 V ac control circuits for 480 V MCCs, both safety-related and nonsafety-related. For Class 1E MCCs, 120 V control circuit connected to CPT is provided with a fuse. For non-Class 1E MCCs, 120 V control circuit connected to CPT is either provided with a fuse or the fault current is limited by the design of CPT, b. The raceway system is designed to prevent the mixing of voltage classes, and c. Panel, cabinet, and board wiring provide separate bundling for opposite train/division wires. 3. Class 1E cables are strictly routed only with their associated train (orange, purple, or green) or instrument channel (red, blue, white, or yellow). Non-Class 1E cables (neutral) are routed only with their own type. In addition, power, control, or instrumentation cables are routed only with their associated service level (that is, 4,160 V ac; 480 V ac; 120 V ac; and 125 V dc, and instrumentation voltage levels). All cables routed from electrical devices which perform shutdown functions are entered into the analysis as potentially associated circuits. Cable routings are identified as they passed through or terminated within each of the individual fire areas. Where trains or channels of redundant divisions, or non-Class 1E circuits, enter the same enclosure, they are physically or mechanically separated from each other in accordance with BVPS-2's position on Regulatory Guide 1.75, Rev. 2. For further

details, see Sections 1.8 and 8.3.1.4. 9.5A.1.2.1.8 Electrical Means of Protection In-Place Electrical means of protection in-place is achieved by the following: 1. BVPS-2 cable wrapping materials provide fire rated protection for electrical raceways associated with safe shutdown capability. The cable wrap is designed to meet the following criteria: a. Vendor testing for cable derating factors for each type of cable insulation and its service level is

required. b. The cable wrap material is nonhygroscopic in nature. c. The cable wrap material is compatible with cable insulations used on BVPS-2. d. The cable wrap weight is seismically analyzed for effect on raceways and seismic supports. e. Only nonhazardous material is used and the material will not off-gas any harmful gases or produce any BVPS-2 UFSAR Rev. 0 9.5A-9 airborne particulate either in its normal installed state or when heated by a fire.

f. The cable wrap has the capability of conforming to various geometric configurations in addition to wrapping cables in different raceway types; that is, cable trays, conduit, or cables in free air.

g. The cable wrap is capable of being easily inspected for conformity, required thickness, and application.

h. Cable wrap material and installation procedures have American Nuclear Insurers acceptance.

9.5A.1.2.1.9 Mechanical Means of Protection In-Place

When practical, redundant mechanical equipment is placed in separate fire areas, where a fire area is defined as totally enclosed by fire barriers. When components are in the same fire area and relocation was not feasible, the area was analyzed based on configuration, combustible loading, and fire protection to ensure compliance with BTP CMEB 9.5.1. Where differences exist, deviations have been documented to justify the existing configurations (Refer to Section 9.5A.2).

9.5A.1.2.2 Safe Shutdown Summary

The following provides a general description of the various systems, components, and methods at BVPS-2 that can be utilized to achieve shutdown.

The reactor coolant boron concentration may be increased using high head charging pumps (2CHS*P21A, 21B, or 21C) which maintain RCS water inventory and deliver borated water to the RCS. Two suction sources of borated water can be used. Either the boric acid transfer pumps (2CHS*P22A, 22B) are used to provide up to 4 percent concentration of boric acid from the boric acid tanks (2CHS*TK21A, 21B) to the charging pump suctions or the refueling water storage tank (2QSS*TK21) may be injected by the charging

pumps via direct suction. Cooldown of the reactor to the hot shutdown condition is accomplished by removing the reactor core heat by the generation and release of steam in the steam generators. The RCS system temperature is reduced from hot standby power operation (approximately 540 F) to hot shutdown (less than 350 F) during this phase. Core heat is transferred by the RCS to the three steam generators (2RCS*SG21A, 21B, 21C) by natural circulation if the reactor coolant pumps are not available.

Heat is removed from the steam generators using the atmospheric steam release system combined with the auxiliary feedwater

system (FWE).

BVPS-2 UFSAR Rev. 12 9.5A-10 The atmospheric steam dump system, located in the main steam valve cubicle, consists of spring-loaded safety valves and manually controlled modulating dump valves designed to release steam directly to the atmosphere on a oncethrough basis.

Feedwater is continuously supplied to the steam generators for this purpose by the FWE. This system includes two 350-gpm

capacity motor-driven auxiliary feedwater pumps (2FWE*P23A, 23B), located in the safeguards area, as well as one 700-gpm steam turbine-driven auxiliary feedwater pump (2FWE*P22) also

located in the safeguards area. These pumps take suction from the primary plant demineralized water storage tank (2FWE*TK21O) (approximately 140,000 gal). A crosstie is also provided from the 600,000 gallon demineralized water storage tank (2WTD-TK23) to gravity feed 2FWE*TK210. The service water system also provides an emergency source of water from the Ohio River to the suction of the auxiliary feedwater pumps using the service water pumps (2SWS*P21A, 21B, 21C) in the intake structure. Cooldown from 350 F to less than 200 F is accomplished by utilizing the residual heat removal system. The residual heat removal pumps circulate reactor coolant from the RCS through the residual heat removal heat exchangers and return the coolant to

the RCS. The residual heat removal heat exchangers are cooled by the component cooling water system which is cooled by the

service water system. Using any of the alternative methods described, the reactor can be placed in a cold shutdown condition within 72 hours and

maintained in a safe shutdown condition. 9.5A.1.2.3 System Description and Identification

9.5A.1.2.3.1 Systems

The following systems are required to bring the plant to a cold shutdown condition. While bringing the plant to shutdown, no

other in-plant emergencies or failures are postulated other than

LOOP. 9.5A.1.2.3.1.1 Auxiliary Feedwater System

Immediately following a reactor trip, a supply of water is required for the steam generators to maintain steam generator level and to remove reactor heat. The FWE is used to maintain steam generator water level while cooling down the primary plant

from normal conditions to 350 F. The FWE consists of two motor-driven pumps, one turbine-driven pump, and six auxiliary feedwater control valves (2FWE*HCV100A,B,C,D,E, and F) to

control feedwater flow rate to the steam generators. The pumps take suction from a 140,000-gallon primary plant demineralized

water storage tank. Additional water volume is provided by the 600,000-gallon demineralized water storage tank which feeds by gravity through piping interconnections between these tanks. The service water system also provides an emergency source of water supplied from the Ohio River. BVPS-2 UFSAR Rev. 12 9.5A-11 9.5A.1.2.3.1.2 Main Steam System In order to achieve cold shutdown in the event of a fire, the main steam isolation valve in each header is closed and the steam is released to the atmosphere via the main steam dump valves, the residual heat release valve and the main steam safety valves. The dump valves and residual heat release valve are manually controlled to release enough steam to remove the reactor decay heat and to cool the RCS from normal conditions down to 350 F. The main steam safety valves operate automatically to prevent overpressurization of the steam generator. Main steam is also provided as motive force to the turbine-driven FWE pump through redundant solenoid-operated

valve and piping flow paths. 9.5A.1.2.3.1.3 Residual Heat Removal System The residual heat removal system (RHR) is the normal means of heat removal from the RCS to reduce temperatures from 350F to below 200F, the cold shutdown temperature. The system consists of two pumps, two heat exchangers, and the associated piping and valves. Component cooling water is provided via separate

headers to the heat exchangers. The RHR system takes suction

from one RCS loop using redundant flow paths, each with two motor-operated valves (MOVs), and discharges via redundant paths

to two RCS loops, each with one MOV. 9.5A.1.2.3.1.4 Component Cooling Water System The primary component cooling water system provides cooling water to the RHR heat exchangers, and RHR pump seal coolers. It consists of three pumps, three heat exchangers, and associated piping and supply/control valves. Separate flow paths are established to each redundant component supplied with water from the component cooling water system. 9.5A.1.2.3.1.5 Chemical and Volume Control System The chemical and volume control system is used to maintain RCS water inventory and to increase RCS coolant boron concentration to a cold shutdown value before cooldown and depressurization is initiated. During cooldown, reactor coolant inventory is controlled to maintain a relatively constant pressurizer water level by use of charging and letdown subsystems. Throttling valves are used to maintain an appropriate charging rate into the RCS using the charging pumps. The boric acid tanks and refueling water storage tank are used to ensure availability of borated water to the charging pumps for injection into the RCS. The boric acid transfer pumps are used to transfer borated water from the boric acid tanks to the charging pump suctions. Letdown from the RCS to reduce inventory is accomplished in either of two ways: 1) either the normal letdown or 2) the

reactor vessel head letdown system is used. The normal letdown line includes isolation valves, a pressure control valve, and two MOVs to direct letdown to the BVPS-1 coolant recovery tanks.

The reactor vessel head letdown system includes two trains (orange and purple) each of which consists of two solenoid operated isolation valves and one hand control valve for

controlling letdown. Letdown is directed to the pressurizer relief tank. BVPS-2 UFSAR Rev. 12 9.5A-12 9.5A.1.2.3.1.6 Service Water System The service water system supplies cooling water to the component cooling water system heat exchangers, emergency diesel coolers, charging pump coolers, and to various heating, ventilating and air-conditioning (HVAC) cooling coils. The service water system

is supplied with water from the Ohio River using the service water pumps (2SWS*P21A, 21B, and 21C) located in the intake structure.

9.5A.1.2.3.1.7 Reactor Coolant System

The RCS consists of three piping loops, each including one steam generator and one reactor coolant pump, which circulate water

through the reactor vessel to the steam generators where heat is removed using the main steam, and FWE. Redundant pressurizer power-operated relief valves are used to depressurize the RCS during temperature reduction by means of discharging to the pressurizer relief tank. The reactor vessel head letdown system can be used as an alternate letdown flow path if the normal letdown line is out of service. Redundant valves with

throttling capability are provided. 9.5A.1.2.3.1.8 Gaseous Nitrogen System

Portions of the gaseous nitrogen system are used to vent the safety injection system accumulators and to allow RCS depressurization without accumulator injection into the RCS. Redundant, paralleled valves are provided on the common header. This arrangement allows depressurization of all three

accumulators and is considered to be redundant to the SIS accumulator isolation valves.

9.5A.1.2.3.1.9 Emergency Diesel Generator Fuel Oil Storage and Transfer System

The emergency diesel generator fuel oil storage and transfer system provides fuel for operation of the Class 1E emergency diesel generators which are operated to supply shutdown loads following a LOOP. Redundant underground storage tanks are provided, each having two pumps per tank. These pumps automatically supply fuel to the associated day tank. Redundant

level indicating switches on each day tank start the pumps.

BVPS-2 UFSAR Rev. 15 9.5A-13 9.5A.1.2.3.1.10 Safety Injection System The portions of the safety injection system required for safe shutdown, are the redundant high head safety injection flow paths, the accumulator isolation valves, and the piping and valves from the refueling water storage tank to the suction of the charging pumps. Redundant high head safety injection flow paths with throttling valves are provided as alternate charging flow paths for RCS inventory control and boration.

The accumulator isolation valves are used to isolate the accumulators from the RCS prior to RCS cooldown to avoid sudden accumulator injection as RCS pressure decreases. The refueling

water storage tank is an alternate source of borated water for RCS inventory control and boration. Redundant valves and piping are provided to allow suction for the charging pumps.

9.5A.1.2.3.1.11 Heating, Ventilating, Air-Conditioning Systems (HVAC) HVAC - Cable Vault and Rod Control The safety-related portion of the cable vault and rod control area air-conditioning system consists of two air-conditioning units (2HVR*ACU208A and 208B), each of which filters and cools

100-percent recirculated air throughout those spaces. HVAC-Control Room (CB-3, CB-4, and CB-5) The main control room, computer room, and equipment room areas are air-conditioned by redundant units (2HVC*ACU201A and 201B).

Air cooling and dehumidification is provided by direct expansion freon cooling coils in each air handling unit. Either of two full capacity freon compressor/condensing units provide the necessary cooling capacity for the system. Heat is rejected through the condenser to the service water system. HVAC - Primary Auxiliary Building

The charging pump cubicles exhaust fans (2HVR*FN264A and 264B)

each exhaust air from the charging pump cubicles, and the primary component cooling water system pump area when the auxiliary building exhaust fans are inoperative. Fans and service water cooling coils are also provided for cooling the MCC enclosures. HVAC - Diesel Generator Building

The diesel generator building ventilation system consists of primary and secondary supply fans (2HVD*FN270A, 270B, 271A and 271B). The primary supply fans operate whenever the diesels are running. When indoor temperature increases, secondary supply

fans start. These fans provide forced ventilation air to dissipate heat generated by the diesel engine and generator.

BVPS-2 UFSAR Rev. 17 9.5A-14 HVAC - Service Building (Emergency Switchgear Rooms) The emergency switchgear supply fans (2HVW*FN261A and 261B) and exhaust fans (2HVZ*FN262A and 262B) ventilate and dissipate equipment heat loads from these rooms. HVAC - Intake Structure

Three axial flow fans (2HVW*FN257A, 257B and 257C) draw outside air into the pump cubicles to dissipate motor heat. Air is exhausted from the top of the cubicles through the screenwell house and out through roof exhaust hoods.

HVAC - Alternate Shutdown Panel Room

The alternate shutdown panel room temperature is maintained by an air-conditioning unit (2HVP*ACUS301) which is comprised of a centrifugal fan, direct expansion cooling coil, cartridge type filter, compressor, a watercooled condenser, an electric heating coil with built-in flow switch, one motor-operated outdoor air damper, and area inlet and outlet fire rated dampers.

9.5A.1.2.3.1.12 Instrument Air System The instrument air system supplied by diesel driven Standby Instrument Air Compressor 2IAS-C21 is required to position several flow control, hand control, and air operated valves that are required for post-fire safe shutdown. The station instrument air system can supply the containment instrument air header via a cross-connect. The diesel driven Standby Instrument Air Compressor 2IAS-C21 is located in the Turbine Building and has an 8-hour fuel supply. The 8-hour fuel supply is adequate to establish stable plant condition and will be replenished as required to supply residual heat control valves to achieve cold shutdown. The diesel driven Standby Instrument Air Compressor 2IAS-C21 does not require any external support systems to perform its safe shutdown function.

9.5A.1.2.3.1.13 Post-Accident Neutron Flux Monitoring System

The post-accident neutron flux monitoring system is an ex-core design containing two fission chambers housed within the neutron

shield tank.

BVPS-2 UFSAR Rev. 11 9.5A-14a This system provides source range neutron indication from 10 to 10 counts per minute. The post-accident neutron flux monitoring system supplies outputs to the plant safety monitoring system and the alternate shutdown panel.

9.5A.1.2.3.1.14 Electrical Systems The following briefly describes the BVPS-2 electrical systems

required to bring the plant to a cold shutdown condition.

BVPS-2 UFSAR Rev. 16 9.5A-15 Emergency Power System The emergency power system is an independent, automatic starting power source which supplies power to vital station auxiliaries

if a normal power source is not available. The following is a discussion of the independence between redundant emergency power sources and between their distribution systems. 1. The electrical power loads for emergency safety features are separated into redundant load groups fed from separate buses such that loss of one group will

not prevent operation of minimum safety functions.

2. The redundant power loads are each connected to buses which may have power fed from an offsite power source or an emergency power source (that is, an emergency diesel generator unit).

3. Two 125 V dc systems, each complete with batteries, chargers, switchgear, and distribution equipment, are provided for ESF equipment. These systems are not tied together. In addition, on each independent system two channel dedicated batteries are provided to supply 125 V dc to two channel dedicated vital bus inverters.

4. A standby source of power for one redundant load cannot be automatically paralleled with the standby

source of power for the other redundant load.

5. Each redundant ac ESF load is supplied with power from a separate emergency diesel generator unit.

A color coding system is used to identify channel cables and to ensure that redundant instrument channels associated with the solid state protection systems are isolated from each other. Channels I, II, III, and IV are color-coded red, white, blue, and yellow, respectively. This channel identity need only be maintained until some channel terminating device is used. The device may be a qualified isolating transformer or an electromagnetic relay. Channel codings are generally applied to inputs from primary and secondary process systems, which are ultimately fed to the solid state protection systems. Redundant sources of power for primary process and ESF, protective equipment, and associated controls are identified as A and B, with orange and purple color coding, respectively. Where circuits may be supplied from either the A or B source, they are

designated by C and color-coded green. AC Emergency Power System The ac emergency system includes power supplies, a distribution system, and load groups arranged to provide power to Class 1E

loads. BVPS-2 UFSAR Rev. 0 9.5A-16 The system has two Class 1E 4,160 V, 3-phase, 60 Hz diesel-driven synchronous generators. The two diesel generator units are electrically and physically isolated from each other. A single nonsafety-related onsite standby diesel generator (black

diesel) is provided to supply non-Class 1E loads. Each 4,160 V Class 1E bus is continuously energized from the station service system or from an emergency diesel generator, and feeds a single 480 V emergency bus. The transfer from the station service system to emergency diesel generators, when

required, can be accomplished either automatically or manually. The emergency buses and the supply for all essential components are normally connected to the station service system. Two circuit breakers in series are provided in these supply circuits from the normal buses to the emergency buses.

The emergency diesel generators can be manually started on a signal from the main control room, or are automatically started on the receipt of a time-delay undervoltage signal from the emergency bus source, a safety injection signal, or an opening of either one of the series-connected normal supply circuit

breakers. Loss of voltage on the normal bus opens both series-connected supply circuit breakers and closes the emergency source breaker when generator voltage and speed is established.

Redundant breakers, which ensure that the emergency bus is disconnected from the normal station service system, have independent trip circuits supplied by independent 125 V dc control power sources. Redundant power sources, circuit breakers, and relays are physically separated by concrete walls

or metal barriers. 120 V ac Vital Bus System The vital bus system is composed of four redundant subsystems to ensure a very reliable electrical source for safeguard protection channels. The 120 V ac vital buses are supplied by four single-phase inverters. During normal operation, each inverter receives power from a separate Class 1E 480 V MCC. Backup power for the inverters is always available through the permanent connection of one inverter to each of four station batteries, such that loss of any one source affects only one vital bus. This provides a stable supply to vital equipment and guarantees proper action when power is required, while eliminating shutdowns.

The vital buses are also supplied with individual static transfer switches. These switches are designed to transfer circuitry to an alternate source during inverter output undervoltage. Manual transfer capability exists to facilitate maintenance procedures.

The alternate source power is supplied through two redundant regulating transformers, each of which feeds two vital bus

transfer

BVPS-2 UFSAR Rev. 13 9.5A-17 switches. The supplies to the alternate source regulators are from two MCCs which are not associated with the balance of the vital bus equipment.

The distribution cabinets have 15- and 20-amp branch circuit breakers to feed the reactor protection channel as well as the other vital instrument channels. Redundant instrument channels

are fed from redundant vital buses. 125 V dc Emergency Power System The 125 V dc power system includes power supplies, a distribution system, and load groups that are arranged to provide direct current electric power to direct current loads or for control and switching of shutdown systems.

The 125 V dc system supplies power for the operation of switchgear and vital bus inverters.

The Class 1E batteries are located in a fire area provided for electrical equipment. Within this fire area, the batteries are located in two areas separated by concrete walls. This permits isolation of the 125 V dc power for the two trains. Each battery is then located in its own room bounded by 3-hour fire-resistant rated walls. In the same area as the battery rooms

are the associated switchgear distribution switchboard, battery charger, and vital bus inverters for the nondedicated batteries. Also within this area are the associated vital bus inverters for the dedicated batteries. Adequate physical separation exists between redundant components to prevent common failure from an exposure fire.

Direct current switchboards 1 and 2 supply their vital bus inverters in addition to the dc distribution panels, the emergency diesel generator auxiliary systems, and the switchgear control circuits.

Batteries 3 and 4 are dedicated to their respective vital bus inverters and as such have no dc switchboards.

9.5A.1.2.4 Alternate Shutdown Panel 9.5A.1.2.4.1 Compliance with Section C.5.c of BTP CMEB 9.5-1

An alternative shutdown capability was developed due to the in-place congestion of electrical cables and their raceways in certain areas, the subsequent limited space in providing separation or in-place protection of redundant trains, and in accordance with Section C.5.b of BTP CMEB 9.5-1. These areas are the instrumentation and relay room (CB-1), cable spreading room (CB-2), main control room (CB-3), west communication room (emergency shutdown panel station) (CB-6), and cable tunnel (CT-l). Fire Areas CB-1, CB-2, and CT-1 are actually one fire area. However, for analysis purposes, the areas are described as three different sub-fire areas.

BVPS-2 UFSAR Rev. 13 9.5A-18 In accordance with Section C.5.c of BTP CMEB 9.5-1, the alternate shutdown panel (ASP) provides a means of alternative shutdown capability which bypasses required safe shutdown all equipment and electrical cables located in the preceding five fire areas. All cables which pass through these areas and which are required for shutdown are electrically disconnected from their circuits to ensure isolation of the affected fire area and

allow independence of the ASP or separated by a l-hour fire-rated material.

In addition, the ASP is relied upon for transfer of controls for the No. 1 EDG for a fire in SB-3 to isolate voltage regulator and tachometer circuits routed in SB-3, and in SB-4 for monitoring of certain instrumentation and ventilation control for the No. 1 EDG Room.

The ASP, which is located at el 755 ft-6 in. of the auxiliary building/cable tunnel, controls one train of redundant division components which are necessary for cold shutdown of the plant.

9.5A.1.2.4.2 Design and Operation

The ASP includes the necessary controls to:

1. Achieve and maintain the reactor in a shutdown condition.

2. Maintain reactor coolant inventory.

3. Achieve and maintain hot standby conditions, and

4. Achieve and thereafter maintain cold shutdown conditions within 72 hours.

The chemical and volume control system and its controls are available to maintain reactor coolant water inventory and to provide borated water to the RCS.

The RHR system, primary component cooling water system, and service water system and their controls are available to remove

decay heat from the reactor. All instrumentation and monitoring equipment necessary for

proper control of the shutdown process is included in the ASP. All electrical equipment, panels, and cabinets used for alternate shutdown implementation meet the same design criteria as other safety-related equipment and hardware. All ASP transfer switches are monitored by the annunciator/computer system, virtually eliminating the possibility of any inadvertent control isolation signal from either the main control board or the emergency shutdown panel.

Power supply to the ASP originates at a Class 1E 4,160 V emergency bus. This supply, which is backed by a Class 1E emergency diesel generator, provides a continued power source during a postulated

BVPS-2 UFSAR Rev. 0 9.5A-19 72-hour LOOP. A voltage regulating isolating transformer is included to provide 120 V ac non-Class 1E power. Since certain components of the ASP are integral portions of the Class 1E system, the entire panel is designed to meet Class 1E qualification requirements, including Seismic Category I criteria. Those components which do not serve a safety-related function are isolated from Class 1E components, in accordance with Regulatory Guide 1.75 and IEEE 384-1974, through the use of barriers and spacing. Most of the required ASP indicating instruments receive their signals from Class 2 transmitters. Four of the ASP indicating instruments (RCS hot leg temperature) receive their signals from Westinghouse Qualification Group A

transmitters. Two fuses are provided for the protection of the control

transformer secondary on each 480 V load that requires a motor starter and is controlled from the ASP. One fuse protects the circuit that has cables which route through CB-1, CB-2, CB-3, CB-6, or CT-1 and the other fuse protects the circuit that routes through other fire areas. In this manner, no single exposure fire postulated in the above fire areas would disable

the other protected leg located on the ASP. BVPS-2 UFSAR Rev. 0 9.5A-20 9.5A.1.3 Fire Hazards Analysis by Fire Area The fire areas discussed in this section are as follows:

Section Fire Area Description Elevation Page 9.5A.1.3.1 ASP Auxiliary building-ASP 755'-6" 9.5A-22 room 9.5A.1.3.2 CB-1 Instrumentation and relay room 707'-6" 9.5A-24 9.5A.1.3.3 CB-2 Cable spreading room 725'-6" 9.5A-27 9.5A.l.3.4 CB-3 Control room 735'-6" 9.5A-29 9.5A.1.3.5 CB-4 Computer room 735'-6" 9.5A-31 9.5A.1.3.6 CB-5 Fan room 735'-6" 9.5A-32 9.5A.1.3.7 CB-6 West communication room 707'-6" 9.5A-34 (ESP station) 9.5A.1.3.8 CP-1 Condensate polishing All 9.5A-36 building 9.5A.1.3.9 CT-1 Cable tunnel/fan room 712'-6"/ 9.5A-38 773'-6" 9.5A.1.3.10 CV-1 Cable vault and rod 735'-6" 9.5A-41 control (west) 9.5A.1.3.11 CV-2 Cable vault and rod 735'-6" 9.5A-43 control (east) 9.5A.1.3.12 CV-3 Cable vault and rod 755'-6" 9.5A-45 control 9.5A.1.3.13 CV-4 Cable vault and rod 773'-6" 9.5A-47 control 9.5A.1.3.14 CV-5 Cable vault and rod 773'-6" 9.5A-49 control 9.5A.1.3.15 CV-6 Cable vault and rod 755'-6" 9.5A-50 control (relay room) 9.5A.1.3.16 DG-1 Diesel generator All 9.5A-52 building (south) 9.5A.1.3.17 DG-2 Diesel generator All 9.5A-54 building (north) 9.5A.1.3.18 FB-1 Fuel building 705' 9.5A-56 9.5A.1.3.19 IS-2 Intake structure 705' 9.5A-58 9.5A.1.3.20 IS-3 Intake structure 705' 9.5A-59 9.5A.1.3.21 IS-4 Intake structure 705' 9.5A-61 9.5A.1.3.22 MS-1 Main steam valve area 773'-6" 9.5A-63 9.5A.1.3.23 PA-3 Auxiliary building 710'-6" 9.5A-65 through 755'-6" 9.5A.1.3.24 PA-4 Auxiliary building 755'-6" 9.5A-69 9.5A.1.3.25 PA-5 Auxiliary building 773'-6" 9.5A-72 9.5A.1.3.26 PA-6 Auxiliary building 755'-6" 9.5A-74 9.5A.1.3.27 PA-7 Auxiliary building 755'-6" 9.5A-75 9.5A.1.3.28 PT-1 Pipe tunnel 718'-6" 9.5A-76 9.5A.1.3.29 RC-1 Reactor containment All 9.5A-78 9.5A.1.3.30 SB-1 Service building 730'-6" 9.5A-82 (West) BVPS-2 UFSAR Rev. 0 9.5A-21 Section Fire Area Description Elevation Page 9.5A.1.3.31 SB-2 Service building 730'-6" 9.5A-84 (East) 9.5A.1.3.32 SB-3 Service building 745'-6" 9.5A-86 (cable tray area) 9.5A.1.3.33 SB-4 Service building 760'-6" 9.5A-88 9.5A.1.3.34 SB-5 Service building 780'-6" 9.5A-90 9.5A.1.3.35 SB-6 Service building 730'-6" 9.5A-92

battery room 2-1 9.5A.1.3.36 SB-7 Service building 730'-6" 9.5A-93

battery room 2-3 9.5A.1.3.37 SB-8 Service building 730'-6" 9.5A-94 battery room 2-2 9.5A.1.3.38 SB-9 Service building 730'-6" 9.5A-95 battery room 2-4 9.5A.1.3.39 SB-10 Service building 760'-6" 9.5A-96

battery room 2-5 9.5A.1.3.40 SG-1N Safeguards building All 9.5A-97 (north) 9.5A.1.3.41 SG-1S Safeguards building All 9.5A-99 (south) 9.5A.1.3.42 TB-1 Turbine building 730'-6' 9.5A-101 9.5A.1.3.43 TB-2 Turbine building 752'-6" 9.5A-104

battery room 2-6 9.5A.1.3.44 WH-1 Waste handling building 722'-6"/ 735'-6" 9.5A-105 9.5A.1.3.45 WH-2 Waste handling building 774'-6" 9.5A-106 9.5A.1.3.46 AIS-1 Alternate intake All 9.5A-108 structure 9.5A.1.3.47 CTP-1 Cooling tower pump All 9.5A-109 house 9.5A.1.3.48 VP-1 Valve pit (east) All 9.5A-110 9.5A.1.3.49 VP-2 Valve pit (west) All 9.5A-111 9.5A.1.3.50 SOB-1 Aux boiler area 730' 9.5A-112 9.5A.1.3.51 SOB-2 SOBS railway bay 730' 9.5A-113 9.5A.1.3.52 SOB-3 South office shops bldg All 9.5A-114 9.5A.1.3.53 TR-1 to 5 Transformers 730' 9.5A-115 9.5A.1.3.54 Not Unit 1 Components BVPS 9.5A-117 Applic- able -Unit 1 BVPS-2 UFSAR Rev. 14 9.5A-22 9.5A.1.3.1 FIRE AREA ASP - ALTERNATE SHUTDOWN PANEL ROOM 9.5A.1.3.1.1 Fire Area Description

Separation between Fire Area ASP and adjacent fire areas is provided by 3-hr fire-rated walls and ceiling. Any penetrations are sealed with a rating equivalent to the barrier rating. Ventilation penetrations are provided with two 1 l/2-hr fire-rated dampers in series.

The fire analysis for this area determined that a fire barrier of <1/2 hr is required. The walls, ceiling, and floor have a fire rating in excess of the required rating.

The ASP (PNL*2ALTSHDN) provides a means of alternate shutdown capability which bypasses equipment and electrical cables required for achieving shutdown located in the instrumentation and relay room (CB-1), cable spreading room (CB-2), control room (CB-3), west communications room (emergency shutdown panel

station) (CB-6), and cable tunnel (CT-1). The ASP houses all instrumentation and monitoring equipment

necessary for proper control of the shutdown process. The shutdown components located in fire area ASP are listed in the Fire Protection Safe Shutdown Report.

9.5A.1.3.1.2 Methods of Suppression/Detection

Fire hose rack stations and portable fire extinguishers are provided. Detection consists of area ionization coverage with

control room and local alarms. This area provides backup shutdown protection in the event of a fire in other areas. Consequently, in the event of a total burnout of this area, normal shutdown paths are available for shutdown using the purple train. A fire in this area will be

controlled and extinguished within the area. 9.5A.1.3.1.3 Safe Shutdown Summary

Since orange train circuits are controlled by the ASP, orange train (in addition to red and blue channel-related shutdown equipment) is assumed lost due to a fire in Area ASP. The purple and green (swing) train equipment is used to achieve shutdown from the main control room.

BVPS-2 UFSAR Rev. 15 9.5A-23 9.5A.1.3.1.4 Deviations from BTP CMEB 9.5-1 C.5.a(4) Modified fire dampers

C.5.b Safe shutdown capability (PORV spurious operation)

BVPS-2 UFSAR Rev. 14 9.5A-24 9.5A.1.3.2 FIRE AREA CB CONTROL BUILDING INSTRUMENTATION AND RELAY AREA 9.5A.1.3.2.1 Fire Area Description

This room is contiguous to CB-2 and CT-1. No barriers are provided between CB-1 and CB-2 or CT-1 as all rooms are part of

one fire area due to the large amount of interconnecting cable trays. The instrumentation room contains both Class 1E and non-Class 1E equipment and cable. The equipment essential for shutdown consists of the primary and secondary process racks, solid state protection racks, auxiliary relay and safeguards cabinets, nuclear instrumentation racks, movable detector flux mapping cabinet, and safeguards test cabinets.

Cable associated with safe shutdown located in this fire area have been identified and evaluated. Redundant trains of safe shutdown circuitry are located in this area. Alternate shutdown capability has been provided for this area.

The shutdown components located in fire area CB-1 are listed in the Fire Protection Safe Shutdown Report.

9.5A.1.3.2.2 Methods of Suppression/Detection The primary fire protection system for this area is an automatic or manual double capacity, total flooding CO system. Hose rack stations and portable fire extinguishers provide a backup. Fire detection is provided by the early warning fire detection system

which provides fire alarms locally and in the control room.

BVPS-2 UFSAR Rev. 12 9.5A-25 The CO system is designed to attain a 50-percent concentration as recommended for cable fires (NFPA-12). Automatic actuation of the CO system is provided by the "XL-3" fire detection system which is a "Priority" system with local and control room

alarms. In the event of a fire in CB-1 or the other two rooms (CB-2 or CT-l), the automatic CO system will flood this entire area, thus preventing the spread of fire to adjacent fire areas. The actuation of the CO system will automatically shut off the supply and exhaust fans for CB-1, CB-2 and CT-1. The fire analysis for this room determined that a 2-hour fire barrier is required. The walls, floor, ceiling, and doors exceed the required rating. A review of the perimeter penetrations of this fire area determined that fire dampers are not necessary in the ductwork which penetrates the partial wall between CB-1 and CT-1 and the slab between CB-1 and CB-2 since they are part of the same fire area. Ductwork penetrating the

perimeter walls of CB-1, CB-2, and CT-1 from adjacent fire areas is equipped with two 1 l/2-hour fire dampers in series.

The following postulated fires were evaluated for this room:

1. A postulated fire in an electrical panel located in this area. The panel separation and panel wiring separation limit the propagation of fire to other panels. The detection system would provide early remote indication of a fire and actuation of the CO system would suppress the fire.

2. The postulated ignition of safety-related cabling. The separation of redundant safety-related cables in conjunction with the flame-resistant, fire retardant properties of the cable insulation, would limit the propagation of fire to redundant cabling. The

detection system would provide early remote indication of a fire and actuation of the CO system would suppress the fire. Therefore, a fire in this area will be controlled and extinguished within the area.

9.5A.1.3.2.3 Safe Shutdown Summary Purple powered components (in addition to white and yellow channel equipment) are assumed to be lost as a consequence of a fire in Area CB-1. Orange powered components, in addition to selected components powered from the black diesel, are utilized

to achieve shutdown. The fire in Area CB-1 could potentially lead to a control room evacuation

BVPS-2 UFSAR Rev. 15 9.5A-26 in the event of loss of plant control. Plant shutdown would, therefore be achieved by the alternate shutdown method. 9.5A.1.3.2.4 Deviations from BTP CMEB 9.5-1

a. C.5.a(4) Modified fire dampers

b. C.5.e(2) CO vs. water in cable rooms. (CO is the primary fixed suppression system instead of water.) c. C.7.c Cable spreading room

   -CO vs water (same as above)    -Aisle separation less than 3' x 8'    -No continuous line-type heat detectors in      cable trays 

d. C.5.a(5) Unsupervised fire doors to area protected by gas suppression system.

e. C.5.c(7) Alternative or dedicated safe shutdown capability (PORV spurious operation)

BVPS-2 UFSAR Rev. 12 9.5A-27 9.5A.1.3.3 FIRE AREA CB CONTROL BUILDING CABLE SPREADING AREA 9.5A.1.3.3.1 Fire Area Description

This room is contiguous to CB-1 and CT-1. No barriers are provided between CB-1, CB-2 and CT-1 as all rooms are part of one fire area due to the large amount of interconnecting cable trays. The cable spreading area contains safety-related redundant instrument, control, and power cables that are required for attaining safe shutdown. The area also contains nonsafety-related instrument, control, and power cable. All power cable is run in metal-enclosed raceways.

Cables associated with safe shutdown located in this fire area have been identified and evaluated. Redundant trains of safe shutdown circuitry are located in this area. Alternate shutdown

capability has been provided for this area. No safe shutdown components are located in Fire Area CB-2.

9.5A.1.3.3.2 Methods of Suppression/Detection

The primary fire suppression system for this area is an automatic or manual double capacity, total flooding CO system. Hose rack stations and portable fire extinguishers provide backup. Fire detection is provided by the early warning fire detection system which provides fire alarms locally and in the control room. The CO system is designed to attain a 50-percent concentration as recommended for cable fires (NFPA-12).

Automatic actuation of the CO system is provided by the "XL-3" fire detection system which is a "Priority" system with local and control room alarms. The alarms enable the control room to

be aware of the status and availability of the CO system at all times. The fire analysis determined that a 2-hour fire barrier is required. The walls, floors, ceiling slab, and doors exceed this required rating. A review of the perimeter penetrations of this fire area has determined that fire dampers are not necessary in the ductwork which penetrates the partial wall between CB-2 and CT-1 and the slab between CB-2 and CB-1 since they are part of the same fire area. Ductwork penetrating the perimeter walls of CB-2, CB-1, and CT-1 from adjacent fire areas is equipped with

two 1 1/2-hour fire-rated dampers in series.

BVPS-2 UFSAR Rev. 15 9.5A-28 The postulated fire for this area is the ignition of safety-related cabling. Based on the flame-resistant, fire-retardant properties of the cable insulation, the automatic CO suppression system, and the local hose rack stations, a fire in

this area will be controlled and extinguished within the area. 9.5A.1.3.3.3 Safe Shutdown Summary Purple powered components (in addition to white and yellow channel equipment) are assumed to be lost as a consequence of a

fire in Area CB-2. Orange powered components, in addition to selected components powered from the black diesel, are utilized

to achieve shutdown. The fire in Area CB-2 could potentially lead to a control room evacuation in the event of loss of plant control. Plant shutdown would, therefore, be achieved by the

alternate shutdown method. 9.5A.1.3.3.4 Deviations from BTP CMEB 9.5-1

a. C.5.e(2) CO vs. water in cable rooms (CO is the primary fixed suppressant instead of water)

b. C.7.c Cable Spreading Room

       - CO vs water (same as above)        - Aisle separation less than 3' x 8'.        - No continuous line-type heat detectors in cable trays. 

c. C.5.a(5) Unsupervised fire doors to area protected by gas suppression system.

d. C.5.c(7) Alternative or Dedicated Safe Shutdown Capability (PORV spurious operation)

BVPS-2 UFSAR Rev. 14 9.5A-29 9.5A.1.3.4 FIRE AREA CB CONTROL BUILDING MAIN CONTROL ROOM 9.5A.1.3.4.1 Fire Area Description

All penetrations of the control room perimeter walls and floors are sealed with a material having a rating equivalent to the barrier rating.*

Cables associated with safe shutdown located in this fire area have been identified and evaluated. Redundant trains of safe shutdown circuitry are located in this area. Alternate shutdown capability has been provided for this area.

Controls, instrumentation, displays, and alarms required for the normal plant operation and plant safe shutdown are located in this area:

The shutdown components located in fire area CB-3 are listed in the Fire Protection Safe Shutdown Report.

• CB-3 is actually one fire area consisting of both the BVPS-1 Control Room (CR-l) and the BVPS-2 Control Room (CB-3).

9.5A.l.3.4.2 Methods of Suppression/Detection

Portable fire extinguishers are provided for this area. Hose rack stations are located in the control building stairwells. Fire detection is provided by the early warning fire detection system using ionization smoke detectors located throughout the control room and in the vertical control boards. This system provides local and control room alarms.

The fire loading for this area determined an equivalent severity of less than a l/2-hour fire barrier. The walls, floors, ceiling slabs, and doors exceed this required rating. A review and evaluation of the perimeter penetrations with adjacent areas determined the following:

1. A fire rated barrier is supplied for the control room benchboard access panels. The 3-hour fire barrier is provided at the floor by the main control board supplier.

2. The control room air-conditioning system services Areas CB-3, CB-4, and CB-5. Control room air-

conditioning ductwork penetrations of the perimeter of these areas are provided with two 1 1/2-hour fire dampers in series.

BVPS-2 UFSAR Rev. 15 9.5A-30 The available fire extinguishing equipment and the automatic detection system, considered in conjunction with the low fire loadings in these areas, and the fact that the control room is continuously manned, provides for the control and total suppression of a fire in this area. The postulated fire for this area is the ignition of safety-related panel wiring. The panel separation, panel wiring separation, and barriers are described in Section 8. The early warning fire detection system provides for detection of a fire in its incipient stages and will be quickly extinguished using the available fire extinguishing equipment.

9.5A.1.3.4.3 Safe Shutdown Summary

Purple powered components (in addition to white and yellow channel equipment) are assumed to be lost as a consequence of a fire in Area CB-3. Orange powered components, in addition to selected components powered from the black diesel, are utilized to achieve shutdown. The fire in Area CB-3 could potentially lead to a control room evacuation in the event of loss of plant control. Plant shutdown would, therefore, be achieved by the alternate shutdown method.

9.5A.1.3.4.4 Deviations from BTP CMEB 9.5-1

a. C.5.a(4) Modified fire dampers (l-hour wrap ductwork)

b. C.5.f(3)

Control room ventilation (Power cables routed within area)

c. C.7.b Control room

  - Peripheral room not separated by l-hour fire barrier (shift supervisor's office).    - Cabling routed under raised floor without automatic suppression.    - Carpeting installed in control room. 

d. C.5.a(5) Modified fire doors

e. C.5.c(7) Alternative or Dedicated Safe Shutdown Capability (PORV spurious operation)

BVPS-2 UFSAR Rev. 12 9.5A-31 9.5A.1.3.5 FIRE AREA CB CONTROL BUILDING COMPUTER ROOM 9.5A.1.3.5.1 Fire Area Description

This area contains the plant computer systems. All penetrations of the perimeter walls are sealed with materials having a rating

equivalent to the barrier rating.

No shutdown components or cable is located in this area. 9.5A.1.3.5.2 Methods of Suppression/Detection The primary fire suppression system for this area is an automatic or manual double capacity, total flooding Halon system. Hose rack stations and portable fire extinguishers provide backup. Fire detection is provided by the early warning fire detection system which provides fire alarms locally and in the control room. The Halon system is designed to attain a 7-percent concentration as recommended by NFPA-12A. Automatic

actuation of the Halon system is provided by the "XL-3" fire detection system which is a "Priority" system with local and control room alarms. The alarms enable the control room to be aware of the status and availability of the Halon system at all times. 9.5A.1.3.5.3 Safe Shutdown Summary All shutdown paths remain available since no shutdown components or cables are located in CB-4. Plant shutdown is achieved from the main control room with orange and/or purple powered components.

9.5A.1.3.5.4 Deviations from BTP CMEB 9.5-1

a. C.5.a.(4) Ventilation penetration openings (two 1 l/2-hour fire-rated dampers in series)

b. C.5.a.(5) Unsupervised fire door to area protected by gas suppression system.

BVPS-2 UFSAR Rev. 14 9.5A-32 9.5A.1.3.6 FIRE AREA CB CONTROL BUILDING FAN ROOM 9.5A.1.3.6.1 Fire Area Description

The fire loading for this area determined an equivalent severity of less than 1/2 hour. The walls, floors, and doors are rated in excess of the rating required. Ductwork penetrating the

walls separating CB-3, CB-4, and CB-5 are all equipped with two 1 l/2-hour fire dampers in series. All penetrations of the perimeter walls are sealed with a material having a rating

equivalent to the barrier rating. This area contains the HVAC equipment and controls for the control building areas CB-3 through CB-5. The emergency outside air pressurization fans and charcoal filter banks are also located in this area. All motors and controls associated with the air-conditioning and pressurizing systems are supplied from redundant emergency powered buses, and all equipment has 100-percent redundancy.

Cables in this fire area associated with safe shutdown have been identified and evaluated.

The shutdown components located in fire area CB-5 are listed in the Fire Protection Safe Shutdown Report.

9.5A.1.3.6.2 Methods of Suppression/Detection

Fire hose rack stations are provided in the control building stairwells on the floor below. Portable fire extinguishers are available in this area. Detection consists of area ionization

coverage with control room and local alarm. Heat detection with control room alarm is provided for the charcoal filter banks.

The following fires were postulated for this area:

1. An oil fire associated with the refrigerant condensing units 2HVC*REF24A/B.

BVPS-2 UFSAR Rev. 9 9.5A-33 2. Ignition of safety-related cabling.

3. A charcoal fire in one of the filter banks.

Based on the available fire extinguishing equipment, the automatic detection system, and the existing barriers, a fire in this area will be controlled and extinguished within the area.

9.5A.1.3.6.3 Safe Shutdown Summary

A fire in Area CB-5 will render both trains of the control room HVAC system in addition to associated service water components inoperable. Unit 2 control room ventilation shall be provided

by the Unit 1 control room HVAC system or portable ventilation. Purple power is assumed lost due to loss of PNL-VITBUS-2-2A and 2-2D and consequently support systems for the 'B' diesel generator.

Plant shutdown is achieved with orange powered components from the main control room.

9.5A.1.3.6.4 Deviations from BTP CMEB 9.5-1

a. C.5.a(4) Modified fire dampers

BVPS-2 UFSAR Rev. 14 9.5A-34 9.5A.1.3.7 FIRE AREA CB CONTROL BUILDING WEST COMMUNICATION ROOM 9.5A.1.3.7.1 Fire Area Description

All penetrations of perimeter walls and ceiling are sealed with a material having a rating equivalent to the barrier rating. Ventilation penetrations through the communication room walls are provided with two 1 1/2-hour fire-rated dampers in series.

The west communication room contains both Class 1E and non-Class 1E equipment and cable.

Cable associated with safe shutdown located in this fire area have been identified and evaluated. Redundant trains of safe shutdown circuitry are located in this area. Alternate shutdown

capability has been provided for this area. The shutdown components located in fire area CB-6 are listed in the Fire Protection Safe Shutdown Report.

9.5A.1.3.7.2 Methods of Suppression/Detection

The primary fire suppression system for this area is an automatic or manual double capacity, total flooding Halon system. Hose rack stations and portable fire extinguishers provide backup. Fire detection is provided by the early warning fire detection system which provides fire alarms locally and in the control room. The Halon system is designed to attain a 7-percent concentration as recommended by NFPA-12A. Automatic actuation of the Halon system is provided by the "XL-3" fire detection system which is a "Priority" system with local and control room alarms. The alarms enable the control room to be aware of the status and availability of the Halon system at all

times. A postulated fire for this area is a fire in the emergency shutdown panel PNL*2SHUTDN. The automatic Halon system is sufficient to limit a fire to this area.

9.5A.1.3.7.3 Safe Shutdown Summary Purple powered components (in addition to white and yellow channel equipment) are assumed to be lost as a consequence of a fire in Area CB-6. Orange powered components, in addition to selected components powered from the black diesel, are utilized

to achieve shutdown. The

BVPS-2 UFSAR Rev. 15 9.5A-35 fire in Area CB-6 could potentially lead to a control room evacuation in the event of loss of plant control. Plant shutdown would, therefore, be achieved by the alternate shutdown method. 9.5A.1.3.7.4 Deviations from BTP CMEB 9.5-1

a. C.5.a(4) Modified fire dampers

b. C.5.a(5) Unsupervised fire doors to area protected by gas suppression system.

c. C.5.c(7) Alternative or Dedicated Safe Shutdown Capability (PORV spurious operation)

BVPS-2 UFSAR Rev. 12 9.5A-36 9.5A.1.3.8 FIRE AREA CP CONDENSATE POLISHING BUILDING 9.5A.1.3.8.1 Fire Area Description

The building construction provides fire barriers in excess of the required rating. Penetrations of the concrete walls to

adjacent fire areas have been sealed with a material having a rating equivalent to the barrier rating. As described under the turbine building analysis, a water spray deluge water curtain has been provided to separate the turbine building (TB-1) from the condensate polishing building via the pipe tunnel. Any ventilation penetrations of the perimeter to adjacent areas have

been provided with two 1 l/2-hour fire dampers in series. There are no shutdown components or cables located in this

building. 9.5A.1.3.8.2 Methods of Suppression/Detection A charcoal filter system located in Zone CP-lA exhausts air from cubicles in the condensate polishing building. The filter is protected by a remote manually operated water spray fire suppression system. Heat detectors actuate an alarm in the main control room.

Other fire hazard areas in the condensate polishing building are the ion exchange resin storage areas (Zone CP-1C, Zone CP-1B, and the primary chemical lab Zone CP-1D. An automatic wet pipe sprinkler system which alarms in the control room and has an audible outside water alarm is provided for these fire hazard

areas. Each system is monitored for abnormal positioning of the sprinkler header isolation valve from the full open position. If this condition exists, an alarmed "TROUBLE" display in the

control room would result. Additional fire suppression capability is provided by fire hose

rack stations and portable fire extinguishers.

The fire protection capabilities are adequate to control and

extinguish any fire in this area. 9.5A.1.3.8.3 Safe Shutdown Summary

A fire in CP-1 does not affect any shutdown components or cable. Plant shutdown can be achieved with orange and/or purple

components from the main control room.

BVPS-2 UFSAR Rev. 0 9.5A-37 9.5A.1.3.8.4 Deviations from BTP CMEB 9.5-1

a. C.5.a(4) Modified fire dampers

b. C.5.a(5) Modified fire doors

BVPS-2 UFSAR Rev. 12 9.5A-38 9.5A.1.3.9 FIRE AREA CT CABLE TUNNEL 9.5A.1.3.9.1 Fire Area Description

This area is contiguous to CB-2 and CB-1. No barriers are provided between CB-1, CB-2 and CT-1 as all rooms are part of

one fire area due to the large amount of interconnecting cable

trays. Fire Area CT-1 consists of two zones: the cable tunnel, el 712 ft-6 in., which connects the control building to the auxiliary building, and the fan room which is located on the 773 ft. - 6 in. elevation of the auxiliary building. These two areas are connected by 2 vertical concrete ventilation shafts which are used to provide ventilation (supply and exhaust air) to the control building (Areas CB-1, CB-2, CB-6, and CT-l). The fan room is separated from the auxiliary building 773 ft. - 6 in. general area by 2-ft-thick reinforced concrete walls, and its roof is separated from the auxiliary building proper.

The control building supply and exhaust fans (2HVC*FN265A, 265B, 266A, and 266B) are housed in the fan room and provide ventilation to Fire Areas CB-1, CB-2, CB-6, and CT-1 (tunnel). In the event of a fire in the fan room, all four fans are assumed lost and portable ventilation equipment will be used to provide ventilation for the control building. Fire dampers are not necessary in the two vertical shafts because of the vertical separation of over 40 ft between the fan room and cable tunnel

and the small size of the shaft opening. Air-operated dampers (2HVC*AOD201A,201B,202A,202B,204A, and

204B) are used to control the air temperature in the control building by modulating recirculation and outside air. Since the fans 2HVC*FN266A,266B,265A, and 265B are assumed to be lost in a fire, the dampers will not be required to function and, therefore, are not protected.

Cables associated with safe shutdown located in this fire area have been identified and evaluated. Redundant trains of safe shutdown circuitry are located in this area. Alternate shutdown

capability has been provided for this area.

9.5A.1.3.9.2 Methods of Suppression/Detection

The primary fire suppression system for this area (except the fan room, el 773'-6") is an automatic or manual, double capacity, total flooding CO system. Hose rack stations and portable fire extinguishers provide backup. Fire detection is provided by the early warning fire detection system which provides fire alarms locally and in the control room. The COsystem is designed to attain a 50-percent concentration as recommended for cable fires (NFPA-12). Automatic actuation of

the CO system is provided by the "XL-3" fire detection system which is a "Priority" system with local and control room alarms. The alarms enable the control room to be aware of the status and availability of the CO system at all times.

BVPS-2 UFSAR Rev. 12 9.5A-39 The fan room is provided with portable fire extinguishers and hose racks. Fire detection is provided by the early warning fire detection system which provides fire alarms locally and in the control room. The fire loading analysis determined a fire severity of less than 3 hours. The walls and doors are 3-hour fire rated and exceed the minimum barrier requirements. A review of the perimeter penetrations of this fire area determined that the fire dampers are not necessary in the ductwork which penetrates the partial wall between CT-1 and CB-2 since it is part of the same fire area. Ductwork penetrating the perimeter walls of CT-1, CB-2, and CB-1 from adjacent fire areas is equipped with two 1 1/2-hour fire-rated dampers in series. The postulated fire for this area is the ignition of safety-related cabling. The flame-resistant, fire-retardant properties

of the cable insulation, automatic CO suppression system, and local hose rack stations determine that a fire in this area will be controlled and extinguished within the area. 9.5A.1.3.9.3 Safe Shutdown Summary

Purple powered components (in addition to white and yellow channel equipment) are assumed to be lost as a consequence of a fire in Area CT-1. Orange powered components, in addition to selected components powered from the black diesel, are utilized to achieve shutdown. Cables required for shutdown from the ASP are adequately protected in place by a fire-wrap material. The

fire in Area CT-1 could potentially lead to a control room evacuation in the event of loss of plant control. Plant shutdown would, therefore, be achieved by the alternate shutdown

method. 9.5A.1.3.9.4 Deviation from BTP CMEB 9.5-1

a. C.5.a(4) Modified fire dampers

b. C.5.e(2) CO vs. water in cable rooms. (CO is the primary fixed suppression system instead of water.)

c. C.7.c Cable Spreading Room

BVPS-2 UFSAR Rev. 15 9.5A-40 - CO vs water (same as above)

- Aisle separation less than 3'x 8' 
- No continuous line-type heat detectors in cable trays 

d. C.5.a(5) - Modified fire doors

    - Unsupervised fire doors to area protected by gas suppression system. 

e. C.5.c(7) - Alternative or Dedicated Safe Shutdown Capability (PORV spurious operation)

BVPS-2 UFSAR Rev. 14 9.5A-41 9.5A.1.3.10 FIRE AREA CV CABLE VAULT AND ROD CONTROL AREA 9.5A.1.3.10.1 Fire Area Description

The area is separated from its redundant area, CV-2, by a 12-inch reinforced concrete wall having a 3-hour fire rating. Any penetrations of walls, ceiling, and floor have been sealed with a material having a rating equivalent to the barrier rating. The ventilation penetrations are provided with two 1 1/2-hour fire dampers in series except for the ductwork associated with the emergency switchgear ventilation supply and exhaust system traversing through this fire area which has been wrapped with a 1-hour fire-rated material.

Area CV-1 contains safety and nonsafety-related cable. Cable associated with safe shutdown located in this fire area have

been identified and evaluated. The shutdown components located in fire area CV-1 are listed in the Fire Protection Safe Shutdown Report.

All containment electrical penetration assemblies in this fire area are orange, red, blue or nonsafety (black) and are completely separated from their redundant counterparts.

9.5A.1.3.10.2 Methods of Suppression/Detection The primary fire suppression system for this area is an automatic or manual, double capacity, total flooding CO system. Hose rack stations and portable fire extinguishers provide backup. Fire detection is provided by the early warning fire detection system which provides fire alarms locally and in the control room. The CO system is designed to attain a 50-percent concentration as recommended for cable fires (NFPA-12).

Automatic actuation of the CO system is provided by the "XL-3" fire detection system which is a "Priority" system with local and control room alarms. The alarms enable the control room to

be aware of the status and availability of the CO system at all times. The postulated fire for this area is the ignition of safety-related cabling. All cables except those that run in conduit are qualified in accordance with IEEE-383-1974 for safety-related applications or similar industry testing for non-safety applications (Refer to Section 8.3.3 for further details).

BVPS-2 UFSAR Rev. 12 9.5A-42 The fire analysis for Area CV-1 determined that a 2-hour fire barrier is required. The ceiling, floor, and walls have a fire rating of 3 hours which meets the required rating. All duct penetrations are provided with two 1 1/2-hour fire dampers in series or the ductwork is wrapped with a 1-hour fire-wrap material, which is adequate when considered in conjunction with the fire suppression/detection systems for this fire area and the flame-resistant, fire-retardant properties of the cable insulation.

The area is protected by an automatic, total flooding, CO suppression system with backup hose rack stations and detection systems. Therefore, a fire in this area will be controlled and

extinguished within the area. 9.5A.1.3.10.3 Safe Shutdown Summary

Orange train (in addition to red and blue channel-related shutdown equipment) is assumed lost during a fire in Area CV-1.

Purple cables which are required for shutdown located in the area are adequately protected by a fire-wrap material. The purple and green (swing) train equipment is used to achieve

shutdown from the control room, supplemented by manual operator actions and repairs.

9.5A.1.3.10.4 Deviations from BTP CMEB 9.5-1

a. C.5.a(4) Modified fire dampers

b. C.5.a(4) Ventilation ductwork is wrapped with 1-hour fire-wrap material to extend the fire barriers in lieu of fire dampers at the barriers.

c. C.5.e(2) No line-type heat detectors installed in cable trays

d. C.5.e(2) CO is used as primary fixed suppression instead of water

e. C.5.a(5) - Modified fire doors

   - Unsupervised fire doors to area protected by gas suppression system. 

BVPS-2 UFSAR Rev. 14 9.5A-43 9.5A.1.3.11 FIRE AREA CV CABLE VAULT AND ROD CONTROL AREA 9.5A.1.3.11.1 Fire Area Description

The area is separated from its redundant area, CV-1, by a 12-inch reinforced concrete wall having a 3-hour fire rating. Any penetrations of walls, ceilings, and floors have been sealed

with a rating equivalent to the barrier rating. The ventilation penetrations between areas are provided with two 1 1/2-hour fire dampers in series.

Area CV-2 contains safety and nonsafety-related cable. Cables associated with safe shutdown located in this fire area have

been identified and evaluated. The shutdown components listed in fire area CV-2 are listed in

the Fire Protection Safe Shutdown Report. All containment electrical penetration assemblies in this area are purple, green, or nonsafety, (black) and are completely separated from their redundant counterparts.

9.5A.1.3.11.2 Methods of Suppression/Detection The primary fire suppression system for this area is an automatic or manual double capacity, total flooding, CO system. Hose rack stations and portable fire extinguishers provide

backup. Fire detection is provided by the early warning fire detection system which provides fire alarms locally and in the control room. The CO system is designed to attain a 50-percent concentration as recommended for cable fires (NFPA-12).

Automatic actuation of the CO system is provided by the "XL-3" fire detection system which is a "Priority" system with local and control room alarms. The alarms enable the control room to

be aware of the status and availability of the CO system at all times. The postulated fire for this area is the ignition of safety-related cabling. All cables which are not qualified in accordance with IEEE-383-1974 or similar flame propagation tests (Refer to Section 8.3.3 for further details) are run in conduit which limits the propagation of fire.

The ceiling, floor, and walls have a fire rating of 3 hours which meets the required rating. All duct penetrations are provided with two 1 1/2-hour fire dampers in series. The fire

dampers are adequate when considered in conjunction with the automatic suppression/detection systems for this fire area and the flame-resistant, fire-retardant properties of the cable

insulation.

BVPS-2 UFSAR Rev. 15 9.5A-44 The area is protected by an automatic, total flooding, CO suppression system with backup hose rack stations and detection systems. Therefore, a fire in this area will be controlled and

extinguished within the area. 9.5A.1.3.11.3 Safe Shutdown Summary

Purple train (in addition to yellow and white channel-related shutdown equipment) is assumed lost during a fire in Area CV-2.

The orange train equipment is used to achieve shutdown from the control room, supplemented by manual operator actions.

9.5A.1.3.11.4 Deviations from BTP CMEB 9.5-1

a. C.5.a(4) Modified fire dampers

b. C.5.e(2) No line-type heat detectors installed in cable trays

c. C.5.e(2) CO is used as primary fixed suppression instead of water

d. C.5.a(5) Unsupervised fire doors to area protected by gas suppression system.

e. C.5.b Safe Shutdown Capability (PORV spurious operation)

BVPS-2 UFSAR Rev. 14 9.5A-45 9.5A.1.3.12 FIRE AREA CV CABLE VAULT AND ROD CONTROL AREA CABLE TUNNEL 9.5A.1.3.12.1 Fire Area Description

Included within this fire area is the cable area located in the northern section of el 755 ft-6 in. of the auxiliary building. Any penetrations of walls, ceilings, and floors have been sealed with a material having a rating equivalent to the fire barrier.

Cables associated with safe shutdown located in this fire area have been identified and evaluated.

The shutdown components located in fire area CV-3 are listed in the Fire Protection Safe Shutdown Report.

All containment electrical penetration assemblies in this fire area are yellow, white, or nonsafety (black).

9.5A.1.3.12.2 Methods of Suppression/Detection The primary fire suppression system for this area is an automatic or manual, double capacity, total flooding, CO system. Hose rack stations and portable fire extinguishers provide backup. Fire detection is provided by the early warning fire detection system which provides fire alarms locally and in the control room. The CO system is designed to attain a 50-percent concentration as recommended for cable fires (NFPA-12). Automatic actuation of the CO system is provided by the "XL-3" fire detection system which is a "Priority" system with local and control room alarms. The alarms enable the control room to be aware of the status and availability of the CO system at all times. The postulated fire for this area is the ignition of safety-related cabling. All cables which are not qualified in accordance with IEEE-383-1974 or similar flame propagation tests (Refer to Section 8.3.3 for further details) are run in conduit which limits the propagation of fire.

The ceiling, floor, and walls have a fire rating of 3 hours which meets the required rating. An additional fire area within this area is CV-6, the Relay Room. The three walls between area CV-6 and area CV-3 have a rating of 2 hours discussed in Section 9.5A.1.3.15. All duct penetrations are provided with two 1 1/2-hour fire dampers in series or the ductwork is wrapped with a 1-hour fire-rated material which is adequate when considered in conjunction with the fire suppression/detection systems for this fire area and the flame-resistant, fire-retardant properties of

the cable insulation.

BVPS-2 UFSAR Rev. 15 9.5A-46 The area is protected by an automatic, total flooding, CO suppression system with backup hose rack stations and detection systems. These systems provide sufficient protection against

the loss of redundant Class 1E circuit functions. Therefore, a fire in this area will be controlled and extinguished within the area. 9.5A.1.3.12.3 Safe Shutdown Summary

Purple train (in addition to yellow and white channel-related shutdown equipment) is assumed lost during a fire in Area CV-3. Manual operator actions will be established to aid ventilation

for the emergency switchgear rooms in lieu of crediting the fire wrap installation for the electrical circuits associated with the emergency switchgear ventilation located in this area. The orange and green (swing) train equipment is used to achieve shutdown from the control room supplemented by manual operator actions and repairs.

9.5A.1.3.12.4 Deviations from BTP CMEB 9.5-1

a. C.5.a(4) Modified fire dampers

b. C.5.a(4) Ventilation ductwork wrapped with 1-hour fire-rated material in lieu of fire dampers

c. C.5.e(2) No line-type heat detectors installed in cable trays

d. C.5.e(2) CO is used as primary fixed suppression instead of water

e. C.5.a(5) - Modified fire doors

   - Unsupervised fire doors to area protected by gas suppression system. 

f. C.5.b Safe Shutdown Capability (PORV spurious operation)

BVPS-2 UFSAR Rev. 14 9.5A-47 9.5A.1.3.13 FIRE AREA CV CABLE VAULT AND ROD CONTROL AREA 9.5A.1.3.13.1 Fire Area Description

Any penetrations of the perimeter concrete walls to adjacent fire areas or buildings have been sealed with a material having a rating equivalent to the barrier rating. Ventilation penetrations of the perimeter walls to adjacent areas have been provided with two 1 1/2-hour fire-rated dampers in series.

The walls, ceiling, and floor have a fire rating in excess of that required by the fire analysis.

Cables associated with safe shutdown located in this fire area have been identified and evaluated.

The shutdown components located in fire area CV-4 are listed in the Fire Protection Safe Shutdown Report.

Emergency Switchgear Room Supply Fans (2HVZ*FN261A,B)

These fans supply air to the emergency switchgear rooms (SB-1, SB-2). These fans are axial fans and are located in the ductwork; the fans are parallel to one another, and only one fan is required for shut down.

Based on the design of the ductwork, the very low combustible loading, the fire detection system, and the manual hose racks, adequate protection is provided to prevent the spread of a fire from one fan to the other.

Emergency Switchgear Room Exhaust Fans (2HVZ*FN262A,B)

These fans are similarly designed and located as the supply

fans. Emergency Switchgear Room Ventilation Dampers (2HVZ*MOD21A,B, 22A,B, 23A,B)

The dampers operate to maintain the proper temperature in the

emergency switchgear rooms. Either Train A or B has sufficient capacity to maintain proper temperatures. The only combustibles in the areas of the dampers are the damper motors. The damper motors are totally enclosed motors in NEMA 4 enclosures which act as radiant shields. Adequate protection is provided to prevent the spread of a fire from one damper to another.

BVPS-2 UFSAR Rev. 12 9.5A-48 Based on the above, a fire in any portion of CV-4 would be controlled and extinguished within the area. 9.5A.1.3.13.2 Methods of Suppression/Detection

Fire hose racks and portable fire extinguishers are provided. Detection consists of area ionization coverage with control room and local alarms. 9.5A.1.3.13.3 Safe Shutdown Summary

Redundant components and cables for emergency switchgear ventilation Train A and Train B are located in Fire Area CV-4. Manual operator actions will be established to aid ventilation for the emergency switchgear rooms in lieu of crediting the fire wrap installation for the electrical circuits associated with the emergency switchgear ventilation located in this area. In the event of a fire in this area, the plant will be shut down from the control room using either the orange or purple train.

9.5A.1.3.13.4 Deviations from BTP CMEB 9.5-1

a. C.5.a(4)

Modified fire dampers

b. C.5.b Separation of safe shutdown components, the following components are not provided with 3-hour separation 2HVZ*MOD21A and B 2HVZ*MOD22A and B 2HVZ*MOD23A and B 2HVZ*FN261A and B 2HVZ*FN262A and B

BVPS-2 UFSAR Rev. 12 9.5A-49 9.5A.1.3.14 FIRE AREA CV CABLE VAULT AND ROD CONTROL 9.5A.1.3.14.1 Fire Area Description

This area contains no safety-related equipment. This area is separated from surrounding areas by 3-hour, fire-rated walls, floor, and ceiling. Any penetrations are sealed with a rating

equivalent to the barrier rating. Ventilation penetrations are provided with two 1 1/2-hour fire-

rated dampers in series. Cables associated with safe shutdown located in this fire area

have been identified and evaluated. 9.5A.1.3.14.2 Methods of Suppression/Detection Fire hose rack stations and portable fire extinguishers are provided. Detection consists of area ionization coverage with control room and local alarms. This area contains a minimal amount of combustible material.

The postulated fire for CV-5 is the ignition of the personnel hatch operator hydraulic oil.

Based on the design of the area, the limited amount of combustibles, the fire detection system, and manual hose racks, a fire in this area would be controlled and extinguished within

the area. 9.5A.1.3.14.3 Safe Shutdown Summary

Redundant cables for emergency switchgear ventilation Train A and Train B are located in this fire area. Manual operator actions will be established to aid ventilation for the emergency switchgear rooms in lieu of crediting the fire wrap installation for the electrical circuits associated with the emergency switchgear ventilation located in this area. In the event of a fire in CV-5, the plant will be shutdown from the control room using the orange train.

9.5A.1.3.14.4 Deviations from BTP CMEB 9.5-1

a. C.5.a(4) Modified fire dampers

b. C.5.a(5) Modified fire doors

BVPS-2 UFSAR Rev. 12 9.5A-50 9.5A.1.3.15 FIRE AREA CV CABLE VAULT AND ROD CONTROL AREA RELAY ROOM 9.5A.1.3.15.1 Fire Area Description

This area contains the relay room which is located in the northern section of el 755 ft-6 in. of the auxiliary building. The relay room is bounded by a 3 hour floor, ceiling and north wall, (adjacent to the Fuel Building). The remaining 3 walls which are common to fire area CV-3 have a fire rating of two

hours. Any penetrations of the walls, ceiling, and floor have been sealed with a material having a rating equivalent to the fire barrier.

No shutdown components are located in Fire Area CV-6.

Cables associated with safe shutdown located in this fire area have been identified and evaluated. Only purple power and control cables are routed through this area. Therefore, full

separation from the orange train has been provided. Ventilation penetrations are provided with two 1 1/2-hour fire-

rated dampers in series. 9.5A.1.3.15.2 Methods of Suppression/Detection The primary fire suppression system for this area is an automatic or manual, double capacity, total flooding, CO system. Hose rack stations and portable fire extinguishers provide backup. Fire detection is provided by the early warning fire detection system which provides fire alarms locally and in

the control room. The CO system is designed to attain a 50-percent concentration as recommended for cable fires (NFPA-12).

Automatic actuation of the CO system is provided by the "XL-3" fire detection system which is a "Priority" system with local and control room alarms. The alarms enable the control room to be aware of the status and availability of the CO system at all times. The postulated fire for this area is the ignition of safety-related cabling. All cables which are not qualified in accordance with IEEE-383-1974 or similar flame propagation tests (Refer to Section 8.3.3 for further details) are run in conduit which limits the propagation of fire.

The floor, ceiling and north wall, (adjacent to the Fuel Building), have a fire rating of 3 hours which meet the required rating. The remaining 3 walls which are common to fire area CV-3 have a fire rating of two hours. This surpasses the required

rating of 1 hour for fire areas equipped with detection and automatic suppression. The fire severity of this area has been calculated to be less than 2 hours, thus confirming the adequacy of this barrier. All duct penetrations are provided with two 1 1/2-hour fire-rated dampers in series which is adequate when considered in conjunction with the automatic suppression/detection systems for this fire area and the flame-resistant, fire-retardant properties of the cable insulation.

BVPS-2 UFSAR Rev. 11 9.5A-51 The area is protected by an automatic, total flooding, CO suppression system with backup hose rack stations and detection systems. Therefore, a fire in this area will be controlled and

extinguished within the area. 9.5A.1.3.15.3 Safe Shutdown Summary Purple train (in addition to yellow and white channel-related shutdown equipment) is assumed lost during a fire in Area CV-6. The orange and green (swing) train equipment is used to achieve shutdown from the control room.

9.5A.l.3.15.4 Deviations from BTP CMEB 9.5-1

a. C.5.a(4) Modified fire dampers

b. C.5.a(4) Ventilation penetration openings (two 1 1/2-hour fire-rated dampers in series)

c. C.5.a(5) Unsupervised fire doors to area protected by gas suppression system.

BVPS-2 UFSAR Rev. 14 9.5A-52 9.5A.1.3.16 FIRE AREA DG DIESEL GENERATOR CUBICLE (ORANGE) 9.5A.1.3.16.1 Fire Area Description

The diesel generator building is designed as a missile-proof structure with perimeter walls and roof constructed of 2-foot-thick reinforced concrete. The interface wall between the diesel generator cubicles is constructed of 2-foot-thick reinforced concrete.

Penetrations of exterior and interior walls forming the fire barriers are sealed with a material having a rating equivalent to the barrier rating except for the intake and exhaust openings which are separated by sufficient distance to preclude the possibility of fire propagation. There are no ventilation penetrations traversing between cubicles. The intake and exhaust openings provide no possibility of allowing a fire in one diesel generator cubicle to propagate into the other cubicle. Cables associated with safe shutdown located in this fire area have been identified and evaluated.

The shutdown components located in fire area DG-1 are listed in the Fire Protection Safe Shutdown Report.

The diesel generators, including respective associated starting equipment and other auxiliaries, are physically and electrically

isolated from each other. 9.5A.1.3.16.2 Methods of Suppression/Detection

The primary fire suppression system for this area is an automatic or manual, double capacity, total flooding, CO system. Hose rack stations and portable fire extinguishers provide backup. Fire detection is provided by the early warning fire detection system which provides fire alarms locally and in

the control room. The CO system is designed to attain a 34-percent concentration as recommended for surface fires (oil fires) by NFPA-12. Automatic actuation of the CO system is provided by heat detectors with local and control room alarms. The alarms enable the control room to be aware of the status and availability of

the CO system at all times.

BVPS-2 UFSAR Rev. 11 9.5A-53 A set of heat detectors with temperature settings below the heat detectors used to actuate the CO system have been provided to shut down the ventilation system before CO is discharged. The floor drain system for the diesel generator cubicles is routed to an oil separator before being discharged to the storm sewer system, thus precluding the possibilities of spreading fires to any other plant area. The fuel oil day tanks are provided with a curb to prevent the

fuel oil from spreading throughout the cubicles area. The postulated fire for this fire area is a break in a diesel fuel oil line with the diesel running which causes ignition of the fuel oil. The CO system along with the fire barrier separating the two fire areas would limit the fire to only one fire area; therefore, the remaining diesel would be available. The diesel fuel oil storage tanks are located beneath the diesel building; one under each diesel room. The tanks are separated from the diesel building by a minimum of 3 feet of reinforced concrete. The only access to the tanks is a manhole for each tank, located in the diesel room vestibules. Based on the location of the tanks, no special protection has been provided

for the tanks. A fire in this area will be controlled and extinguished within

the area. 9.5A.1.3.16.3 Safe Shutdown Summary

Fire Area DG-1 contains emergency diesel generator 2EGS*EG2-1. Orange train (in addition to red and blue channel-related shutdown equipment) is assumed lost during a fire in this area. Purple train equipment is utilized to achieve shutdown from the main control room.

9.5A.1.3.16.4 Deviation from BTP CMEB 9.5-1

a. C.5.a(5) Modified fire doors Unsupervised fire door to area protected by gas suppression system.

b. C.6.a(l) General area detection not provided on Elevation 759'-0"

BVPS-2 UFSAR Rev. 14 9.5A-54 9.5A.1.3.17 FIRE AREA DG DIESEL GENERATOR CUBICLE (PURPLE) 9.5A.1.3.17.1 Fire Area Description

The diesel generator building is designed as a missile-proof structure with perimeter walls and roof constructed of 2-foot-thick reinforced concrete. The interface wall between the

redundant diesel generator cubicles is constructed of 2-foot-thick reinforced concrete.

Penetrations of exterior and interior walls forming the fire barriers are sealed with a material having a rating equivalent to the barrier rating except for the intake and exhaust openings which are separated by sufficient distance to preclude the possibility of fire propagation. There are no ventilation penetrations traversing between cubicles. The intake and exhaust openings provide no possibility of allowing a fire in one diesel generator cubicle to propagate into the other cubicle. No fire hazards exist in the area of the exterior

nonfire-rated door of the west wall. Cables associated with safe shutdown located in this fire area

have been identified and evaluated. The shutdown components located in fire area DG-2 are listed in the Fire Protection Safe Shutdown Report.

The diesel generators, including respective associated starting equipment and other auxiliaries, are physically and electrically isolated from each other.

9.5A.1.3.17.2 Methods of Suppression/Detection The primary fire suppression system for this area is an automatic or manual, double capacity, total flooding, CO system. Hose rack stations and portable fire extinguishers provide backup. Fire detection is provided by the early warning fire detection system which provides fire alarm locally and in the control room. The CO system is designed to attain a 34-percent concentration as recommended for surface fires (oil fire) by NFPA-12. Automatic actuation of the CO system is provided by heat detectors with local

BVPS-2 UFSAR Rev. 11 9.5A-55 and control room alarms. The alarms enable the control room to be aware of the status and availability of the CO system at all times.

A set of heat detectors with temperature settings below the heat

detectors used to actuate the CO system have been provided to shut down the ventilation system before CO is discharged. The floor drain system for the diesel generator cubicles is routed to an oil separator before being discharged to the storm sewer system, thus precluding the possibilities of spreading fires to any other plant area. The fuel oil day tanks are provided with a curb to prevent the

fuel oil from spreading throughout the cubicles area. The postulated fire for this fire area is a break in a diesel fuel oil line with the diesel running which causes ignition of the fuel oil. The CO system along with the fire barrier separating the two fire areas would limit the fire to only one fire area; therefore, the remaining diesel would be available. The diesel fuel oil storage tanks are located beneath the diesel building; one under each diesel room. The tanks are separated from the diesel building by a minimum of 3 feet of reinforced concrete. The only access to the tanks is a manhole for each tank, located in the diesel room vestibules. Based on the location of the tanks, no special protection has been provided

for the tanks. A fire in this area will be controlled and extinguished within

the area. 9.5A.1.3.17.3 Safe Shutdown Summary

Fire Area DG-2 contains emergency diesel generator 2EGS*EG2-2. Purple train (in addition to white and yellow channel-related shutdown equipment) is assumed lost during a fire in this area. Orange train equipment is utilized to achieve shutdown from the main control room.

9.5A.1.3.17.4 Deviation from BTP CMEB 9.5-1

a. C.5.a(5) Modified fire doors Unsupervised fire door to area protected by gas suppression system.

b. C.6.a(6) General area detection not provided on Elevation 759'-0" BVPS-2 UFSAR Rev. 12 9.5A-56 9.5A.1.3.18 FIRE AREA FB FUEL AND DECONTAMINATION BUILDING 9.5A.1.3.18.1 Fire Area Description All penetrations of the reinforced concrete south wall to the primary auxiliary building have been sealed with a material having a rating equivalent to the barrier rating. The ventilation penetration between this area and the reactor containment contiguous area (CV-1) has been provided with two 1 1/2-hour fire dampers in series. This is the only ventilation penetration between the fuel/decontamination building and the adjacent buildings.

No shutdown components or cables are installed in this fire area. A charcoal filtration system (Fire Zone FB-lA), located in the decontamination area, exhausts air from the decontamination building. The charcoal filter is protected by a manually

operated water spray fire protection system. Heat detectors signal an alarm in the control building. Loss of this filter due to a fire would not affect the safe shutdown.

9.5A.1.3.18.2 Methods of Suppression/Detection

Due to the extremely low fire loading and the fact the fuel pools are normally full of water, smoke detection is provided only at the fuel pool cooling pumps and in the charcoal filter. Interior hose racks and portable fire extinguishers are provided. Additional coverage is provided by yard hydrants or hose racks and portable extinguishers within the adjacent primary auxiliary

building.

A fire in this fire area will be controlled and extinguished within the area.

9.5A.1.3.18.3 Safe Shutdown Summary

Plant shutdown can be achieved with any orange and/or purple powered components from the main control room. A fire in FB-1 does not affect any safe shutdown components or cables.

9.5A.1.3.18.4 Deviations from BTP CMEB 9.5-1

a. C.5.a (4) Modified fire dampers

BVPS-2 UFSAR Rev. 0 9.5A-57 b. C.5.a (4) Fire dampers located outside fire wall and the ductwork portion wrapped with a 1-hour fire-rated material.

c. C.7.k Fuel pool cooling pumps

d. C.5.a(5) Modified fire doors

BVPS-2 UFSAR Rev. 12 9.5A-58 9.5A.1.3.19 FIRE AREA IS INTAKE STRUCTURE 9.5A.1.3.19.1 Fire Area Description

Fire Area IS-2 contains the "swing" service water pump (2SWS*P21C). The barriers that comprise the perimeter of this area consist of reinforced concrete walls and slabs with a minimum thickness of 18 inches. All door openings between other cubicles have 3-hour fire-rated doors. All penetrations of intercompartment walls are sealed with a material having a rating equivalent to the fire barrier. This area contains equipment for both BVPS-1 and BVPS-2.

A 12-inch-wide slot exists in the ceiling of this cubicle for the ventilation system. This slot will not allow a fire to spread to other areas. There are no ventilation penetrations

between IS-2 and adjacent areas. No components or cables located in this area are required for

plant shutdown. 9.5A.1.3.19.2 Methods of Suppression/Detection Early warning detection and control room alarm is provided by BVPS-1 for IS-2. Hose racks and portable fire extinguishers are provided outside the cubicles. Fire suppression by water can also be gained by utilizing the outside hose headers test connections.

The postulated fire for IS-2 is a fire in the service water pump. Based on the existing fire loading, fire detection which alarms in the common control room, manual hose stations and 3-hour fire-rated walls, the fire would be contained within the cubicle. 9.5A.1.3.19.3 Safe Shutdown Summary

Plant shutdown can be achieved with either orange or purple power components from the main control room.

9.5A.1.3.19.4 Deviations from BTP CMEB 9.5-1 None

BVPS-2 UFSAR Rev. 14 9.5A-59 9.5A.1.3.20 FIRE AREA IS INTAKE STRUCTURE 9.5A.1.3.20.1 Fire Area Description

This area contains the Train B service water pump. The area is comprised of reinforced concrete walls and a floor slab with a minimum thickness of 18 inches. All doors leading to adjacent

areas have a 3-hour fire rating. This area contains equipment for both BVPS-1 and BVPS-2.

A 12-inch wide slot exists in the ceiling of this pump cubicle for the ventilation system. This slot will not allow a fire in one cubicle to propagate to another. All penetrations of intercompartment walls are sealed with a material having a rating equivalent to the fire barrier. There are no ventilation penetrations between IS-3 and adjacent cubicles.

The shutdown components located in fire area IS-3 are listed in the Fire Protection Safe Shutdown Report.

Power and control cables enter this area from duct lines. All Class 1E and non-Class 1E circuits within this area are routed

in conduit. The two emergency MCCs are fed from separate emergency 480 V

substations and enter the cubicles from a duct line. Cables associated with safe shutdown located in this fire area

have been identified and evaluated. 9.5A.1.3.20.2 Methods of Suppression/Detection

Early warning detection and control room alarm is provided by BVPS-1 for IS-3. Hose racks and portable fire extinguishers are provided outside the cubicles. Fire suppression by water can also be gained by utilizing the outside hose headers test connections.

The postulated fire for IS-3 is a fire in the service water pump. Based on the existing fire loading, fire detection which

alarms in the common control room, manual hose stations, and 3-hour fire-rated walls, the fire would be contained within the cubicle. As a result of redundancy and separation, a loss of availability of one service water pump would not affect the ability to achieve safe shutdown. Availability of the alternate intake structure, which provides total redundancy for BVPS-2

service water pumps in an isolated structure approximately 1,800 feet upstream, provides the capability to achieve safe shutdown on loss of this entire structure.

BVPS-2 UFSAR Rev. 12 9.5A-60 9.5A.1.3.20.3 Safe Shutdown Summary Fire Area IS-3 contains the Train B service water pump. This

pump is assumed lost and subsequently renders the purple emergency diesel generator unavailable. The purple train (in addition to white and yellow channel-related shutdown equipment) is assumed lost during a fire in this area. Orange train equipment is utilized to achieve shutdown from the main control room, supplemented by manual operator actions.

9.5A.1.3.20.4 Deviations from BTP CMEB 9.5-1

None BVPS-2 UFSAR Rev. 14 9.5A-61 9.5A.1.3.21 FIRE AREA IS INTAKE STRUCTURE 9.5A.1.3.21.1 Fire Area Description

This area contains the Train A service water pump. The area is comprised of reinforced concrete walls and a floor slab with a minimum thickness of 18 inches. All doors leading to adjacent

areas have a 3-hour fire rating. This area contains equipment for both BVPS-1 and BVPS-2.

A 12-inch-wide slot exists in the ceiling of this pump cubicle for the ventilation system. This slot will not allow a fire in one cubicle to spread to another. All penetrations of intercompartment walls are sealed with a material having a rating equivalent to the fire barrier. There are no ventilation penetrations between IS-4 and adjacent areas.

The shutdown components located in fire area IS-4 are listed in the Fire Protection Safe Shutdown Report.

Power and control cables enter this area from duct lines. All Class 1E and non-Class 1E circuits within this area are routed

in conduit. The two emergency MCCs are fed from separate emergency 480 V

substations and enter the cubicles from a duct line. Cables associated with safe shutdown located in this fire area

have been identified and evaluated. 9.5A.1.3.21.2 Methods of Suppression/Detection

Detection and control room alarm is provided by BVPS-1 for IS-4. Hose racks and portable fire extinguishers are provided outside the cubicles. Fire suppression by water can also be gained by utilizing the outside hose headers test connections that are normally used for fire pump performance testing and system

flushing. The postulated fire in IS-4 occurs in the fire pump, fuel oil tank which also disables the diesel-driven fire pump. The motor-driven fire pump is located in IS-1 which is over 40 feet away and separated from IS-4 by IS-2 and IS-3. A fire in IS-4 would not impair the operation of the motor-driven fire pump and, therefore, manual hose station would be available and the fire limited to IS-4. As a result of the redundancy and

separation, a loss of availability of one

BVPS-2 UFSAR Rev. 0 9.5A-62 service water pump would not affect the ability to achieve safe shutdown. Availability of the alternate intake structure, which provides total redundancy for BVPS-2 service water pumps in an isolated structure approximately 1,800 feet upstream, provides

the capability to achieve safe shutdown on the loss of this entire structure.

A fire in this area will be controlled and extinguished within the area.

9.5A.1.3.21.3 Safe Shutdown Summary Fire Area IS-4 contains the Train A service water pump. This

pump is assumed lost and subsequently renders the orange emergency diesel generator unavailable. The orange train (in addition to red and blue channel-related shutdown equipment) is assumed lost during a fire in this area. Purple train equipment is utilized to achieve shutdown from the main control room, supplemented by manual operator actions.

9.5A.1.3.21.4 Deviations from BTP CMEB 9.5-1

None BVPS-2 UFSAR Rev. 14 9.5A-63 9.5A.1.3.22 FIRE AREA MS MAIN STEAM VALVE AREA 9.5A.1.3.22.1 Fire Area Description

All penetrations of the concrete wall and floor to adjacent fire areas have been sealed with a material having a rating equivalent to the barrier rating.

The shutdown components located in fire area MS-1 are listed in the Fire Protection Safe Shutdown Report.

The main steam valve area houses the main steam isolation valves, atmospheric steam dump valves, residual heat release

valve, and main feedwater isolation valves. The main steam isolation valves are required to isolate the steam generators from the turbine and to provide pressure boundary integrity. The atmospheric steam dump and residual heat release valves are used to control reactor plant cooldown by controlling steam flow to the atmosphere from the steam generators. The steam dump valves are electro-hydraulic operated and close on loss of electrical power or control

signal. The steam dump valves are separated from each other by 15 feet and a 2-foot-thick partial buttress wall which extends at least 2 feet beyond the valves. The dump valves are located about 20 feet above the main concrete floor. The main steam isolation valves are separated by approximately 15 feet and are approximately 15 feet above the floor.

The main feedwater isolation valves are electro-hydraulic operated. These valves are required to isolate the steam generators.

All cables within this area are enclosed in conduit; therefore, they are not considered as part of the fire loading.

Cables associated with safe shutdown located in this fire area have been identified and evaluated.

BVPS-2 UFSAR Rev. 12 9.5A-64 The postulated fire for this area is the rupture and subsequent ignition of the total inventory of hydraulic fluid for one feedwater steam isolation valve operator. The fire analysis for this area determined that a fire barrier of less than 1/2 hour is required. The walls and floor have a fire rating of 3 hours which exceeds that required by the fire analysis. All penetrations of the concrete walls and floor to adjacent fire areas have been sealed with a material having a rating equivalent to the barrier rating with the exception of the

ceiling which goes out to the roof area where combustibles or fire hazards would not be present.

9.5A.1.3.22.2 Methods of Suppression/Detection The hose rack stations and portable fire extinguishers are

provided. Detection is provided by ionization coverage with local and control room alarms.

Based on the elevation of the main steam isolation valves and steam dump valves above the feedwater isolation valves, the high flash point of the oil, the low combustible loading, the manual hose racks, and ionization detectors, the integrity of the main steam valves would not be impaired. In the event one steam dump valve would be rendered inoperable, at least two would be

available (minimum required for cooldown). Therefore, a fire in this area will be controlled and

extinguished within the area without preventing safe shutdown. 9.5A.1.3.22.3 Safe Shutdown Summary

A fire in Area MS-1 will not jeopardize either the orange or purple power trains outside of MS-1. Plant shutdown can be achieved from the main control room supplemented by manual operator actions.

9.5A.1.3.22.4 Deviations from BTP CMEB 9.5-1

a. C.5.b Safe shutdown components not separated by 3-hour barrier (2SVS*PCV101A, B, and C, 2SVS*HCV104, 2MSS*AOV101A, B, and C)

BVPS-2 UFSAR Rev. 14 9.5A-65 9.5A.1.3.23 FIRE AREA PA AUXILIARY BUILDING GENERAL AREA 9.5A.1.3.23.1 Fire Area Description

Fire area PA-3 consists of el 710 ft-6 in., 718 ft-6 in., and 735 ft-6 in. of the primary auxiliary building and the degasifier cubicle on El 755 ft-6 in.

All penetrations of the perimeter concrete walls to adjacent fire areas or buildings have been sealed with a material having a rating equivalent to the barrier rating. Any ventilation penetrations of the walls to adjacent fire areas have been provided with two 1 l/2-hour fire dampers in series except as

noted in Section 9.5A.2, Item C.5.a(4). Cables associated with safe shutdown located in this fire area

have been identified and evaluated. The shutdown components located in fire area PA-3 are listed in the Fire Protection Safe Shutdown Report.

BVPS-2 UFSAR Rev. 12 9.5A-66 Auxiliary Building Emergency Exhaust 2HVP*MOD21A (-O) 2HVP*MOD21B (-P)

Due to the pressure relief requirements for a high energy line break, the sliding steel fire door separating PA-3 from PA-4 on el 755 ft-6 in. is held open and is provided with fusible-links

for automatic closure in the event of a fire. The fire analysis for this area determined that a fire barrier of 1 hour is required. The walls, ceiling, and floor have a fire rating of 3 hours which exceeds the required ratings. In order to perform a fire hazards analysis of this fire area, the area was further divided into fire zones. These fire zones (PA-3A, 3B, 3C, 3D, 3E, and 3F) were analyzed separately because of the configuration and importance of the equipment.

Cables associated with safe shutdown located in this fire area have been identified and evaluated.

The primary auxiliary building (PA-3) contains the following safety-related equipment:

1. Charging pumps (Zones PA-3A, 3B, 3C)

2. Component cooling water pumps (Zones PA-3D, 3E, 3F)

3. Portions of piping and valves of the chemical volume control and letdown systems.

Charging Pump Cubicles (Zones PA-3A, 3B, and 3C) Each pump is located in an individual cubicle with 2-ft-thick reinforced concrete side walls and a 2-ft-thick removable concrete backwall with a small opening at the top for the crane access rail to pass through. The back wall consists of removable block to facilitate removal of a charging pump for

maintenance. The east wall of each cubicle is a 2-ft-thick concrete wall and has a labyrinth-type opening for radiation protection. This opening provides ventilation to the charging pump. Ventilation penetrations for the charging pump cubicles are provided with 1 l/2-hour fire dampers. A curb is provided in each opening to contain any oil spills within the cubicle. Each cubicle is provided with a drain to prevent the accumulation of spilled oil. The fire loading in the cubicle is less than 1/2 hour. Due to the configuration of the cubicle, the

curbed floor, oil drainage system, fire detection system and manual hose racks, a fire in any one cubicle would be controlled and extinguished within the cubicle.

BVPS-2 UFSAR Rev. 13 9.5A-67 A fire was also postulated outside the charging pump cubicles along the eastern side of the cubicles. The only combustible materials in this area are the electrical cables in cable trays overhead along the east wall of the auxiliary building. All the cables, except those run in conduit are IEEE-383-1974 or similarly rated cables. (Refer to Section 8.3.3 for further details.) Based on the type of cable, the labyrinth-type design

of the opening into the cubicles, the 20 feet distance between the openings, the fire detection system and manual hose stations, a fire in front of the charging cubicles would not spread to more than one cubicle. This ensures that a charging pump would be available for shutdown.

Component Cooling Water Pumps (Zones PA-3D, 3E, 3F)

The component cooling water pumps are located in the northeast corner of el 735 ft-6 in. The component cooling water pumps supply cooling water to various primary plant components. During shutdown, they provide a heat sink for the residual heat removal system. Only one pump is required for shutdown. The only appreciable combustible loading within 20 diagonal feet of the coolant pumps are the pumps themselves (1/2 gal of lube oil

and the motor insulation for each pump). The component cooling water pumps are arranged so that the "A" pump is separated from the "B" pump by a distance of 24 ft with the "C" pump (swing pump) in between. The component cooling water pumps are protected by a preaction spray system. The system is actuated by heat detectors and the pipe is air supervised for reliability. Thus, there is sufficient protection for these pumps from any postulated fire in the area.

Piping and Valves for Chemical Volume Control and Letdown Systems The chemical volume control and letdown systems are required for safe shutdown. The charging pump suction valves 2CHS*LCV115B and D, 1CHS*MOV350, and 2CHS*FCV113A, which are located on el 710 ft-6 in., are not separated by a fire barrier. This configuration has been documented and justified in Section 9.5A.2. The area is out of normal plant travel routes, has a low combustible loading (<1 hr) and the cables for 2CHS*LCV115D have been adequately protected with a fire-wrap material. The only combustibles within the adjacent area (within 20 feet) are the motor operators on the valves. The motors are totally enclosed and a total burnout of one motor would not affect the operation of the other motor. The valves can also be operated

manually if required. 9.5A.1.3.23.2 Methods of Suppression/Detection

Fire hose rack stations and portable fire extinguishers are located in the area. Detection consists of area ionization

coverage (early warning system) with control room and local alarms. The component cooling water pumps are protected by a preaction spray system actuated by a rate-compensated heat

detection system.

BVPS-2 UFSAR Rev. 12 9.5A-68 9.5A.1.3.23.3 Safe Shutdown Summary Both orange and purple shutdown components and associated cables are located in Fire Area PA-3. Both trains are utilized for shutdown for various fire scenarios from the control room supplemented with manual operator actions. Protection is

provided for both orange and purple cables. 9.5A.1.3.23.4 Deviations from BTP CMEB 9.5-1

a. C.5.b 3-hour barriers between redundant components (Charging pumps, component cooling water

pumps, charging pump suction source isolation values) b. C.5.e(2) Concentrated cable tray areas where primary suppression is manual hose stations

c. C.5.a(4) Modified fire dampers

d. C.5.a(4) Fire damper installed outside of fire wall with 1-hour fire wrap

e. C.5.e(2) Cable trays do not have continuous line-type heat detectors

f. C.5.a(5) Modified fire doors

g. C.6.a(1) General area detection not provided in all areas of el 710 feet 6 inches and el 718 feet 6 inches

h. C.5.b Safe shutdown cables protected by a fire wrap material.

BVPS-2 UFSAR Rev. 12 9.5A-69 9.5A.1.3.24 FIRE AREA PA PRIMARY AUXILIARY BUILDING EL 755 FT.-6 IN. 9.5A.1.3.24.1 Fire Area Description

Ventilation penetrations of the concrete walls to adjacent fire areas have been provided with two 1 1/2-hour fire dampers in series except as noted in Section 9.5A.2, Item C.5.a(4). Due to the pressure relief requirements for a high energy line

break, the rolling steel fire door separating PA-3 from PA-4 is normally held open but is provided with fusible links for automatic closure in the event of a fire.

Cables associated with safe shutdown located in this fire area have been identified and evaluated.

The fire analysis for this area determined that a fire barrier of 1 hour is required. The walls, ceiling, and floor have a

fire rating of 3 hours, which exceeds the required rating except as noted in Section 9.5A.2, Item C.5.a(4).

Within PA-4 are two motor control center rooms which are separated by 3-hour fire-rated barriers; (Fire Areas PA-6 and PA-7). These areas are discussed in Sections 9.5A.1.3.26 and

27. The primary auxiliary building (PA-4) contains the following major safety-related equipment:

1. Boric acid transfer pumps (2CHS*P22A,B)

2. Boric acid storage tanks (2CHS*TK21A,B)

3. Chemical volume control tank (2CHS*TK22)

4. Charging pump emergency exhaust fans (2HVP*FN264A,B)

Boric Acid Transfer Pumps Each pump is located within an individual cubicle with 2-foot-thick reinforced concrete walls. The west wall of each cubicle has a labyrinth-type opening for missile and radiation protection. This opening provides ventilation to the boric acid transfer pumps. The combustible loading in each cubicle is the transfer pump motor and associated cables. The postulated fire for a boric acid transfer pump cubicle is a fire in the motor. Based on the design of the cubicles, the low combustible loading, the fire detection system, and manual hose racks, a fire in either cubicle would be controlled and extinguished within the cubicle.

BVPS-2 UFSAR Rev. 12 9.5A-70 Boric Acid Storage Tanks Each tank is located within an individual cubicle with 2-foot-thick reinforced concrete walls. The south wall of each cubicle

has a labyrinth-type opening for access to the cubicle. The combustible loading in the cubicle is the cabling for

instrumentation associated with the tanks, which is negligible. The postulated fire for a boric acid transfer tank cubicle is a

cable fire. Based on the design of the cubicles, the low combustible

loading, the fire detection system and manual hose racks, a fire in either cubicle would be controlled and extinguished within the cubicle.

Chemical Volume Control Tank The control tank is located in a cubicle with 2-foot-thick reinforced concrete walls. The south wall has a labyrinth-type opening for access to the cubicle.

The combustible loading in the cubicle is the cabling for instrumentation associated with the tank.

The postulated fire for the control tank is a cable fire.

Based on the design of the cubicle, the low combustible loading, the fire detection system and manual hose racks, a fire in the cubicle would be controlled and extinguished within the cubicle.

Charging Pump Emergency Exhaust Fans The exhaust fans are located in the northwest corner of the auxiliary building in a cubicle created by the arrangement of equipment and layout of other cubicles. The fans are axial fans and are totally contained within the ductwork. The only combustible materials within 20 feet of the fans are cable trays located along the east wall of the cubicle. All cables, except those which run in conduit, are IEEE-383-1974 or similarly rated cables (Refer to Section 8.3.3 for further details). Based on the design and layout of the area, the type of cable, the fact the fans are located inside the ductwork, a fire in the area would not affect the fans. Loss of both fans has been analyzed and determined that manual actions would be necessary to provide

temporary charging pump ventilation within 24 hours. 9.5A.1.3.24.2 Methods of Suppression/Detection

Fire hose rack stations and portable fire extinguishers are provided. Detection consists of area ionization coverage with control room and local alarms.

BVPS-2 UFSAR Rev. 8 9.5A-71 9.5A.1.3.24.3 Safe Shutdown Summary Cables associated with both orange and purple shutdown components are routed through fire area PA-4. Orange powered component cables are adequately protected in this area with a fire-wrap material. Shutdown is demonstrated using active components powered from the orange train. For a postulated fire

in the "A" boric acid transfer pump cubicle, the "B" (purple) boric acid transfer pump would be available. Shutdown will be achieved from the control room supplemented by manual operator

actions. 9.5A.1.3.24.4 Deviations from BTP CMEB 9.5-1

a. C.5.a(4) Modified fire dampers

b. C.5.a(4) Fire dampers located outside fire barrier with duct protected by 1-hour fire wrap

c. C.5.b Boric acid transfer pump and boric acid transfer tank (3-hour barrier separation

between redundant components)

d. C.5.b Charging pump emergency exhaust fan separation

e. C.5.b Safe shutdown cables protected with a fire-wrap material

f. C.5.a(5) Modified fire doors

g. C.5.d(5) Hydrogen piping is Seismic Category II

BVPS-2 UFSAR Rev. 16 9.5A-72 9.5A.1.3.25 FIRE AREA PA PRIMARY AUXILIARY BUILDING El 773'6" 9.5A.1.3.25.1 Fire Area Description

Penetrations of the perimeter concrete block walls have been sealed with a rating equivalent to the barrier rating.

Ventilation penetrations of the perimeter to adjacent areas have been provided with two 1 l/2-hour fire dampers in series except as noted in Deviations below.

The primary auxiliary building contains the supplemental leak collection filter banks (Zones PA-5A, 5B, 5C, and 5D). Of the four charcoal filter banks, two operate continuously and two are on standby.

The filters are located in 2-foot-thick concrete enclosures, two filters in each enclosure. For personnel access, a labyrinth-type opening on the north and south ends are provided.

Due to the low combustible fire loading in the area and the concrete filter enclosures, the structural steel supporting the

fire barriers was not fireproofed. Cable associated with safe shutdown located in this fire area

have been identified and evaluated. 9.5A.1.3.25.2 Methods of Suppression/Detection

Fire hose rack stations and portable fire extinguishers are provided. Detection consists of area ionization coverage to

alarm locally and in the control room. Each of the supplementary leak collection filter banks (Zones PA-5A, 5B, 5C, and 5D) is protected by a manually operated water spray system and is provided with heat-actuated line-type

detectors (thermistor cable). These detectors alarm locally and in the control room. Based on the above, a fire in this area would be controlled and extinguished within the immediate area.

9.5A.1.3.25.3 Safe Shutdown Summary A fire in PA-5 causes loss of instrument air. Plant shutdown capability is demonstrated utilizing orange powered components and achieved from the main control room.

BVPS-2 UFSAR Rev. 16 9.5A-73 9.5A.1.3.25.4 Deviations from BTP CMEB 9.5-1

a. C.5.a(4) Modified fire dampers

b. C.5.a(4) Fire dampers located outside fire barrier with duct protected by l-hour fire wrap

c. C.5.a(l) Structural steel not fireproofed

d. C.5.a(5) Modified fire doors

e. C.6.a(l) General area detection not provided in Component Cooling Surge Tank Cubicle

f. C.5.a(4) Non-rated damper to SB-5 was evaluated under Generic Letter 86-10.

BVPS-2 UFSAR Rev. 14 9.5A-74 9.5A.1.3.26 FIRE AREA PA MOTOR CONTROL CENTER ROOM (ORANGE) 9.5A.1.3.26.1 Fire Area Description

This area is separated from PA-4 and its redundant counterpart (PA-7) by 3-hour fire-rated walls and ceilings which exceed the required rating. All penetrations are sealed with a material

having a rating equivalent to the barrier rating. Cables associated with safe shutdown located in this fire area

have been identified and evaluated. The shutdown component located in fire area PA-6 is listed in the Fire Protection Safe Shutdown Report.

9.5A.1.3.26.2 Methods of Suppression/Detection

Fire hose rack stations and portable fire extinguishers are provided. Detection consists of area ionization coverage with

control room and local alarms. Based on the design of the area, the low combustible loading, the fire detection systems and portable fire extinguishers with manual hose rack backup, a fire would be controlled and extinguished within the area.

9.5A.1.3.26.3 Safe Shutdown Summary

Fire Area PA-6 contains MCC*2-E03, which powers several orange train components within the charging, service water, and component cooling water systems. Only components associated

with the MCC are assumed lost. The unaffected purple train equipment is used to achieve shutdown from the control room supplemented by manual operator actions.

9.5A.l.3.26.4 Deviations from BTP CMEB 9.5-1

None BVPS-2 UFSAR Rev. 14 9.5A-75 9.5A.1.3.27 FIRE AREA PA MOTOR CONTROL CENTER ROOM (PURPLE) 9.5A.1.3.27.1 Fire Area Description

This area is separated from PA-4 and its redundant counterpart (PA-6) by 3-hour fire-rated walls and ceilings which exceed the required rating. All penetrations are sealed with a material

having a rating equivalent to the barrier rating. Cables associated with safe shutdown located in this fire area

have been identified and evaluated. The shutdown components located in fire area PA-7 are listed in the Fire Protection Safe Shutdown Report.

9.5A.1.3.27.2 Methods of Suppression/Detection

Fire hose rack stations and portable fire extinguishers are provided. Detection consists of area ionization coverage with

control room and local alarms. Based on the design of the area, the low combustible loading, the fire detection systems, and portable fire extinguishers with manual hose rack backup, a fire would be controlled and extinguished within the area.

9.5A.1.3.27.3 Safe Shutdown Summary

Fire Area PA-7 contains MCC*2-E04, which powers several purple train components within the charging, service water, and component cooling water systems. Only components associated

with the MCC are assumed lost. The unaffected orange train equipment is used to achieve shutdown from the control room supplemented by manual operator actions.

9.5A.1.3.27.4 Deviations from BTP CMEB 9.5-1

None BVPS-2 UFSAR Rev. 15 9.5A-76 9.5A.1.3.28 FIRE AREA PT PIPE TUNNEL 9.5A.1.3.28.1 Fire Area Description

The fire analysis for this area determined that there are virtually no combustibles in this area (all cables are run in conduit). The walls, ceiling, and floor have a fire rating of 3

hours. Penetrations are sealed with a rating equivalent to the barrier rating. Ventilation penetrations of the perimeter walls and ceilings to adjacent fire areas are provided with two 1 1/2-

hour fire dampers in series. Cables associated with safe shutdown located in this fire area

have been identified and evaluated. The shutdown components located in fire area PT-1 are listed in

the Fire Protection Safe Shutdown Report.

BVPS-2 UFSAR Rev. 18 9.5A-77 The containment isolation service water valves (2SWS*MOV160, 161, 162, 163, 164, 165, 166, and 167) are used to isolate service water for reactor containment ventilation on a

containment isolation signal.

The containment isolation component cooling water valves

(2CCP*MOV150-1, 151-1, 156-1, and 157-1) are used to isolate component cooling water to containment on a containment

isolation signal.

The charging system valve (2CHS*MOV289) is used to isolate

charging on a safety injection signal, while valves 2CHS*MOV308A, B, and C require manual operation to isolate

charging.

The letdown valve (2CHS*AOV204) is used to isolate normal

letdown on a containment isolation signal.

The safety injection valves (2SIS*MOV867D, 840, and HCV868A) are used under accident conditions to provide borated water to the

reactor coolant system.

9.5A.1.3.28.2 Methods of Suppression/Detection

Fire hose rack stations and portable fire extinguishers are provided. Detection consists of area ionization coverage with control room and local alarms. Based on the existing configuration, the fire protection provided and the low

combustible loading, a fire in this area would be controlled and

extinguished within the area.

9.5A.1.3.28.3 Safe Shutdown Summary

The purple train (in addition to white and yellow channel-related shutdown equipment) is assumed lost during a fire in Area PT-1. Orange and green (swing) train equipment is used to achieve shutdown from the control room supplemented by manual

operator actions.

9.5A.1.3.28.4 Deviations from BTP CMEB 9.5-1

a. C.5.a(4) Modified fire dampers

b. C.6.a(l) General area detection not provided in pipe trench BVPS-2 UFSAR Rev. 18 9.5A-78 9.5A.1.3.29 REACTOR CONTAINMENT (RC-1)

9.5A.1.3.29.1 Fire Area Description

The containment structure perimeter consists of a 10-foot

concrete mat, with 4 ft-6 in. thick reinforced concrete walls to the dome. The dome is a minimum thickness of 2 feet-6 in. of reinforced concrete. A continuous steel liner is provided on the entire interior for assuring leak tightness of the

structure.

Cables associated with safe shutdown located in this fire area

have been identified and evaluated.

The shutdown components located in fire area RC-1 are listed in

the Fire Protection Safe Shutdown Report.

In order to perform a fire hazards analysis for this structure, areas of major fire potential within the containment were

identified. The areas identified and analyzed were:

1. Reactor coolant pumps, steam generators, and reactor coolant piping

2. General area cabling

3. DELETED

4. Cable penetration areas

5. Residual heat removal pumps

6. Pressurizer

BVPS-2 UFSAR Rev. 18 9.5A-79 Reactor Coolant Pumps (2RCS*P21A, 21B, 21C; Fire Zones RC-lC, lD, lE) The three reactor coolant pumps, steam generators, and piping

associated with each reactor coolant loop are separated from each other at various levels by reinforced concrete walls and distance. This constitutes sufficient separation to prevent a fire from spreading from one steam generator cubicle to another steam generator cubicle. Oil collection systems have been installed for the reactor coolant pump lubricating oil system. A fire in any portion of the oil collection system could be postulated to result in loss of the respective reactor coolant

pump. This would not affect the ability to achieve shutdown since shutdown can be attained without the availability of any of these pumps. Steel lube oil storage drain tanks, one for each reactor coolant pump, are provided to accommodate the

lubricating oil collection system.

General Area Cabling

The separation between redundant safety-related cables is

defined in Section 8.3 under general plant areas.

Protection for redundant safe shutdown cables inside containment is provided by placing cables in conduits and by a separation of

20-feet minimum horizontal distance where possible.

Fire hose rack stations and portable extinguishers throughout the containment provide the necessary fire suppression for the

containment area.

BVPS-2 UFSAR Rev. 18 9.5A-80 Cable Penetration - Class 1E (Orange and Purple) (Fire Zones RC-1F and RC-1G) The Class 1E (orange) and Class 1E (purple) cable penetrations

are required to attain shutdown. The Class 1E (orange) and Class 1E (purple) cable penetrations are located in the annular area between the concrete crane wall and the outside concrete

wall of the reactor containment.

Photo-electric smoke detectors (early warning detection system)

are provided for both Class 1E (orange) and Class 1E (purple) cable penetrations and will actuate an alarm in the control

room.

Heat actuators are provided to actuate the deluge valves to alarm in the control room. Subsequently, control room operator action is required to open the corresponding containment isolation valve and release water to the spray systems provided

for the purple and orange cable penetration areas.

Residual Heat Removal Pumps 2RHS*P21A and 21B

The two residual heat removal pumps are separated by a distance

of approximately 3 feet.

Each residual heat removal pump is protected by an open head

deluge spray system. The deluge spray is actuated by heat

detectors and is automatic in nature with the exception of the containment isolation valve which is operated from the control

room. The heat detectors also provide alarms in the control

room.

Photo-electric smoke detectors (early warning detection system)

provide fire alarms in the control room.

Pressurizer

The major combustibles in the area are the pressurizer heater cables. A fire in these heater cables was postulated and it was determined, based on separation of the pressurizer cubicle that the fire would be limited to the pressurizer area and would not be of sufficient size to damage the pressurizer itself. In the

event the pressurizer heaters are lost, the plant can still be

shut down safely.

9.5A.1.3.29.2 Methods of Suppression/Detection

Fire hose rack stations and portable fire extinguishers are located throughout the containment. Also included are deluge water spray systems for protection of the residual heat removal pumps, and the orange and purple cable penetrations.

As discussed above, early warning fire detection has been

provided for the RHR pumps and cable penetration areas.

BVPS-2 UFSAR Rev. 20 9.5A-81 9.5A.1.3.29.3 Safe Shutdown Summary

Due to compartmentalized arrangement for the reactor containment, the lack of transient combustibles during normal

operation, and the fire detection and suppression systems, a

fire would be limited to an individual compartment. The plant

would be shut down using the unaffected equipment in the area

from the control room, supplemented by manual operator actions.

9.5A.1.3.29.4 Deviations from BTP CMEB 9.5-1

a. C.5.b Safe shutdown components not separated by 3-hour barrier

  - RHR pumps and valves    - Component cooling water valves to RHR     heat exchangers 
  - Cable penetration area (orange and purple)    - Process instrumentation (steam generator level, pressurizer level, RCS hot leg temperature, and nuclear instruments)    - Reactor coolant system letdown    - Reactor coolant system depressurization/high-low pressure interface 

b. C.5.e(2) Concentrated cable trays without automatic suppression

c. C.7.a(1)(c) No general area detection for containment

d. C.5.a(5) Nonlisted fire door (personnel hatch)

BVPS-2 UFSAR Rev. 14 9.5A-82 9.5A.1.3.30 FIRE AREA SB EMERGENCY SWITCHGEAR ROOM (ORANGE) 9.5A.1.3.30.1 Fire Area Description

The building construction provides fire barriers in excess of the required ratings determined by the fire loadings. All penetrations of walls and ceiling are sealed with a material having a rating equivalent to the barrier rating. Ventilation penetrations are provided with two 1 1/2-hour fire dampers in series. The ventilation ductwork for the battery room exhaust system is protected with a l-hour fire-rated material instead of installing fire dampers in the floor between SB-1 and SB-3 in order for the system to provide continuous operation.

Fire Area SB-1 contains the orange safety-related 4 kV switchgear, and 480 V substation which supplies power to Class

1E circuits required for safe shutdown. Battery rooms SB-6 and SB-7 are located within SB-1. Each battery room is a separate fire area with 3-hour fire-rated barriers. (See Sections

9.5A.1.3.35 and 36.) Cables associated with safe shutdown located in this fire area

have been identified and evaluated: The shutdown components located in fire area SB-1 are listed in the Fire Protection Safe Shutdown Report.

9.5A.1.3.30.2 Methods of Suppression/Detection

Fire hose rack stations and portable fire extinguishers are located within SB-1. Detection consists of area ionization

coverage with control room and local alarms. With the 3-hour barriers, ionization smoke detection, fire

extinguishers and local hose racks, a fire in SB-1 will be controlled and extinguished within the area.

9.5A.1.3.30.3 Safe Shutdown Summary Fire Area SB-1 contains the orange power emergency buses. The orange train (in addition to red and blue channel-related shutdown equipment) is assumed lost during a fire in this area. Purple train equipment is utilized to achieve shutdown from the

main control room supplemented with manual operator actions.

BVPS-2 UFSAR Rev. 15 9.5A-83 9.5A.1.3.30.4 Deviations from BTP CMEB 9.5-1

a. C.5.a(4) Modified fire dampers

b. C.5.a(4) Ventilation ductwork protected by 1-hour fire-rated wrap vs. installing fire dampers at the barrier.

c. C.5.a(5) Modified fire doors

d. C.5.b Safe Shutdown Capability (PORV spurious operation)

BVPS-2 UFSAR Rev. 14 9.5A-84 9.5A.1.3.31 FIRE AREA SB EMERGENCY SWITCHGEAR ROOM (PURPLE) 9.5A.1.3.31.1 Fire Area Description

The building construction provides fire barriers in excess of the required ratings determined by the fire loadings. All penetrations of walls and ceiling are sealed with a material having a rating equivalent to the barrier rating. Ventilation penetrations are provided with two 1 1/2-hour fire dampers in series. The ventilation ductwork for the battery room exhaust system is protected with a l-hour fire-rated material instead of installing fire dampers in the floor between SB-2 and SB-3 in order for the system to provide continuous operation.

Fire Area SB-2 contains the purple safety-related 4 kV switchgear and 480 V substation which supplies power to Class 1E

circuits required for safe shutdown. Battery rooms SB-8 and SB-9 are located within SB-2. Each battery room is a separate fire area with 3-hour fire-rated barriers. (See Sections 9.5A.1.3.37

and 38.) Cables associated with safe shutdown located in this fire area

have been identified and evaluated. The shutdown components located in fire area SB-2 are listed in the Fire Protection Safe Shutdown Report.

9.5A.1.3.31.2 Methods of Suppression/Detection

Fire hose rack stations and portable fire extinguishers are located within SB-2. Detection consists of area ionization

coverage with control room and local alarms. With the 3-hour barriers, ionization smoke detection, portable fire extinguishers, and local hose racks, a fire in SB-2 will be controlled and extinguished within the area.

9.5A.1.3.31.3 Safe Shutdown Summary Fire Area SB-2 contains the purple power emergency buses. The purple train (in addition to white and yellow channel-related shutdown equipment) is assumed lost during a fire in this area.

BVPS-2 UFSAR Rev. 15 9.5A-85 Orange train equipment is utilized to achieve shutdown from the main control room supplemented by manual operator actions. 9.5A.1.3.31.4 Deviations from BTP CMEB 9.5-1

a. C.5.a(4) Modified fire dampers

b. C.5.a(4) Ventilation ductwork protected by l-hour fire- rated wrap vs. installing fire dampers

at the barrier.

c. C.5.a(5) Modified fire doors

d. C.5.b Safe Shutdown Capability (PORV spurious operation)

BVPS-2 UFSAR Rev. 12 9.5A-86 9.5A.1.3.32 FIRE AREA SB SERVICE BUILDING CABLE TRAY AREA 9.5A.1.3.32.1 Fire Area Description

Any penetrations of floors, walls, and ceiling will be sealed with a rating equivalent to the barrier rating.

Ductwork running between the battery room exhaust fans in Area CV-4 and the battery rooms SB-6, SB-7, SB-8, and SB-9 pass through this area. Also passing through this area is the

ductwork running between the emergency switchgear area ventilation equipment room in the contiguous fire area CV-4 and the emergency switchgear areas, SB-1 and SB-2. This ductwork has been wrapped with a l-hour fire-rated material. The ventilation penetrations on the perimeter of this area are provided with two 1 1/2-hour fire dampers in series.

Cables associated with safe shutdown located in this fire area

have been identified and evaluated.

There are no shutdown components located in SB-3.

9.5A.1.3.32.2 Methods of Suppression/Detection The primary fire suppression system for this area is an automatic or manual double capacity, total flooding, CO system. Hose rack stations and portable fire extinguishers provide backup. Fire detection is provided by the early warning fire detection system which provides fire alarms locally and in the

control room. The CO system is designed to attain a 50-percent concentration as recommended for cable fires (NFPA-12). Automatic actuation

of the CO system is provided by the "XL-3" fire detection system which is a "Priority" system with local and control room alarms. The alarms enable the control room to be aware of the status and availability of the CO system at all times. The 3-hour fire barriers consisting of the walls, floors, ceiling slab, and doors are in excess of the required rating

determined by the fire loading analysis. The postulated fire for this area is the ignition of safety-related cabling. The flame-resistant, fire-retardant properties of the cable insulation, automatic COsuppression system, fire hose rack stations, and detection system, provides adequate protection against loss of redundant Class 1E circuit functions.

BVPS-2 UFSAR Rev. 15 9.5A-87 Based on the above, a fire in this area will be controlled and extinguished within the area. 9.5A.1.3.32.3 Safe Shutdown Summary

Both orange and purple power trains traverse SB-3. Most of the orange train is in conduit, and will be protected. Shutdown is

accomplished using only orange train powered equipment from the control room supplemented by manual operator actions. Cables required for shutdown are adequately protected in place by a

fire-wrap material. Alternate shutdown capability from the ASP is provided for transfer of the EDG controls for a fire in SB-3 to isolate the voltage regulator and tachometer circuits routed

in SB-3. 9.5A.1.3.32.4 Deviations from BTP CMEB 9.5-1

a. C.5.a(4) Modified fire dampers

b. C.5.a(4) Fire damper extends 2 inches above fire barrier (ceiling of SB-3).

c. C.5.a(4) Ventilation ductwork protected by 1-hour fire-rated wrap vs. installing fire dampers at the

barrier. d. C.5.a(2) Primary fixed fire suppression system is CO instead of water.

e. C.5.e(2) Cable trays do not have continuous line-type heat detectors.

f. C.5.a(5) Modified fire doors

g. C.5.b Safe Shutdown Capability (PORV spurious operation)

BVPS-2 UFSAR Rev. 13 9.5A-88 9.5A.1.3.33 FIRE AREA SB NORMAL SWITCHGEAR ROOM 9.5A.1.3.33.1 Fire Area Description

Only safe shutdown cables are located within the fire area. Safe shutdown components are not located in this fire area.

The building construction provides fire barriers in excess of the required ratings determined by the fire loading.

All penetrations of the walls, floor, and ceiling are sealed with a material having a rating equivalent to the barrier rating. Ventilation duct penetrations between SB-4 and all adjacent fire areas are provided with two 1 1/2-hour fire-rated dampers in series except for the ductwork associated with the battery room exhaust system which is wrapped with a 1-hour fire-

rated material. Nonsafety-related 4,160 V switchgear and 480 V substations and relay panels are located in this fire area. Battery room SB-10 is located in the fire area and enclosed in a 3-hour fire-rated barrier. (See Section 9.5A.1.3.39.)

The postulated fire for this area is an electrical fire in the 4,160 V switchgear which will be contained within the fire area.

Cable associated with safe shutdown located in this fire area have been identified and evaluated.

9.5A.1.3.33.2 Methods of Suppression/Detection

Fire hose rack stations and portable fire extinguishers are located in the area with additional portable extinguishers available in adjacent areas. Detection consists of area

ionization coverage with control room and local alarms. 9.5A.1.3.33.3 Safe Shutdown Summary

The orange and green (swing) train equipment with some black diesel supplied components is used to achieve shutdown from the main control room supplemented by manual operator actions. Orange cables required for shutdown are adequately protected by a fire-wrap material. Alternate shutdown capability from the ASP is provided for monitoring the RCS cold leg temperature and main steam pressure, and the ventilation control for 2HVD*FN270A and 271A for DG-1. 9.5A.1.3.33.4 Deviations from BTP CMEB 9.5-1

a. C.5.a(4) Modified fire dampers

BVPS-2 UFSAR Rev. 13 9.5A-89 b. C.5.a(4) Fire damper extends 2 inches above fire barrier (floor of SB-4).

c. C.5.a(4) Ventilation ductwork protected by 1-hour fire-rated wrap vs. installing fire dampers at the

barrier. d. C.5.b Safe shutdown cable protected with a fire wrap material.

e. C.5.a(5) Modified fire doors.

f. C.5.b Lack of fixed automatic suppression.

BVPS-2 UFSAR Rev. 16 9.5A-90 9.5A.1.3.34 FIRE AREA SB SERVICE BUILDING ELEVATION 780 FT-6 IN. 9.5A.1.3.34.1 Fire Area Description

The building construction provides fire barriers in excess of the required ratings determined by the fire loading. Penetrations of walls and floor are sealed with a rating equivalent to the barrier rating. A deluge water curtain is provided in the main steam pipe chase to prevent the spread of a fire between this area and the turbine building (TB-1). Ventilation duct penetrations are provided with two 1 l/2-hour fire dampers in series except as noted in Deviations below. Due to the low combustible fire loading, the structural steel supporting the fire barriers was not fireproofed.

Cables associated with safe shutdown located in this fire area have been identified and evaluated.

The shutdown components located in fire area SB-5 are listed in the Fire Protection Safe Shutdown Report.

9.5A.1.3.34.2 Methods of Suppression/Detection

Fire hose rack stations and portable fire extinguishers are located in the area. Detection consists of area ionization smoke detection coverage with control room and local alarms.

Based on the above, a fire in this area will be controlled and extinguished within the area.

9.5A.1.3.34.3 Safe Shutdown Summary

The only safe shutdown components affected by a fire in fire area SB-5 are those associated with main feedwater isolation Train B. All other safe shutdown components and associated cables are unaffected and available for shutdown. These valves fail safe (closed) and, therefore, would not affect safe shutdown.

BVPS-2 UFSAR Rev. 16 9.5A-91 9.5A.1.3.34.4 Deviations from BTP CMEB 9.5-1

a. C.5.a(4) Modified fire dampers

b. C.5.a(4) Fire dampers not installed in fire barrier are protected with l-hour fire-rated wrap vs. 3-hour.

c. C.5.a(1) Structural steel not fireproofed.

d. C.5.a(5) Modified fire doors

e. C.5.a(4) Non-rated damper to PA-5 was evaluated under Generic Letter 86-10.

BVPS-2 UFSAR Rev. 14 9.5A-92 9.5A.1.3.35 FIRE AREA SB BATTERY ROOM 2-1, ELEVATION 730 FT-6 IN 9.5A.1.3.35.1 Fire Area Description

Battery room (fire area) SB-6 is entirely contained within Fire Area SB-1.

The battery room is enclosed by 3-hour rated walls and ceiling. This room is constantly purged using the battery room exhaust system to prevent the possible buildup of hydrogen gas. Ventilation duct penetrations to adjacent fire areas are provided with two 1 1/2-hour fire dampers in series. All penetrations of walls and floor are sealed with a material having a rating equivalent to the barrier rating.

Cables associated with safe shutdown located in this fire area have been identified and evaluated.

The shutdown component(s) located in fire area SB-6 are listed in the Fire Protection Safe Shutdown Report.

9.5A.1.3.35.2 Methods of Suppression/Detection Fire hose rack stations and portable fire extinguishers are provided. Detection consists of area ionization (early warning system) coverage with control room and local alarms.

Based on the above, a fire will be controlled and extinguished within the area.

9.5A.1.3.35.3 Safe Shutdown Summary Fire Area SB-6 contains station battery BAT*2-1. The assumed

loss of this battery coincident with the loss of offsite power will prevent automatic start of the orange diesel. Therefore, the orange train (in addition to red and blue channel-related shutdown equipment) is assumed lost during a fire in this area. Purple train equipment is utilized to achieve shutdown from the main control room supplemented by manual operator actions.

9.5A.1.3.35.4 Deviations from BTP CMEB 9.5-1

a. C.5.a(4) Modified fire dampers

b. C.5.a(5) Modified fire door

BVPS-2 UFSAR Rev. 14 9.5A-93 9.5A.1.3.36 FIRE AREA SB BATTERY ROOM 2-3 9.5A.1.3.36.1 Fire Area Description

Battery room 2-3 (fire area SB-7) is entirely contained within Fire Area SB-1.

This battery room is enclosed by 3-hour rated walls and ceiling. This room is constantly purged using the battery room exhaust system to prevent the possible buildup of hydrogen gas.

Ventilation duct penetrations to adjacent fire areas are provided with two 1 1/2-hour fire dampers in series. All penetrations of walls and floors are sealed with a material

having a rating equivalent to the barrier rating. Cables associated with safe shutdown located in this fire area

have been identified and evaluated. The shutdown components located in fire area SB-7 are listed in the Fire Protection Safe Shutdown Report.

9.5A.1.3.36.2 Methods of Suppression/Detection

Fire hose rack stations and portable fire extinguishers are provided. Detection consists of area ionization (early warning

system) coverage with control room and local alarms. A fire will be controlled and extinguished within the area.

9.5A.1.3.36.3 Safe Shutdown Summary A fire in Area SB-7 will render station battery BAT*2-3 inoperable. This subsequently causes the loss of all components associated with PNL*DC2-19, which is normally powered by BAT*2-3. Loss of this battery will cause the momentary loss of blue channel components associated with UPS*VITBS2-3 while the orange diesel starts during the assumed loss of offsite power. These blue channel components are powered from an ac source via an

inverter. The loss of power to PNL*DC2-19 renders 2SIS*HCV868A and 2RCS*HCV250A inoperable. This causes the loss of charging Train C and letdown Train B, respectively. All other shutdown components and paths are available. The plant is shut down with

orange and/or purple power from the main control room. 9.5A.1.3.36.4 Deviations from BTP CMEB 9.5-1

a. C.5.a(4) Modified fire dampers

b. C.5.a(5) Modified fire door

BVPS-2 UFSAR Rev. 14 9.5A-94 9.5A.1.3.37 FIRE AREA SB BATTERY ROOM 2-2, ELEVATION 730 FT-6 IN.

9.5A.1.3.37.1 Fire Area Description

SB-8 contains safety-related station battery BAT*2-2. Battery room (fire area) SB-8 is entirely contained within Fire Area SB-

2. The battery room is enclosed by 3-hour rated walls and ceiling.

This room is constantly purged using the battery room exhaust system to prevent the possible buildup of hydrogen gas. Ventilation duct penetrations to adjacent fire areas are

provided with two 1 1/2-hour fire dampers in series. All penetrations of walls and floor are sealed with a material having a rating equivalent to the barrier rating.

Cables associated with safe shutdown located in this fire area have been identified and evaluated.

The shutdown component(s) located in fire area SB-8 are listed in the Fire Protection Safe Shutdown Report.

9.5A.1.3.37.2 Methods of Suppression/Detection

Fire hose rack stations and portable fire extinguishers are provided. Detection consists of area ionization (early warning system) coverage with control room and local alarms.

Based on the above, a fire will be controlled and extinguished within the area.

9.5A.1.3.37.3 Safe Shutdown Summary

Fire Area SB-8 contains station battery BAT*2-2. The assumed loss of this battery coincident with the loss of offsite power will prevent automatic start of the purple diesel. Therefore, the purple train (in addition to white and yellow channel-related shutdown equipment) is assumed lost during a fire in this area. Orange train equipment is utilized to achieve shutdown from the main control room supplemented by manual operator actions.

9.5A.1.3.37.4 Deviation from BTP CMEB 9.5-1

a. C.5.a(4) Modified fire dampers

b. C.5.a(5) Modified fire door

BVPS-2 UFSAR Rev. 14 9.5A-95 9.5A.1.3.38 FIRE AREA SB BATTERY ROOM 2-4 9.5A.1.3.38.1 Fire Area Description

Battery room 2-4 (fire area) SB-9 is entirely contained within Fire Area SB-2.

This battery room is enclosed by 3-hour rated walls and ceiling. This room is constantly purged using the battery room exhaust system to prevent the possible buildup of hydrogen gas.

Ventilation duct penetrations to adjacent fire areas are provided with two 1 1/2-hour fire dampers in series. All penetrations of walls and floor are sealed with a material

having a rating equivalent to the barrier rating. Cables associated with safe shutdown located in this fire area

have been identified and evaluated. The shutdown component(s) located in fire area SB-9 are listed in the Fire Protection Safe Shutdown Report.

9.5A.1.3.38.2 Methods of Suppression/Detection

Fire hose rack stations and portable fire extinguishers are provided. Detection consists of area ionization (early warning

system) coverage with control room and local alarms. A fire will be controlled and extinguished within the area.

9.5A.1.3.38.3 Safe Shutdown Summary

A fire in Area SB-9 will render station battery BAT*2-4 inoperable. This subsequently causes the loss of all components associated with PNL*DC2-20, which is normally powered by BAT*2-

4. Loss of this battery will cause the momentary loss of the yellow channel components associated with UPS*VITBS2-4 while the purple diesel starts during the assumed loss of offsite power.

These yellow channel components are powered from an ac source via an inverter.

The loss of power to PNL*DC2-20 renders 2SIS*HCV868B and 2RCS*HCV250B inoperable. This causes the loss of charging Train B and letdown Train C, respectively. All other shutdown

components and trains are available. The plant is shut down with orange and/or purple power from the main control room.

9.5A.1.3.38.4 Deviation from BTP CMEB 9.5-1

a. C.5.a(4) Modified fire dampers

b. C.5.a(5) Modified fire door

BVPS-2 UFSAR Rev. 12 9.5A-96 9.5A.1.3.39 FIRE AREA SB NONSAFETY BATTERY ROOM 9.5A.1.3.39.1 Fire Area Description

Battery room SB-10 located within Fire Area SB-4 contains only nonsafety-related batteries. No shutdown components or cable is

affected.

This battery room is enclosed by 3-hour rated walls and ceiling, and is constantly purged using the battery room exhaust system to prevent the possible buildup of hydrogen gas. Ventilation duct penetrations to adjacent fire areas are provided with two 1 1/2-hour fire dampers in series. All penetrations of walls and

floor are sealed with a material having a rating equivalent to the barrier rating. 9.5A.1.3.39.2 Methods of Suppression/Detection Fire hose rack stations and portable fire extinguishers are provided. Detection consists of area ionization (early warning system) coverage with control room and local alarms.

A fire will be controlled and extinguished within this area. 9.5A.1.3.39.3 Safe Shutdown Summary

No shutdown components or cable are located in the area. Shutdown can be achieved from the control room using normal

methods. 9.5A.1.3.39.4 Deviation from BTP CMEB 9.5-1

a. C.5.a(4) Modified fire dampers

BVPS-2 UFSAR Rev. 14 9.5A-97 9.5A.1.3.40 FIRE AREA SG-1N - NORTH SAFEGUARDS AREA 9.5A.1.3.40.1 Fire Area Description

The area is separated from its redundant area (SG-1S) by a 3-hour barrier. However, at E1. 690'-11", where the fire loading is insignificant, there are unsealed manway openings permitting

passage between the SG-1N and the SG-1S area. All penetrations of the perimeter to adjacent fire areas have

been sealed with a material having a rating equivalent to the barrier rating, the only exception being the unsealed personnel manway openings at E1. 690'-11". Ventilation penetrations between SG-1N, its redundant counterpart (SG-1S), and adjacent areas are provided with two 1 1/2-hour fire dampers in series.

Cable associated with safe shutdown located in this fire area have been identified and evaluated.

The shutdown components located in fire area SG-1N are listed in the Fire Protection Safe Shutdown Report.

9.5A.1.3.40.2 Methods of Suppression/Detection Fire hose rack stations and portable fire extinguishers are provided. Automatic water deluge spray system is provided for each of the auxiliary feedwater pumps.

Area detection consists of area ionization coverage with control room and local alarms. The auxiliary feedwater pump also has rate-compensated detectors providing actuation of the deluge

water spray system with control room and local alarms. Auxiliary feedwater pump 2FWE*P23B is used to maintain steam

generator level and remove reactor decay heat. The following postulated fires were evaluated for this area:

1. Postulated ignition of safety-related cabling. Redundant safety-related cable separation, in conjunction with the pre-retardant characteristics of cable, would limit the propagation of a fire to one train of redundant cabling.

2. Rupture and ignition of the lubricating oil system associated with motor-driven auxiliary feedwater pump 2FWE*P23B. The two motor-driven auxiliary feedwater

pumps are separated by a 3-hour fire wall.

BVPS-2 UFSAR Rev. 19 9.5A-98 The fire suppression and detection systems provide the required fire protection for control and extinguishment of a fire in this

area.

9.5A.1.3.40.3 Safe Shutdown Summary

Safe shutdown capability with a fire in this area is described in the Fire Protection Safe Shutdown Report.

9.5A.1.3.40.4 Deviation from BTP CMEB 9.5-1

a. C.5.a(5) Modified fire doors

b. C.6.a(1) General area detection not provided in recirculation spray pump cubicles nor in the

hydrogen recombiner cubicles.

BVPS-2 UFSAR Rev. 14 9.5A-99 9.5A.1.3.41 FIRE AREA SG-1S - SOUTH SAFEGUARDS AREA 9.5A.1.3.41.1 Fire Area Description

The area is separated from its redundant area (SG-1N) by a 3-hour barrier. However, at El. 690'-11", where the fire loading is insignificant, there are unsealed personnel manway openings

permitting passage between the SG-1N and the SG-1S areas. All penetrations of the perimeter to adjacent fire areas have

been sealed with a material having a rating equivalent to the barrier rating, the only exception being the unsealed personnel manway openings at El. 690'-11". Ventilation penetrations between SG-1S, its redundant counterpart (SG-1N), and adjacent areas are provided with two 1 1/2-hour fire dampers in series.

Cables associated with safe shutdown located in this fire area have been identified and evaluated.

The shutdown components located in fire area SG-1S are listed in the Fire Protection Safe Shutdown Report.

9.5A.1.3.41.2 Methods of Suppression/Detection Fire hose rack stations and portable fire extinguishers are

located in each area. Automatic water deluge spray systems are provided for each of the auxiliary feedwater pumps.

Area detection consists of area ionization coverage with control room and local alarms. The auxiliary feedwater pump also has rate- compensated detectors providing actuation of the deluge

water spray system, with control room and local alarms. The motor-driven auxiliary feedwater pump 2FWE*P23A and the steam- driven auxiliary feedwater pump 2FWE*P22 are used to maintain steam generator level and remove decay heat by adding feedwater to the steam generators.

Auxiliary feedwater pumps 2FWE*P22 and 23A are partially separated by a stairwell enclosure which does not extend across the full width of the building. The stairwell provides 18 ft separation between the

BVPS-2 UFSAR Rev. 17 9.5A-101 9.5A.1.3.42 FIRE AREA TB TURBINE BUILDING

9.5A.1.3.42.1 Fire Area Description

Ventilation penetrations of the perimeter walls to adjacent fire

areas are provided with two 1 1/2-hour fire dampers in series.

The shutdown components located in fire area TB-1 are listed in

the Fire Protection Safe Shutdown Report.

No special protection has been provided for the station service

air compressors since the plant can be shut down without station air following a fire in TB-1.

9.5A.1.3.42.2 Methods of Suppression/Detection

General Area

The fire suppression systems provided for the general area and for the significant hazards within the turbine building eliminate any possible effect on adjacent safety-related areas

due to a fire in this building.

An automatic wet pipe sprinkler system is installed under the

operating and mezzanine floors of the turbine building which

alarms in the control room and provides an audible outside water

alarm. The system is monitored for abnormal positioning of any sprinkler header isolation valve from the full open position. If this condition existed, an alarm displays in the control room. Backup suppression capability consists of interior hose

racks and portable fire extinguishers. Three-hour fire barriers

separate the turbine building from all safety-related areas with the exception of the entrance to the condensate polishing

building (CP-1) pipe tunnel.

An automatic water spray deluge water curtain is provided at the entrance to the condensate polishing pipe tunnel (west wall el 730 ft-6 in.) to prevent a fire from spreading from the turbine building into the condensate polishing building (CP-1). This deluge spray system was installed because of the congestion of

piping in the area. The deluge spray system is automatically actuated by rate-compensated heat detectors that alarm locally

and in the control room.

A pair of thermal detectors are mounted at the standby enclosure discharge louvers for the Diesel Driven Instrument Air Compressor. The detector(s) are interlocked with the standby emergency stop circuit to immediately secure the diesel. These detectors stop the fuel pump, stop the fan driven air flow through the enclosure, and send an alarm signal to actuate remote alarms in the main control room.

BVPS-2 UFSAR Rev. 13 9.5A-102 The construction, fire suppression, and alarms provide the capability for early detection and total suppression of any fire

in this area and preclude fire propagation to safety-related areas. Turbine Oil Reservoir and Coolers (TB-1A)

This equipment is located on the turbine building basement slab. This equipment is not required for attaining safe shutdown. A reinforced concrete curb is provided in this area. Any oil spilled, or water associated with the water spray deluge system, is carried away via a sump pit to a 30,000 gal. underground storage tank. This assures that oil will not accumulate, and prevents oil from spreading beyond the curbed area.

A 2-hour fire-rated partial wall separates the turbine oil reservoir from the turbine building railroad bay. This prevents

a fire in the railroad bay from affecting the turbine oil reservoir.

This area is provided with a heat detector actuated automatic water spray deluge system. The supervision, alarms and status of the deluge system are provided on a local control panel with

annunciation in the control room. Backup suppression capability consists of interior hose racks and portable fire extinguishers.

Hydrogen Seal Oil Unit (TB-1B)

This equipment is located on the turbine building basement slab. This equipment is not required for attaining a safe shutdown. A concrete curb is provided in this area. Any oil spilled, or water associated with the water spray deluge system, is carried

to an oil separator before being discharged to the storm sewer system. This assures that oil will not spread beyond the curbed area. This area is provided with a heat detector actuated automatic water spray deluge system. The supervision, alarms, and status of the deluge systems are provided on a local control panel with annunciation in the control room. Backup suppression capability consists of interior hose racks and portable fire extinguishers.

BVPS-2 UFSAR Rev. 13 9.5A-103 Turbine Generator (TB-lD)

This fire zone and associated equipment are located on the turbine building operating deck. This equipment is not required in attaining safe shutdown. A separate CO main supply unit has been provided for the turbine generator. This unit is utilized as a fire suppression system and also for purging hydrogen from the generator. The hydrogen purge system cannot be operated, unless by intentional

use of a bypass, if the level of liquified CO is below the minimum required for fire suppression. The CO system has been divided into four separate areas, each protected by an individual direct application system. The CO system is actuated by rate-compensated heat detectors which also provide local and control room alarms. The CO system is supervised by local control panels which provide control room annunciation. The turbine generator system also has additional manual "spurt" pushbutton stations which discharge immediately and continuously

until the pushbutton is released. This system also utilizes an "EARLY WARNING" detection system. The early warning heat

detector is set lower than the automatic CO actuation heat detector. Actuation of any "EARLY WARNING" detector results in an alarm in the control room, thereby signaling a potential

fire. Two CO hose reel assemblies are centrally located, one on each side of the turbine generator. The hose reels extend fire suppression to those surfaces not protected by fixed means

and conserve CO for those surfaces requiring fire extinguishment. Backup suppression capability consists of

interior hose racks and portable fire extinguishers. 9.5A.1.3.42.3 Safe Shutdown Summary

The station air compressors are assumed lost during a fire in Area TB-1. Either purple or orange train equipment is used to achieve shutdown from the main control room.

9.5A.1.3.42.4 Deviations from BTP CMEB 9.5-1

a. NONE BVPS-2 UFSAR Rev. 12 9.5A-104 9.5A.1.3.43 FIRE AREA TB BATTERY ROOM TURBINE BUILDING 9.5A.1.3.43.1 Fire Area Description

Battery room Fire Area TB-2 is located within Fire Area TB-1. The building construction provides fire barriers in excess of the required ratings as determined by the fire loadings; i.e., 2-hour separation from the turbine building. The battery room contains no shutdown components or cable. The battery Bat-2-6, located in this fire area, is used to provide back-up power to

the nonsafety-related DC system. 9.5A.1.3.43.2 Methods of Suppression/Detection Fire hose rack stations and portable fire extinguishers are provided. Area detection consists of ionization coverage with control room and local alarms.

9.5A.1.3.43.3 Safe Shutdown Summary

Plant shutdown can be achieved with orange and/or purple power from the main control room following a fire in TB-2. A fire in TB-2 does not affect any shutdown components or cable.

9.5A.1.3.43.4 Deviations from BTP CMEB 9.5-1.

None BVPS-2 UFSAR Rev. 12 9.5A-105 9.5A.1.3.44 FIRE AREA WH WASTE HANDLING BUILDING (WASTE HANDLING AREA) 9.5A.1.3.44.1 Fire Area Description

The building construction provides fire barriers in excess of the required rating. Any penetrations of the perimeter concrete

walls have been sealed with a rating equivalent to the barrier requirements.

The only interface between the waste handling building and a safety-related structure is the north wall where the waste handling building abuts the primary auxiliary building. A 3-

hour fire barrier is established at this interface. There are no shutdown components or cables located in this building. The waste handling area (WH-l) contains the liquid waste handling system which is used to treat potential contaminated liquids for reuse within the plant.

9.5A.1.3.44.2 Methods of Suppression Fire hose rack stations and portable fire extinguishers provide

fire suppression for the general area of WH-1. The radwaste baler area is protected by an automatic wet pipe sprinkler system. In the event of a fire, a control room alarm and an audible outside water operated alarm would sound for the wet pipe sprinklers. The system is monitored for abnormal positioning of the sprinkler header isolation valve from the full open position. If this condition existed, an alarm displays in the control room.

A postulated fire would be capable of being controlled and extinguished within the area.

9.5A.1.3.44.3 Safe Shutdown Summary Plant shutdown can be achieved with orange and/or purple powered components from the main control room. A fire in WH-l does not affect any shutdown components or cables.

9.5A.1.3.44.4 Deviations from BTP CMEB 9.5-1 C.5.a(5) Modified fire doors

BVPS-2 UFSAR Rev. 14 9.5A-106 9.5A.1.3.45 FIRE AREA WH WASTE HANDLING BUILDING (RADIATION PROTECTION AREA) 9.5A.1.3.45.1 Fire Area Description

The building construction provides fire barriers in excess of the required rating. Any penetrations of the perimeter concrete

walls have been sealed with a rating equivalent to the barrier rating. The only interface between the waste handling building and a Category I structure occurs where the waste handling building abuts the primary auxiliary building. A 3-hour fire barrier is established at this interface. Ventilation penetrations of the walls to primary auxiliary building and condensate polishing building are provided with two 1 1/2-hr fire dampers in series.

There are no shutdown components or cable located in this building.

The radiation protection area (WH-2) consists of the secondary chemical lab, the men's and women's sanitary facilities, clothes lockers, and radiation protection facilities office.

9.5A.1.3.45.2 Methods of Suppression/Detection

Fire Area WH-2 is protected by an automatic wet pipe sprinkler system. In the event of a fire, a control room alarm and an audible outside water operated alarm would sound for the wet pipe sprinklers. The system is monitored for abnormal positioning of the sprinkler header isolation valve from the

full open position. If this condition exists an alarm displays in the control room.

Fire hose rack stations and portable fire extinguishers are used as backup suppression in WH-2.

A fire can be controlled and extinguished in the area. 9.5A.1.3.45.3 Safe Shutdown Summary

Plant shutdown can be achieved with orange and/or purple powered components from the main control room. A fire in WH-2 does not

affect any shutdown components or cables.

BVPS-2 UFSAR Rev. 0 9.5A-107 9.5A.1.3.45.4 Deviations from BTP CMEB 9.5-1

a. C.5.a(4) Modified fire dampers

b. C.5.a(5) Modified fire doors

BVPS-2 UFSAR Rev. 12 9.5A-108 9.5A.1.3.46 ALTERNATE INTAKE STRUCTURE (AIS-1) This fire area is separated from the rest of the plant. The superstructure is a steel-framed structure with insulated steel siding. This structure contains equipment for BVPS-1 (WR-9A, B auxiliary river water pumps) and for BVPS-2 (2SWE-P21A, B standby service water pumps).

The alternate intake structure and equipment is provided in the

event of the complete loss of the intake structure and is, therefore, not required for shutdown. The yard hydrant system and portable fire extinguishers provide

manual suppression in the event of a fire. Based on the above, a fire in this area would be controlled and

extinguished in the area. Plant shutdown can be achieved with orange and/or purple powered components from the main control room. A fire in AIS-1 does not affect any shutdown components or cables.

BVPS-2 UFSAR Rev. 17 9.5A-109 9.5A.1.3.47 COOLING TOWER PUMP HOUSE (CTP-1) The construction provides barriers in excess of the required

ratings determined by the fire loading. The structure is also

located a distance away from safety-related buildings. The cooling tower pumps which provide cooling water to the main

condenser are not required for safe shutdown. Fire suppression is provided by portable fire extinguishers and

the yard hydrant system. Based on the above, a fire in this area would be controlled and

extinguished within the area. Plant shutdown can be achieved with orange and/or purple powered components from the main control room. A fire in CTP-1 does not affect any shutdown components or cables.

BVPS-2 UFSAR Rev. 14 9.5A-110 9.5A.1.3.48 FIRE AREA VP SERVICE WATER VALVE PIT (ORANGE) 9.5A.1.3.48.1 Fire Area Description

Valve pit VP-1 is located north of the fuel handling building, below grade, and is separated from the redundant valve pit (VP-2) by a 1-ft-thick reinforced concrete wall constituting a 3-hour fire barrier. Cable associated with safe shutdown located in this fire area

have been identified and evaluated. The shutdown components located in fire area VP-1 are listed in the Fire Protection Safe Shutdown Report.

All cabling in this area is run in conduit and, therefore, is

not considered in the fire loading. The fire analysis for this area determined a fire barrier of

<1/2 hr is required. The walls have a fire rating of 3 hours, which exceeds the required rating. Penetrations in the wall separating VP-1 and VP-2 are sealed with a 3-hour material.

9.5A.1.3.48.2 Methods of Suppression/Detection

Yard hydrants are available for fighting a fire in this area. Based on the design of the area, the low combustible loadings and the yard fire main and fire hydrants, a fire in this area would be controlled and extinguished within the area.

9.5A.1.3.48.3 Safe Shutdown Summary Fire Area VP-1 contains several service water Train A motor-operated valves and instrumentation that are required for plant shutdown. It is assumed that a fire in this area will render service water Train A unavailable. The orange emergency diesel generator, 2EGS*EG2-1, will subsequently be lost. The orange power train (in addition to red and blue channel-related shutdown equipment) is assumed lost during a fire in this area. Purple train equipment is utilized to achieve shutdown from the main control room supplemented by manual operator actions.

9.5A.1.3.48.4 Deviations from BTP CMEB 9.5-1 None

BVPS-2 UFSAR Rev. 14 9.5A-111 9.5A.1.3.49 FIRE AREA VP SERVICE WATER VALVE PIT (PURPLE) 9.5A.1.3.49.1 Fire Area Description

Valve pit VP-2 is located north of the fuel handling building, below grade, and is separated from the redundant valve pit (VP-1) by a 1-ft-thick reinforced concrete wall constituting a 3-hour fire barrier. Cables associated with safe shutdown located in this fire area

have been identified and evaluated. The shutdown components located in fire area VP-2 are listed in the Fire Protection Safe Shutdown Report.

All cabling in this area is run in conduit and, therefore, is

not considered in the fire loading. The fire analysis for this area determined a fire barrier of

<1/2 hr is required. The walls have a fire rating of 3 hours, which exceeds the required rating. Penetrations in the wall separating VP-2 and VP-1 are sealed with a 3-hour material.

9.5A.1.3.49.2 Methods of Suppression/Detection

Yard hydrants are available for fighting a fire in this area. Based on the design of the area, the low combustible loadings and the yard fire main and fire hydrants, a fire in this area would be controlled and extinguished within the area.

9.5A.1.3.49.3 Safe Shutdown Summary Fire Area VP-2 contains several service water Train B motor-operated valves and instrumentation that are required for plant shutdown. It is assumed that a fire in this area will render service water Train B unavailable. The purple emergency diesel generator, 2EGS*EG2-2, will subsequently be lost. The purple power train (in addition to white and yellow channel-related shutdown equipment) is assumed lost during a fire in this area. Orange train equipment is utilized to achieve shutdown from the main control room supplemented by manual operator actions.

9.5A.1.3.49.4 Deviations from BTP CMEB 9.5-1 None

BVPS-2 UFSAR Rev. 12 9.5A-112 9.5A.1.3.50 FIRE AREA SOB AUXILIARY BOILER AREA 9.5A.1.3.50.1 Fire Area Description

Fire Area SOB-1 contains the auxiliary boiler. SOB-1 is located in the west portion of the first two floors of the south office

shops building. The fire analysis for this area determined a

fire barrier of 1 l/2-hour is required. The auxiliary boiler area is separated from the turbine building and the remainder of the south office shops building by 3-hour fire-rated walls and floor. The ceiling has a 2-hour fire rating. Any penetrations are sealed with a rating equivalent to the barrier rating.

No shutdown components or cable is located in this fire area. 9.5A.1.3.50.2 Methods of Suppression/Detection The auxiliary boiler area is protected by a general area wet pipe sprinkler system with fire hose rack stations for backup. The sprinkler system also provides control room and local alarms. The auxiliary boilers are not required for shutdown but provide heating and processing steam when both Unit 1 and Unit 2 are in a shut down condition.

A fire can be controlled and extinguished within the area.

9.5A.1.3.50.3 Safe Shutdown Summary Plant shutdown can be achieved with orange and/or purple powered components from the main control room. A fire in SOB-1 does not affect any shutdown components or cable.

9.5A.1.3.50.4 Deviations from BTP CMEB 9.5-1 None

BVPS-2 UFSAR Rev. 13 9.5A-113 9.5A.1.3.51 FIRE AREA SOB SOSB RAILWAY BAY 9.5A.1.3.51.1 Fire Area

This area is located on the first floor of the SOSB and is used to allow railway access to the turbine building. No shutdown components or cables are located in this fire area. 9.5A.1.3.51.2 Methods of Suppression/Detection

The area is protected by a general area dry pipe sprinkler system with fire hose rack stations for backup. The sprinkler

system also provides control room and local alarms. A fire can be controlled and extinguished within the area.

The dry pipe sprinkler system and the fire rating of the area will prevent a fire in the turbine building railway bay from

propagating beyond the SOSB railway bay. 9.5A.1.3.51.3 Safe Shutdown Summary

Plant shutdown can be achieved with orange and/or purple powered components from the main control room. A fire in SOB-2 does not

affect any shutdown components or cable. 9.5A.1.3.51.4 Deviations from BTP CMEB 9.5-1

NONE BVPS-2 UFSAR Rev. 18 9.5A-114 9.5A.1.3.52 FIRE AREA SOB SOUTH OFFICE SHOPS BUILDING

9.5A.1.3.52.1 Fire Area Description

The south office shops building is a seven-story general shops and office building and, except for the auxiliary boiler (SOB-l), is not part of the production plant. SOB-3 consists of the

remainder of the SOSB (excluding SOB-1 and SOB-2). The first

and second floors contain light duty machine shops, chemical storage areas, and a lube oil storage room. The upper floors

contain general offices and locker rooms.

No shutdown components or cable is located in this area.

The fire analysis for this area determined a fire barrier of <1 hour is required. The floors of SOSB are separated by a 1 l/2-hour fire-rated floor/ceiling assembly. The SOSB is separated from the turbine building by a 3-hour rated wall assembly.

These barriers exceed the required rating.

9.5A.1.3.52.2 Methods of Suppression/Detection

The SOSB is protected by a general area sprinkler system throughout the majority of the building. A halon system provides protection in the communications room. Detection is provided by a general area detection system that senses smoke, heat, and/or flame. The detection system provides control room

and local alarms.

Fire hose rack stations and portable fire extinguishers are

provided as backup.

A fire can be controlled and extinguished within the area.

9.5A.1.3.52.3 Safe Shutdown Summary

Plant shutdown can be achieved with orange and/or purple powered components from the main control room. A fire in SOB-3 does not

affect any shutdown components or cable.

9.5A.1.3.52.4 Deviations from BTP CMEB 9.5-1

None

BVPS-2 UFSAR Rev. 15 9.5A-115 9.5A.1.3.53 FIRE AREAS TR-1/TR-2/TR-3/TR-4/TR TRANSFORMER AREAS 9.5A.1.3.53.1 Fire Area Description

The oil-filled transformers at BVPS-2 consist of the main transformer (TR-MT-2), two unit station service transformers TR-

2C and D, and two system station service transformers TR-2A and B. These are located in Fire Areas TR-1 through TR-5, respectively. None of these are required for attaining safe shutdown. These transformers are located within 50 feet of plant buildings in the yard.

All of these transformers are provided with slag-filled sumps for cooling of hot oil and are of sufficient capacity to retain the total oil inventory associated with each transformer.

The main and unit station service transformers are located south of the turbine building and are separated from each other by 12-inch-thick reinforced concrete partial barrier fire walls, thereby permitting each to be protected as a separate hazard. The south wall of the turbine building was provided with an insulated metal siding and a 3-ply gypsum board design exterior wall assembly extending from the west end of the building for a distance of 130 feet and from ground elevation to a height of

approximately 70 feet. Transformer Fire Area TR-5 is located east of the turbine

building between the diesel generator building and the south office shops building. The diesel generator building has a 3-hour rated fire wall with an equivalent rated exterior door.

The south office shops building is provided with a 2-hour fire-rated exterior wall assembly.

Transformer Fire Area TR-4 is located west of the fuel building. The walls of the fuel building and cable tunnel in this area are 3-hour fire-rated. The exterior doors to the cable tunnel

stairwell and fuel building are 3-hour fire-rated. The isolation of the transformers from any safety-related equipment or areas precludes any possible effect on the ability to attain safe shutdown due to a transformer fire.

9.5A.1.3.53.2 Methods of Suppression/Detection Each of these transformers is provided with an individual heat detector actuated, automatic, water spray deluge system. These deluge systems are also automatically actuated by transformer protection relays. Backup suppression capability consists of

yard fire hydrants.

BVPS-2 UFSAR Rev. 0 9.5A-116 A fire in any one of these areas would be controlled and extinguished within the area. 9.5A.1.3.53.3 Safe Shutdown Summary

Plant shutdown can be achieved with orange and/or purple components from the main control room. A fire in TR-1/TR-2/TR-

3/TR-4/TR-5 does not affect any shutdown components or cable. 9.5A.1.3.53.4 Deviation from BTP CMEB 9.5-1

a. C.5.a(13) Outdoor transformers less than 50 feet from buildings

BVPS-2 UFSAR Rev. 17 9.5A-117 9.5A.1.3.54 UNIT 1 COMPONENTS 9.5A.1.3.54.1 Fire Area Description

The standby diesel (black diesel) is located in its own building separate from the rest of the plant. The black diesel is used to provide power to ASP transfer relay circuits and certain other control circuits used for post fire safe shutdown.

A fire in this area would not affect Unit 2's normal operations.

9.5A.1.3.54.2 Method of Detection and Suppression The black diesel has a total flooding CO suppression system backed up by portable fire extinguishers and yard hydrants. 9.5A.1.3.54.3 Safe Shutdown Summary

The loss of the black diesel will not affect safety-related equipment. Therefore Unit 2 will be shut down using orange and/or purple train components from the control room.

9.5A.1.3.54.4 Deviations from BTP CMEB 9.5-1

None BVPS-2 UFSAR Rev. 15 9.5A-118 9.5A.2 Differences from Branch Technical Position CMEB 9.5-1 The Beaver Valley Power Station - Unit 2 (BVPS-2) Fire Protection Program meets the intent of Branch Technical Position (BTP) CMEB 9.5-1, Rev. 2, dated July 1981. The following provides the descriptions of the BVPS-2 alternatives to specific guidelines of BTP CMEB 9.5-1 and the associated justification for each alternative. The specific alternatives discussed in this section are as follows: BTP CMEB 9.5-1 Section Subject Page C.3.b Fire Brigade 9.5A-119 C.5.a(1) Structural Steel 9.5A-120 C.5.a(3) Conduits/Penetration Seals 9.5A-121 C.5.a(4) Ventilation Penetration Openings (Fire Dampers) 9.5A-123 C.5.a(4) One-Hour Fire Wrap of Ductwork 9.5A-124 C.5.a(5) Modified Fire Doors 9.5A-126 C.5.a(13) Transformers 9.5A-128 C.5.b Safe Shutdown Components 9.5A-129 C.5.b Safe Shutdown Circuitry 9.5A-144 C.5.c(7) Alternative or dedicated safe shutdown capability 9.5A-145a C.5.d(5) Hydrogen Piping 9.5A-146 C.5.e(2) Continuous Line - Type Heat Detectors 9.5A-147 C.5.e(2) Concentrated Cable Tray Areas 9.5A-148 C.5.e(2) Cable Rooms: CO vs Water 9.5A-150 C.5.f(3) Control Room Ventilation 9.5A-152 C.5.g(1) Lighting of Yard Areas 9.5A-153 C.6.a(1) Fire Detection 9.5A-154a C.6.b(7) Fire Hydrant Spacing 9.5A-154b C.7.a(1)(c) Containment (General Area Detection) 9.5A-155 C.7.b Control Room 9.5A-156 C.7.c Cable Spreading Room 9.5A-158 C.7.k Safety-Related Pumps 9.5A-161 C.7.l New Fuel Area 9.5A-162 C.7.m Spent Fuel Pool Area 9.5A-163 C.7.n Radwaste and Decontamination Areas 9.5A-164

BVPS-2 UFSAR Rev. 12 9.5A-119

SUBJECT:

Fire Brigade Item C.3.b:

The Standard Review Plan states that the qualification of fire brigade members should include an annual physical examination to determine their ability to perform strenuous fire fighting

activities. Difference From The SRP:

As a minimum, physical examinations will be conducted for the fire brigade every 3 years, and each member's records will be

reviewed annually by the Medical Department.

Justification:

This procedure was established and approved for BVPS-1 and has been in effect since 1976 without any problems. The physical

examination (nuclear physical) given to the fire brigade members is the same examination given to all workers involved in radiological work at the site. This examination is far more extensive than the examination required for nonradiological workers. Fire brigade members who become physically unfit to perform their function on the fire brigade are reviewed at the

time their physical inability occurs, in accordance with company policy, and corrective action is taken. The annual review is merely a confirmation that no physical problems relating to a

fire brigade member have been overlooked. If the latter occurs, immediate corrective action is taken.

BVPS-2 UFSAR Rev. 14 9.5A-120

SUBJECT:

Structural Steel Item C.5.a(l):

The Standard Review Plan states that fire barriers with a minimum fire resistance rating of 3 hours should be provided to:

(a) Separate safety-related systems from any potential fires in nonsafety-related areas that could affect their ability

to perform their safety function; (b) Separate redundant divisions or trains of safety-related systems from each other so that both are not subject to damage from a single fire;

(c) Separate individual units on a multiple-unit site unless the requirements of General Design Criterion 5 are met with respect to fires. Difference from the SRP: The structural steel supporting the 3-hour fire-rated concrete block walls which separate the 780 ft-6 in. el of the service building (SB-5) from the turbine building (TB-1) and the 773 ft-6 in. el of the auxiliary building (PA-5) and which separate

PA-5 from the radiation protection area (WH-2) and TB-1 has not been fire proofed.

Justification: The combustible loading in SB-5 is < 1/2 hour. The largest

portion of that loading is the charcoal filters, which are all provided with manually actuated deluge spray systems and heat detection systems. There are no local concentrations of combustibles (stacks of cable trays) adjacent to the columns. Therefore, a fire in either of these areas will not be large enough to cause structural damage and no safety-related equipment in these areas is required for safe-shutdown. Postulating failure of the steel, safe shutdown can still be achieved.

BVPS-2 UFSAR Rev. 8 9.5A-121

SUBJECT:

Conduits/Penetration Seals Item C.5.a(3):

The Standard Review Plan states that openings inside conduit larger than 4 inches in diameter should be sealed at the fire barrier, and that openings inside conduit 4 inches or less in

diameter should be sealed at the fire barrier unless the conduit extends at least 5 feet on each side of the fire barrier and is sealed either at both ends or at the fire barrier with noncombustible material to prevent the passage of smoke and hot gases. Differences from the SRP:

a. Openings inside conduit greater than 4 inches in diameter may be sealed at the first access point on one side of the fire barrier with a fire seal material combined with a fire-wrap material encasing the conduit from the fire seal

to the barrier.

b. The following criteria may be applied for internal conduit seals in conduit 4 inches or less in diameter to prevent the propagation of combustible products (smoke and hot gases). Barriers will be evaluated to determine the need for sealing. The occupancy, safe shutdown equipment and existing fire protection features on each side of the barrier will be evaluated to determine the need for sealing to prevent smoke passage. The following conditions on each

side will be used to determine the need for prevention of smoke passage:

1. If there is automatic suppression provided on both sides of the barrier, a fire of sufficient heat to cause combustion of cables inside the conduits or generation of excessive smoke outside the conduits would not be expected to develop. Therefore, sealing inside conduits would not be required.

2. If all equipment in the areas on both sides of the barrier is of the same division for safe shutdown or not required for safe shutdown, there is no need to seal. The area on a side of a barrier will be considered to have one division of safe shutdown in cases where the

conduit of the redundant division is protected by a one hour rated wrap throughout the area.

BVPS-2 UFSAR Rev. 8 9.5A-121a 3. For barriers where a potential for exposure of redundant safe shutdown trains exist, the following analysis will be made and sealing provided inside the conduit which could affect equipment of the redundant division by

passage of smoke.

a) All conduits 3 inches to 4 inches in diameter will be sealed at the barrier or first opening on both sides of the barrier. This will prevent passage of smoke from either side into the adjacent area. b) Conduits less than 3 inches in diameter will be sealed on any side of the barrier where the following conditions exist:

i) The conduit terminates in a panel or enclosure containing equipment within a 10 foot lineal run from the point it enters the area. If the conduit length is more than 10 feet in the area, the products of combustion would condense out inside the conduit and would not

be expected to reach equipment.

ii) The panel or equipment in which the conduit terminates is required for safe shutdown or contains safe shutdown equipment. The affects of smoke and gases would be limited to the immediate enclosed area of conduit termination. Therefore, only those conduits connected to panels with safe shutdown equipment would have a potential for damage and affect safe shutdown. If both above conditions exist on a side of the barrier, the conduit will be sealed on that side of the barrier to prevent the passage of smoke generated in the conduit on the other side (fire side) of the barrier. Each side of the barrier will be evaluated to the above two conditions to determine which conduits less than 3 inches in diameter

must be sealed.

Fire protection engineering evaluations shall apply the revised

internal conduit sealing criteria for specific conduit configurations based on plant specific fire severities, locations of safe shutdown equipment, and the availability of

fire detection and suppression systems for barriers described in the Fire Protection Safe Shutdown Report for BVPS Unit 2 as providing separation of redundant trains of safe shutdown

equipment.

BVPS-2 UFSAR Rev. 8 9.5A-121b Justification:

a. Openings inside conduit greater than 4 inches in diameter will be sealed at the barrier where possible. Due to clearance problems, there are specific cases where this cannot occur. For these cases, the installation of a fire seal at the first opening on one side of the barrier, combined with fire wrap from the seal to the barrier, effectively extends the fire barrier. This method provides the same degree of protection as would sealing at the

barrier.

b. These sealing criteria are consistent with those documented in a letter from Cleveland Electric Illuminating (CEI, 1985) Perry Nuclear Power Plant to the NRC. The NRC (USNRC, 1985) stated that CEI'S conduit sealing criteria

are an acceptable deviation from Section C.5.a(3) of BTP CMEB 9.5-1. In addition, specific conduit configurations will be evaluated for sealing requirements based on plant specific

fire severities, locations of safe shutdown equipment, availability of fire detection and suppression systems, and will be documented in fire protection engineering evaluations in accordance with guidance provided in Generic Letter 86-10. This provides a level of protection equivalent to BTP CMEB 9.5-1.

BVPS-2 UFSAR Rev. 16 9.5A-122

SUBJECT:

Penetration Seal Design Item C.5.a(3):

The Standard Review Plan states that penetration designs should utilize only noncombustible materials and should be qualified by tests. The penetration qualification tests should use the time-temperature exposure curve specified by ASTM E-119, "Fire Test of Building Construction and Materials." Differences from the SRP: Penetrations in fire barriers for ventilation ductwork are

sealed with non-tested fire seals. Justification:

a. Due to plant construction, a rated seal could not be installed in the ductwork passing between the Auxiliary Building 773'6" (Fire Area PA-5) and the Radiation Protection Building 786'6" (Fire Area WH-2). The penetration is in a 12" block wall which has two pieces of ductwork passing through it. Each duct has two 1 1/2 hour fire dampers located in it. Due to the spacing of the dampers and the thickness of the wall, one damper is located outside the wall. The ductwork will be fire wrapped with 1 hr. wrap from just beyond the fire damper to the opening and then flared to cover the face of the

opening. To allow the damper in the wall to expand the opening around the ductwork is filled with Kaowool. Both fire areas have a fire severity of less than 1/2 hour.

Fire area WH-2 has an Automatic Sprinkler suppression system and Fire Area PA-5 is provided with an Automatic General Area fire detection system. Both systems provide

alarms in the control room.

b. Due to plant construction the penetration for the ductwork passing between the pipe tunnel el. 718'6" (Fire Area PT-1) and Cable Vault el. 735'6" (Fire Area CV-1) is not sealed in accordance with the fire damper manufacturers

requirements. The block out is in the 2 ft. thick concrete floor separating the two fire areas. There are two pieces of ductwork passing through this hole. The fire damper listing requires the retaining angle to extend over the opening and onto the floor. Since the two ducts are run side-by-side, this requirement cannot be met between the

two ducts. A barrier is provided between the two ducts by filling the area with Kaowool and the area above the retaining angles is covered with two layers (1 hr. rating)

of E54A fire wrap material. The combustible loading in the pipe tunnel is less than 1/2 hour and the area has a general area smoke detection system which alarms locally and in the Control Room. The Cable Vault el. 735'6" has a combustible loading of less than 2 hrs. and has an automatic CO suppression system.

BVPS-2 UFSAR Rev. 1 9.5A-122a c. The penetration for the ductwork passing between the Cable Vault el. 735'6" (Fire Area CV-1) and Cable Vault el. 755'6" (Fire Area CV-3) is not sealed in accordance with the fire damper manufacturers requirements because of plant

configuration. The block out is in the 2 ft. thick concrete floor separating the two fire areas. Two pieces of ductwork pass through this hole. The fire damper listing requires the retaining angle to extend over the opening onto the floor. Since no floor exists in the area between the two ducts, this area was filled with Kaowool.

The retaining angles on top were covered with two layers (1 hr. rating) of E54A fire wrap material. Both areas are provided with automatic CO suppression systems.

BVPS-2 UFSAR Rev. 9 9.5A-123

SUBJECT:

Ventilation Penetration Openings (Fire Dampers) Item C.5.a(4):

The Standard Review Plan states that penetration openings for ventilation systems should be protected by fire dampers having a rating equivalent to that required of the barrier (see NFPA-90A, "Air Conditioning and Ventilating Systems"). Difference from the SRP:

Fire dampers installed in barrier openings consist of two 1 l/2-hour fire-rated dampers in series instead of one 3-hour fire-

rated damper. This is not a tested configuration. Justification:

The two 1 l/2-hour fire dampers in series is equivalent to a 3-hour rated damper and adequately assures that the fire barriers

will be maintained for the specific fire areas. These dampers were all purchased as U.L.-rated dampers and placed in series in common sleeves to provide the equivalent 3-hour rated damper. In most cases, the U.L. label was removed due to the two dampers being in series, a configuration in which the dampers were not U.L. tested. When additional dampers were required, they were purchased under the same specifications and purchase order as the original dampers.

In the remaining few cases, the U.L. label was removed because of the addition of the CO release device. This is because the dampers were not tested with the release device installed. However, the COrelease device is a plunger operated pin in addition to the fusible link pin in the damper. The CO release device is listed for this application with U.L. and therefore does not reduce the effectiveness of the damper. Combustible loadings were calculated for all fire areas within the plant. There are two fire areas that have fire loadings in excess of 1 l/2-hours that have ventilation penetrations. These areas are listed below and have fire loadings of less than 3

hours and all areas have an automatic fire suppression system.

1. Cable Tunnel (CT-1) 2. Cable Vault and Rod Control Areas (CV-1)

BVPS-2 UFSAR Rev. 13 9.5A-123a The fire loadings in these areas are due in a large part to cables. All cables, except certain cables located in conduit, are IEEE-383-1974 for safety related applications or similarly rated for non-safety applications (Refer to Section 8.3.3 for further details), and thus will not support combustion even though they are included in the fire loadings calculations.

BVPS-2 UFSAR Rev. 16 9.5A-125 The fire severity in these areas is less than 1 hour on both sides of the barrier or automatic suppression and detection has been provided. The fire dampers are used as fire barriers between: Opposite Side Located in

1) PA-3 (less than 1 hr) and PA-5 (less than 1 hr) 2) PA-4 (less than 1 hr) and PA-3 (less than 1 hr)

3) SB-3 (less than 2 hr and SB-4 (less than 1 hr) with suppression) 4) SB-4 (less than 1 hr) and SB-5 (less than 1 hr)

5) PT-1 (less than 1 hr) and SG-1S (less than 1 hr) 6) PA-5 (less than 1 hr) and WH-2 (less than 1 hr)

b. Due to field interferences, fire wrap material cannot be placed on all sides of this 2-inch portion of the ductwork. Combustible loadings (within SB-3 and SB-4 <

1* hour) are less than the rating of the lower damper which is located in the barrier. Additionally, these areas are provided with automatic detection with local

and control room alarms.

For fire areas PA-3 and PA-4 Degassifier and Gas Waste Charcoal Bed Cubicles), an evaluation (10080-DMC-0699) has been performed in accordance with Generic Letter 86-10 to justify the acceptability of the ductwork.

  *Allowable combustible loadings in SB-3 are increased as result of Design Analysis 10080-DEC-196 

c. Due to plant layout the ventilation ductwork for the battery room exhaust system was required to pass through other fire areas (SB-1, SB-2, SB-4) not serviced by this system. In order to ensure the system availability in the event of a fire in an area not

using this system, the ductwork was protected with a l-hour fire-rated material and fire dampers were not installed in the fire barriers. The fire severity in these areas (SB-1, SB-2, SB-4) is less than 1 hour and automatic general area fire detection with local and control room alarms has been provided.

d. Due to plant layout the ventilation ductwork for the emergency switchgear ventilation and the battery room exhaust system were required to be installed in other fire areas (CV-1, CV-3, SB-3) not serviced by this equipment. In order to ensure the system availability

in the event of a fire in an area not using these systems, the ductwork was protected with a l-hour fire-rated material and fire dampers were not installed in the fire barriers. These fire areas (CV-l, CV-2, and CV-3) are provided with automatic suppression and detection with local and control room alarms.

e. A Generic Letter 86-10 evaluation determined that the Gland Steam System ductwork will prevent the spread of fire between PA-5 and SB-5 without crediting 2GSS-DMPF23A and B as fire dampers.

BVPS-2 UFSAR Rev. 13 9.5A-126

SUBJECT:

Modified Fire Doors Item C.5.a(5):

The Standard Review Plan states that door openings in fire barriers should be protected with equivalently rated doors, frames, and hardware that have been tested and approved by a nationally recognized laboratory. Such doors should be self-closing or provided with closing mechanisms and should be inspected semiannually to verify that automatic hold-open, release, and closing mechanisms and latches are operable. (See NFPA 80, "Fire Doors and Windows.")

Areas protected by automatic total flooding gas suppression systems should have electrically supervised self-closing fire doors or fire doors should be kept closed and electrically

supervised at a continuously manned location. Differences from the SRP:

a. Fire door assemblies have been modified from their tested configuration by the addition of security hardware and alarm equipment as required by NRC regulation.

b. Rolling steel fire doors in the safeguards building have had the lower jam modified from the tested configuration to allow for the installation and removal

of equipment.

c. Special purpose-type door assemblies (containment access doors/hatches) are not UL rated.

d. Hollow metal swing type fire door assemblies differ from their original UL tested configuration by having door clearances larger than those identified in ASTM E-152 and NFPA-80.

e. For areas protected by automatic total flooding gas suppression systems, certain doors are not equipped with electrical supervision but are locked closed or self-closing and maintained closed.

Justifications:

a. These modifications were made following the guidelines suggested by Underwriters Laboratories. They are similar to those made on BVPS-1 which were reviewed and found acceptable by the NRC. The door areas have either automatic detection and suppression or manual fire fighting equipment available in the areas. The security alarmed doors also have remote monitoring capability via the security system video monitors and the alarm function in the event the door is left open, which would alert personnel of an abnormal condition in

these areas.

BVPS-2 UFSAR Rev. 13 9.5A-126a The adequacy of fire door assemblies in fire barriers separating safety-related areas will be justified by one of the following:

1. the door assembly will bear a UL label denoting the required fire rating,

2. the door assembly will have certification from the Vendor identifying the fire rating, or

3. the door assembly will be justified by an engineering analysis.

Table 9.5A-2 provides the list of fire doors with security modifications including the fire severities and methods of fire suppression for the areas separated

by these doors.

b. The rolling steel doors in the north and south safeguards areas are not used to separate adjacent fire areas but are used to separate the stairwell within a fire area from the remainder of the area. Since the safeguards areas are normally unoccupied and the fire severity is less than 1/2 hour, this arrangement is acceptable.

c. These containment area special purpose-type door assemblies are capable of providing adequate fire protection for the area. The doors provide a pressure boundary and no UL fire-rated doors for these purposes are available.

BVPS-2 UFSAR Rev. 11 9.5A-127 d. The fire door assemblies will be justified by engineering analysis (Calc. No. 10080-DMC-3443).

e. Areas protected by automatic total flooding gas suppression systems are located in buildings that are provided with restricted access by electrically supervised security access locks which place the areas of concern out of normal travel routes. These doors are maintained closed, self-closing, administratively controlled by procedure, and checked on a daily basis. This ensures the operability of the doors and verifies that they are in the closed position. All fire doors to areas protected by automatic total flooding gas suppression systems are in accordance with the guidelines of the applicable NFPA codes for gaseous suppression systems (NFPA 12 or 12A). Doors subject to this exception are listed below:

FIRE DOOR AREA ACCESSED STATUS CS-25-1 Cable Spreading to North Stair (Control Bldg. 725') Locked closed CS-25-2 Cable Spreading to South Stair (Control Bldg. 725') Locked closed CS-25-3 Cable Spreading to Equipment Shaft (Control Bldg. 725') Locked closed DG-59-1 Diesel Generator 2-1 Room to Silencer Room (DG Bldg. 759') Locked closed DG-59-2 Diesel Generator 2-1 Room to Plenum (DG Bldg. 759') Locked closed DG-59-3 Diesel Generator 2-2 Room to Silencer Room (DG Bldg. 759') Locked closed DG-59-4 Diesel Generator 2-2 Room to Plenum (DG Bldg. 759') Locked closed DG-59-5 Diesel Generator 2-1 Room to Diesel Generator 2-2 Room (DG Bldg. 759') Self-closing & maintained closed IR-07-1 Process Equip Area to South Stair (Control Bldg. 707') Self-closing & maintained closed IR-07-2 Process Equip Area to Equip Shaft (Control Bldg. 707') Locked closed IR-12-1 Cable Tunnel to South Stair (Control Bldg. 712') Self-closing & maintained closed CR-07-1 West Comm. Rm. to North Stair (Control Bldg. 707') Self-closing & maintained closed CR-07-3 East Comm. Rm to West Comm. Rm. (Control Bldg. 707') Self-closing & maintained closed CR-07-4 Process Equip Area to West Comm. Rm. (Control Bldg. 707') Self-closing & maintained closed CV-35-4 West Cable Vault to West Stair (CV Bldg. 735') Self-closing & maintained closed CV-55-1 Rod Control Area to West Stair (CV Bldg. 755') Self-closing & maintained closed BVPS-2 UFSAR Rev. 11 9.5A-127a FIRE DOOR AREA ACCESSED STATUS M-35-1 East Cable Vault to West Cable Vault (CV Bldg. 735') Self-closing & maintained closed M-35-2 East Cable Vault to West Stair (CV Bldg. 735') Self-closing & maintained closed M-35-4 East Cable Vault to Main Steam Pipe Chase (CV Bldg. 735') Self-closing & maintained closed M-55-1 Rod Control Area to East Stair (CV Bldg. 755') Self-closing & maintained closed M-55-2 Rod Control Area to Main Steam Pipe Chase (CV Bldg. 755') Self-closing & maintained closed A-55-4 Rod Control Area to Relay Room (PAB Bldg. 755') Locked closed A-55-5 Rod Control Area to Relay Room (PAB Bldg. 755') Locked closed A-55-6 Rod Control Area to Relay Room (PAB Bldg. 755') Locked closed A-55-9 Rod Control Area to Alt. Shutdown Panel Rm. (CV Bldg. 755') Self-closing & maintained closed A-73-4 Primary Aux Bldg. to Control Bldg Vent Rm. (PAB 773') Locked closed S-35-70 Control Room to Computer Room (Control Bldg. 735') Self-closing & maintained closed The areas serviced by the automatic fire suppression systems are also protected by an early-warning smoke detection system which alarms in the control room. This system would provide early indication to the operations staff of a fire event in these areas. The gas suppression total-flooding systems servicing these areas are also designed to provide a "double-shot" full discharge capability, such that the initial discharge would be automatic and the follow-up discharge would be manually activated, if necessary. Manual hose stations for backup water suppression capability is also available for the subject areas providing additional defense-in-depth fire protection capability.

BVPS-2 UFSAR Rev. 15 9.5A-128

SUBJECT:

Transformers Item C.5.a(13)

The Standard Review Plan states that outdoor oil-filled transformers should be located at least 50 feet distant from buildings, or building walls within 50 feet of oil-filled transformers should be without openings and have a fire resistance rating of at least 3 hours.

Difference from the SRP: Transformers TR-2A, TR-2C, TR-2D, and TR-MT-2 are located within

50 feet of buildings which do not have a fire-resistance rating of at least 3 hours.

Justification: The walls within 50 feet of these transformers which do not have

a 3-hour fire rating are the turbine building and south office and shops building (SOSB) walls. The turbine building has been provided with an insulated metal siding and 3-ply gypsum board design exterior wall assembly. The SOSB has been provided with 2-hour fire-rated walls in the exposed areas. The SOSB is not part of the production plant. In addition, these transformers are provided with slag-filled sumps for cooling of hot oil. Sumps are of sufficient capacity to retain the total oil inventory associated with each transformer. These transformers

are also protected by heat actuated water deluge suppression systems. BVPS-2 UFSAR Rev. 0 9.5A-129

SUBJECT:

Safe Shutdown Components Item C.5.b:

The Standard Review Plan states that one of the redundant trains is to be free of fire damage so that safe shutdown can be achieved. This can be achieved by:

a) Separating redundant trains by a fire barrier having a 3-hour rating. b) Separating redundant trains by a horizontal distance of more than 20 feet with no intervening combustibles or fire hazards. In addition, fire detectors and an automatic fire suppression system should be installed in the fire area. c) Enclosing one redundant train in a fire barrier having a 1-hour rating. In addition, fire detectors and an automatic fire suppression system should be installed in the fire area. Differences from the SRP: The following safe shutdown components have not been provided

with adequate separation as noted above: DESCRIPTION MARK NUMBER FIRE AREA (1) Charging Pumps 2CHS*P21A,B,C PA-3 (2) Component Cooling Water Pumps 2CCP*P21A,B,C PA-3 (3) Boric Acid Transfer Pumps and Storage Tanks 2CHS*P22A,B

TK21A,B PA-4 PA-4 (4) Charging System Control Valves 2CHS*LCV115B,D 2CHS*FCV113A 2CHS*MOV350 PA-3 PA-3 PA-3 (5) Emergency Switchgear Supply and Exhaust Fans 2HVZ*FN261A,B 2HVZ*FN262A,B CV-4 CV-4 (6) Emergency Switchgear Supply and Exhaust Dampers 2HVZ*MOD21A,B 2HVZ*MOD22A,B CV-4 CV-4 (7) Emergency Exhaust Fans 2HVP*FN264A,B PA-4 (8) Auxiliary Feedwater Control Valves 2FWE*HVC100A,B,C, D,E,F SG-1S (9) Atmospheric Steam Dump Valves 2SVS*PCV101A,B,C

2SVS*HVC104 MS-1 MS-1 (10) Main Steam Isolation Valves 2MSS*AOV101A,B,C MS-1 (11) Equipment inside containment (Various) RC-1 Justifications:

1. The charging pumps (2CHS*P21A,B,C) are located in three cubicles adjacent to each other in the auxiliary building, el. 735 ft-6 in. The communicating walls between the

BVPS-2 UFSAR Rev. 13 9.5A-130 cubicles are 2-foot-thick concrete walls with all penetrations sealed with 3-hour fire seals. The west wall of each cubicle is a composite of 2-foot-thick poured concrete walls with 2-foot-thick by 6 foot wide removable concrete blocks in the middle of each cubicle for pump removal. The top 5 feet has been left

open to allow the monorail crane to pass through. The 12 foot high wall will prevent the passage of a fire at floor level from passing into the charging pump cubicle and all cables immediately outside the cubicle and inside the cubicles are in conduit. The east wall of each cubicle is a 2-foot-thick concrete wall and has a

labyrinth-type opening for missile and radiation scatter protection. Charging pumps are arranged such that the "A" pump is separated by more than 20 feet

from the "B" pump with the "C" pump (swing pump) in between. Walls extend from a 3-hour rated floor to a 3-hour rated ceiling. Electrical raceways associated

with redundant trains of safe shutdown components were adequately protected by a fire-wrap material. A curb is provided in each opening to contain any oil spills within the cubicle. Each cubicle is provided with a drain to prevent accumulation of spilled oil. Additionally, the entire area of PA-3 including the

cubicles is protected by an early warning smoke detection system. The total combustible loading for the PA-3 area in which the three cubicles are located is less than 1-hour duration. The fire load in the charging pump

cubicles is less than 1/2 hour.

Cable insulation composes the majority of the fire loading in PA-3. All cables not in conduit are IEEE-383-1974 for safety related applications or similarly rated for non-safety applications (Refer to Section 8.3.3 for further details), which inhibits fire spread. This cable will not propagate fire even if its outer covering and insulation have been destroyed in the area of flame impingement. BVPS-2 postulates the worst possible fire in this area to be a slow-developing cable type of fire. This type of fire would be

detected in its incipient stages by the early warning smoke detection system and responded to by the plant fire brigade prior to the development of any major fire

involvement.

BVPS administratively controls all flammable liquids. Therefore, considering the original design philosophies, the type of fire hazard, the worst postulated fire, the separation of the cubicles, the smoke detection system, and the lack of transient combustibles, this configuration ensures that at least one train will be free of fire damage to achieve safe

shutdown.

BVPS-2 UFSAR Rev. 13 9.5A-131 2. The component cooling water pumps (2CCP*P21A, B, and C) are located in the auxiliary building el 735 ft-6 in. The component cooling water pumps supply cooling water to various primary plant components such as the reactor coolant pumps, residual heat removal heat exchangers, nonregenerative heat exchanger, shield tank coolers, CRDM shroud cooling coils and primary

plant sampling system coolers. The only appreciable combustible loading within 20 feet of the coolant pumps are the pumps themselves (1/2-gal of lube oil and the motor insulation for each pump). The component cooling water pumps are arranged so that the "A" pump is separated from the "B" pump by a distance of 24 feet with the "C" pump (swing pump) in between. The component cooling water pumps are protected by a preaction spray system. The system is actuated by heat detectors and the pipe is air supervised for reliability. Thus, there is sufficient protection for these pumps from any postulated fire in the area. At least one train will remain free of fire damage to achieve safe shutdown.

3. Boric Acid Transfer Pumps (2CHS*P22A,B) and Boric Acid Storage Tanks (TK21A,B):

Boric Acid Transfer Pumps Each pump is located within an individual cubicle with 2-foot-thick reinforced concrete walls. The west wall of each cubicle has a labyrinth-type opening for missile and radiation protection. This opening is

used for personnel access and to provide ventilation to the boric acid transfer pumps. The combustible loading in each cubicle is the transfer pump motor and associated cables. The postulated fire for a boric acid transfer pump cubicle is a fire in the motor. Based on the design of the cubicles, the low combustible loading, the fire detection system and manual hose racks, a fire in either cubicle would be controlled and extinguished within the cubicle. Boric Acid Storage Tanks

Each tank is located within an individual cubicle with 2-foot-thick reinforced concrete walls. The south wall of each cubicle has a labyrinth-type opening for

access to the cubicle.

The combustible loading in each cubicle is the cabling for instrumentation associated with the tanks, which is negligible. The postulated fire for a boric acid transfer tank cubicle is a fire in the cables. Based on the design of the cubicles, the low combustible loading, the fire detection system and manual hose racks, a fire in either

BVPS-2 UFSAR Rev. 12 9.5A-132 cubicle would be controlled and extinguished within the cubicle. 4. Charging System Suction Valves

The charging system is used to provide borated water to the reactor coolant system using the charging pumps. The charging pumps are provided with four suction paths for safe shutdown. Two paths are from the refueling water storage tank (suction isolation 2CHS*MOV350 and 2CHS*FCV113A). The refueling water suction valves (2CHS*LCV115B and D) are located together in the valve cubicle on the 718 ft-6 in. elevation of the auxiliary

building. The boric acid storage tank suction valves (2CHS*MOV350 and 2CHS*FCV113A) are located together on the 710 ft-6 in. elevation of the auxiliary building.

These valves are not separated by 3-hour fire barrier and there is approximately 15 feet between the 2CHS*LCV115B and D valves and the 2CHS*MOV350 and

2CHS*FCV113A valves. For radiation hazard reasons, these areas are restricted access and are out of normal plant travel routes. The only combustibles within the area are the motor operators on the valves and TSI Thermo-Lag insulation. The motors are totally enclosed

and a total burnout of one motor would not affect the operation of the other motors. The valves can be opened manually if required and the cables to 2CHS*LCV115D have been adequately protected by a fire-wrap material equal to that required of the barrier and commensurate with the hazards of the area. Due to the fact that only one out of the four valves has to operate, the area contains negligible combustibles (all cables in the area are in conduits), and the area is provided with general area fire detection and hose racks and portable fire extinguishers, a fire in the area will not prevent safe shutdown.

5. Emergency Switchgear Room Supply and Exhaust Fans (2HVZ*FN261A,B and 262A,B)

The supply fans (2HVZ*FN261A,B) supply air to the emergency switchgear rooms (SB-1 and SB-2). These fans are axial fans and are located (along with the motors)

in the ductwork in the cable vault rod control area, el 773 ft-6 in. (CV-4). The fans are parallel to one another and only one fan is required for shutdown. The motors for the fans are totally enclosed motors and the cables for 2HVZ*FN261A are protected in place with a 1-hour fire-rated material in the area outside of the

ductwork.

Based on the design of the ductwork, the negligible combustible loading (all cables are in conduits in this area), the fire detection system, and manual hose racks, adequate protection is provided to prevent the spread of a fire from one fan to the other. In addition, loss of ventilation for the Emergency Switchgear Rooms has been analyzed, and the analysis

determined that manual operator actions could be established to aid ventilation for the rooms. BVPS-2 UFSAR Rev. 13 9.5A-133 The exhaust fans (2HVZ*FN262A,B) remove air from the emergency switchgear rooms (SB-1 and SB-2). These fans are similar to the supply fans in design and layout and are also located in CV-4. Adequate protection is

provided to prevent the spread of a fire from one fan to the other, and as stated for the supply fan, manual operator actions can be provided for loss of emergency

switchgear room ventilation.

6. Emergency switchgear room supply dampers (2HVZ*MOD21A and B) are located in the intake plenum located in the cable vault and rod control area el 773 ft-6 in., which is out of normal travel routes and has very little combustibles (<< 1/2 hr.). The dampers operate to maintain the proper temperature in the emergency switchgear rooms. Either Train A or B has sufficient capacity to maintain proper temperatures. The only combustibles inside the area are the two motor actuators and the roll filter and TSI Thermo-Lag Material. The roll filter complies with NFPA 90A Class 2 media. The damper motors are totally enclosed motors in NEMA 4 enclosures which act as a radiant shield.

Therefore, a burnout of one motor would not affect the operation of the other motor. Emergency switchgear room exhaust dampers 2HVZ*MOD22A and B are located in the discharge plenum of the

exhaust system located in the cable vault and rod

control building el 773 ft-6 in. which is out of normal travel routes and has very little combustible loading (<< 1/2 hr.). The dampers operate to maintain the proper temperature in the emergency switchgear rooms. Either Train A or B has sufficient capacity to maintain proper temperatures. The only combustibles in the plenum are the two motor actuators (one for each damper) and TSI Thermo-Lag Material. The damper motors are totally enclosed motors in NEMA 4 enclosures which

act as a radiant shield on its own. Therefore, a burnout of one motor would not affect the operation of the other motor.

7. Charging Pump Emergency Exhaust Fans

The exhaust fans are located in the northwest corner of the auxiliary building in a cubicle created by the arrangement of equipment and layout of other cubicles.

The fans are axial fans and are totally contained within the ductwork. The only combustible materials within 20 feet of the fans are cable trays located

along the east wall of the cubicle. All cables, except those which run in conduit are IEEE-383-1974 for safety related applications or similarly rated cables for non-safety applications (Refer to Section 8.3.3 for further details). Based on the design and layout of the area, the type of cable, and the fact the fans are located inside the ductwork, a fire in the area would not affect the fans. Loss of both fans has been analyzed and the analysis determined that manual actions would be necessary to provide temporary charging pump ventilation within 24 hours. BVPS-2 UFSAR Rev. 0 9.5A-134 8. The auxiliary feedwater control valves are located in the south safeguards building (SG-1S). These valves are hydro-electrically operated, normally open valves, that on loss of electrical control fail as is, and on loss of hydraulic oil, auxiliary feedwater flow will open the valve (the desired position). The combustible loading in SG-1S is less than 1/2 hour. Throttling on the discharge valve for auxiliary feedwater pump 2FWE-P23B can be done to achieve

shutdown.

9. The atmospheric steam dump valves (2SVS*PCV101A, B, and C and 2SVS*HCV104) are all located in the main steam valve house and have not been provided with 3-hour separation. They are partially separated by concrete walls which extend at least 2 feet beyond the valves. The valves are located approximately 25 feet above the floor. The main steam valve house has a

combustible loading of less than 1/2 hour.

10. The main steam isolation valves (2MSS*AOV101A,B, and C) are located in the main steam valve house. The valves are required to close to provide isolation for the steam generators. The main steam valves are normally open, and held open by air pressure during plant operation. The valves are closed by springs when air is removed from the valves. Three solenoid valves are used to normally open and close a main steam valve. One is an air supply valve energized to open, admitting supply air to open and hold open the

main steam valve. The other two solenoid valves de-energize to open venting the air from the main steam valve allowing the valve to close. Therefore, loss of

power to the solenoids will close the main steam valves. The main steam valve house has a fire severity rating of <1/2 hour and automatic fire detection with hose racks and portable fire extinguishers has been provided. Therefore a fire in the area will not prevent the main steam isolation

valves from closing.

11. The following systems have equipment located in the primary reactor containment (RC-1):

a. Reactor Coolant System (RCS) Letdown

b. RCS Depressurization

c. Process Instrumentation

d. Residual Heat Removal (RHS)

e. Safety Injection Accumulator Isolation/Venting The following assumptions were used in evaluating system availability and dictating manual actions.

BVPS-2 UFSAR Rev. 0 9.5A-134a a. The plant experiences a fire in Fire Area RC-1.

b. The fire is localized in nature and fires are not postulated from transient sources.

BVPS-2 UFSAR Rev. 0 9.5A-135 c. The plant experiences a loss of offsite power.

d. The reactor is scrammed.

e. Instrument air is available.

NOTE: Assumption c is valid except when the availability of offsite power represents a worst case condition as is the case for some spurious operations scenarios.

a. RCS Letdown Train A utilizes the normal RCS letdown flow path. Trains B and C utilize the redundant reactor vessel head vent flow paths discharging to the pressurizer relief tank.

Trains A, B, and C Valve and Cable Physical Separation

The valves and associated cables are listed below:

Valve Mark No. Train A Trains B and C

2CHS*AOV200A 2RCS*SOV200A 2CHS*AOV200B 2RCS*SOV200B 2CHS*AOV200C 2RCS*SOV201A 2CHS*LCV460A 2RCS*SOV201B

Train A Trains B and C 2CHS*LCV460B 2RCS*HCV250A 2RCS*HCV250B

Valve Separation Analysis

Train A valves 2CHS*LCV460A and B are located on the 692 ft

elevation near column line 13, and 2CHS*AOV200A, B, C are located on the 718 ft elevation near column line 5. Train B(C) valves 2RCS*SOV200A,B, 2RCS*SOV201A,B are located on the reactor vessel seismic support platform on elevation 767 ft and valves 2RCS*HCV250A, B are located on elevation 738 ft near column line

6.

Train A valves are physically separated from Train B and C valves in cubicles angularly separated inside RC-1. Although

strict conformance with BTP CMEB 9.5-1 is not fully achieved due to the potential for intervening combustibles, the design attributes discussed in Section 9.5A.1.3.29 of the RC-1 fire

area analysis and the spatial separation, afford an equivalent level of protection to that required in BTP CMEB 9.5-1.

BVPS-2 UFSAR Rev. 0 9.5A-136 Letdown Train A, B, and C Cable Separation Analysis During transit of Train A, B, and C cables from the valves to the electrical penetration area, cable separation is not in

strict conformance with the cable separation requirements specified in BTP CMEB 9.5-1, since redundant cables are routed within 20 feet of each other and cables in tray within the annulus area act as intervening combustibles. However, one train of safe shutdown cables is always routed in conduit.

Although strict conformance with BTP CMEB 9.5-1 is not fully achieved due to intervening combustibles, the design attributes discussed in Section 9.5A.1.3.29 of the RC-1 fire area analysis

and the spatial separation afford an equivalent level of protection to that required in BTP CMEB 9.5-1.

Spurious Actuations

For Train A all valves fail closed on a loss of power or a loss of air supply. A loss of power could occur due to a fire induced open in the control cables, or, for 2RCS*LCV460A and 2RCS*LCV460B, a spurious generated low pressurizer level signal.

For Trains B and C all valves also fail closed on a loss of power but do not have interlocks that could cause spurious actuation. The head vent isolation valves represent a high-low interface boundary. Since there is no common signal to open these valves, a minimum of three independent hot shorts, one in

each valve circuit, are required to cause loss of RCS pressure boundary. If this improbable event occurs, the valves will be deenergized at their power source.

b. RCS Depressurization

Train A utilizes the pressurizer power operated relief valves. Train B utilizes the charging system auxiliary spray valve.

Trains A and B Valve and Cable Physical Separation

The valves and associated cables are listed below:

Valve Mark No. Train A Train B

2RCS*PCV455D 2CHS*MOV311

2RCS*MOV537 Valve Separation Analysis Train A valves are located in the pressurizer cubicle on elevation 767 ft, and the Train B valve is located on elevation

718 ft near column line 6.

BVPS-2 UFSAR Rev. 15 9.5A-137 Although strict conformance with BTP CMEB 9.5-1 is not fully achieved due to the potential for intervening combustibles, the design attributes discussed in Section 9.3A.1.3.29 of the RC-1 fire area analysis and the spatial separation afford an

equivalent level of protection to that required in BTP CMEB 9.5-

1.

Depressurization Train A and B Cable Separation

During transit of Train A and B cables from the valves to the electrical penetration area, cable separation is not in strict conformance with the cable separation requirements specified in BTP CMEB 9.5-1 since cables in trays within the annulus area act as intervening combustibles. However, the design attributes discussed in Section 9.5A.1.3.29 of the RC-1 fire area analysis and the spatial separation afford an equivalent level of

protection to that required in BTP CMEB 9.5-1. Spurious Actuations For discussion of spurious PORV actuation, refer to the section on deviation from Item C.5.b for Safe Shutdown Circuitry.

The guidelines presented in BTP CMEB 9.5-1 indicate that for analysis purposes the plant experiences a fire in a particular fire area and also experiences a loss of offsite power. In the discussion that follows, a loss of offsite power does not present the worst case; therefore, offsite power is considered available. The case in point is a spurious opening of either one of the normal spray valves 2RCS*PCV455A or 2RCS*PCV445B. With loss of offsite power this would not present a problem as

RCP flow is required for the spray paths. Appropriate operator actions will be required if RCP flow is available for the one spray path which spuriously opened. As stated above, only one

valve is subject to hot shorts.

BVPS-2 UFSAR Rev. 20 9.5A-138 c. Process Instrumentation The minimum instrumentation, located inside containment, that is required for safe shutdown are steam generator wide range level

indication, pressurizer level, nuclear instrumentation, and RCS

loop temperature.

The essential instruments are listed below:

Instrument

Steam Generator Level

2FWS*LT477

2FWS*LT487

2FWS*LT497

Pressurizer Level

2RCS*LT459

2RCS*LT460

RCS Hot Leg Temperature

2RCS*TE413

2RCS*TE423

2RCS*TE433

Nuclear Instrumentation 2NME*ND52A 2NME*ND52B

Instrument Transmitter and Cable Separation Analysis

Steam Generator Level Transmitter and Cable Separation Analysis

Shutdown operations require the availability of a minimum of two

steam generators. With this fact as a consideration and the uncertainty of the location of a fire in RC-1, and three steam generator level transmitters are analyzed without assignments of either Train A or B. FWS*LT487 is located in the annulus area between column lines 8 and 9 on elevation 718 ft. Its transmitter cables are routed in conduit to penetration RCP*17.

Both the LT487 and its associated conduit are protected by the cable penetrations area deluge spray suppression system.

FWS*LT477 is located on elevation 718 ft in the annulus area

near column line 16.

FWS*LT497 is located on elevation 718 ft in the annulus area near column line 5. The cables for LT477 and LT497 are routed in opposite directions in the annulus area to penetrations RCP*20 and 19B respectively. Redundant transmitter cables are

routed within 20 feet of one another only in the penetration

area on elevation 735 ft, which is protected by the penetration

area deluge spray suppression system.

BVPS-2 UFSAR Rev. 0 9.5A-139 All transmitters are physically separated by greater than 20 ft. Although strict conformance with BTP CMEB 9.5-1 is not fully achieved for transmitter location or cable routings due to the cables in trays acting as intervening combustibles, the design

attributes discussed in the RC-1 fire area analysis (Section 9.5A.1.3.29) and the spatial separation afford an equivalent level of protection to that required in BTP CMEB 9.5-1.

Spurious Actuations Only one level transmitter's cable is subject to a hot short. A hot short to the level transmitter's cable is analogous to a high steam generator level which results in securing feed flow

to that particular steam generator. An open on a level transmitter's cable will be analogous to a low steam generator level which will result in full feed flow to that particular

steam generator. Pressurizer Level Transmitter and Cable Separator Analysis Pressurizer level transmitters RCS*LT459 and 460 are located on the 738 ft elevation in the annulus area near column lines 4.5

and 6 respectively. The cables for both transmitters are routed in conduit in opposite directions around the containment annulus to the orange and purple cable penetration areas. Both the redundant transmitters and associated cabling are separated by greater than 20 feet throughout RC-1.

Although strict conformance with BTP CMEB 9.5-1 is not fully achieved due to intervening combustibles in the form of cables in trays, the design attributes discussed in the RC-1 fire area analysis (Section 9.5A.1.3.29) and the spatial separation afford an equivalent level of protection to that required in BTP CMEB 9.5-1. Spurious Actuations Level transmitters 2RCS*LT459, and RCS*LT460 close valves 2CHS*LCV460A and B on a low pressurizer level. This signal also closes 2CHS*AOV200A, B, and C. Either one of these level transmitters could generate a low pressurizer level signal if their cables experience a fire induced open thus resulting in a loss of Letdown Train A.

RCS wide range pressure indication is provided by 2RCS*PT440 and 441 which are located outside the containment. The following discussion addresses spurious signals generated by fire induced failures in the pressurizer pressure transmitter circuits located inside RC-1.

Pressurizer pressure transmitters provide signals to open the pressurizer power operated relief valves (PORVS) on high pressure and also send signals to actuate safety injection on low pressure. BVPS-2 UFSAR Rev. 15 9.5A-140 For fire induced failures of the pressure transmitters, a high pressure signal can be generated by a hot short. A spurious PORV opening due to failure of the pressure transmitters can be overridden by operator action to place the Benchboard control switch in the Close position or deenergize the control circuit.

A fire induced open for the pressure transmitters cable will result in a low pressure signal. Although all pressure transmitter cables are routed in separate conduits and are all powered from separate channels, it could be considered credible that two of these pressurizer pressure transmitter cables could open when subjected to a common fire hazard (i.e., electrical penetrations area) thus resulting in spurious generation of a safety injection signal and therefore a containment isolation signal. This would result in a loss of instrument air inside containment, a loss of RCS Letdown - Path A, RCS Depressurization - Path B, and RCS Boration - Path A. RCS Letdown - Train B, RCS Depressurization - Train B, and RCS Boration - Train B will be available.

This condition can be corrected by resetting the spurious safety injection signal and realigning the affected valves.

RCS Loop Temperature Indication The present BVPS-2 design provides a single (loop mounted) hot and cold temperature measurement for each RCS loop.

All RCS loop cold leg temperature measurements are dependent on one purple-related power source and all RCS loop hot leg temperature measurements are dependent on one orange-related power source. The loss of a single power source could result in the loss of all RCS loop hot leg or cold leg temperature indication. The NRC has accepted this design based on the Westinghouse Owners Group (WOG) letter dated June 14, 1983 (NSID/WOG-108) and the fact that diverse measurement is available for RCS loop hot leg and cold leg temperature measurement. Core exit thermocouples can be used in lieu of RCS hot leg temperature and steam line pressure of the appropriate loop can be used in lieu of RCS loop cold leg temperature.

A fire inside RC-1 which results in the destruction of the cables for either RCS loop hot or cold leg temperature

indication is analogous to a loss of power to the instruments and, therefore, the justification provided to the NRC is considered acceptable for this scenario.

The RCS loop hot leg temperature elements are designated as safe shutdown Train A and the core exit thermocouples are designated

safe shutdown Train B.

BVPS-2 UFSAR Rev. 0 9.5A-141 Hot Leg Temperature Indication Equipment and Cable Separation Analysis The core exit thermocouples are located in the reactor vessel

core outlet. Instrument cables are routed into the annulus area on elevation 735 ft. Each train associated group is routed in opposite directions around the annulus to their respective penetration area. Redundant core exit thermocouple cabling is separated by more than 20 feet once the cables penetrate the crane wall.

Loop hot leg temperature elements are located in their respective steam generator cubicles with associated cables routed to the orange penetration area. Therefore either the core exit thermocouples or hot leg temperature indicator will always be available.

Although strict conformance with BTP CMEB 9.5-1 is not fully achieved due to intervening combustibles in the form of cables

in trays, the design attributes discussed in the RC-1 fire area analysis (Section 9.5A.1.3.29) and the spatial separation afford an equivalent level of protection to that required in BTP CMEB

9.5-1. Spurious Actuations Spurious actuations of RCS loop hot leg temperature elements are of concern when cold overpressure mitigation is in the armed

position. Opening the instrument cables for the temperature elements produces a spurious low temperature signal. As indicated by the cable routing, all temperature elements

eventually enter the same raceways, therefore opens in all cables could be considered credible. The RCS loop temperature elements signals are compared to RCS loop WR pressure to open

PORV 2RCS*PCV456 on a predetermined setpoint. With credible pressure and temperature indication available, this spurious actuation of the PORV can be isolated by blocking the generated

signals at the main board. Cold Leg Temperature Indicator The RCS loop cold leg temperature elements are designated as safe shutdown Train A and the steam generator pressure

indicators are designated as safe shutdown Train B. Since Train B is located outside RCS one method will always be

available. Spurious Actuations Spurious actuations of RCS loop cold leg temperature elements are of concern when cold overpressure mitigation is in the armed

position. Opening the instrument cables for the temperature elements produces a spurious low temperature signal. The RCS loop cold leg temperature elements signals are compared to RCS loop WR pressure to open PORV 2RCS*PCV456 on a predetermined setpoint. With credible pressure and

BVPS-2 UFSAR Rev. 20 9.5A-142 temperature indication available this spurious actuation of the PORV can be isolated by blocking the generated signals at the

main board.

Nuclear Instrumentation The environmentally qualified post accident neutron flux monitoring system is credited for subcritical flux monitoring during post-fire operating conditions. This system consists of two redundant detectors, 2NME*ND52A (orange train) and 2NME*ND52B (purple train) and associated instrument channels with readout on the plant safety monitoring system in the control room. There is also an indicator on the Alternate Shutdown Panel for 2NME*ND52A. The in-containment portion of these channels consists of two detectors and the associated in-containment cable. The detectors are mounted on opposite sides of the reactor vessel within the neutron shield tank. The in-containment cable is enclosed in a steel conduit raceway system from the detector pigtails to the reactor containment penetrations. Physical separation of the in-containment cables is evaluated in Generic Letter 86-10 evaluation 12-063. Spurious Actuation There are no automatic actuations associated with nuclear instrument channels 2NME*ND52A and 52B.

d. Residual Heat Removal System (RHS)

Since RHS is a cold shutdown system, all RHS valve operations

can be manually conducted at the valve if required.

RHS heat exchanger cooling water supply valves 2CCP*MOV112A and B are located in the north section of RC-1 el 717 ft-6 in. outside of the crane well, 1 ft-0 in. below a walkway.

2CCP*MOVl12A and B are supply isolation valves to the RHS heat exchangers and RHS pump seal coolers. The valves fail as is, on a loss of power or motor. A manual handwheel is provided for valve operation if necessary. The valves are in an area with

low fire loading, the only combustibles in the area are four cable trays that are 10 ft above the valves. The valve motors are totally enclosed and a total burnout of one motor would not

affect the operation of the other. RHS pumps supply isolation valves 2RHS*MOV701A and B and MOV702A and B are located in the northeast section of RC-1 el 692 ft-11 in. The valves are motor-operated gate valves normally closed and will be opened only for RHS operations. The major combustible in the area is the lube oil contained in the reactor coolant pumps (RCS pumps).

The RCS pumps are provided with a lube oil leak collection system which eliminates the RC pumps as an exposure fire

problem. The valves, themselves, are the only other

combustibles in the area. The isolation valve motors are

totally enclosed and the total burnout of any other motor would not affect the operation of the other motors. The valves can

also be operated manually if required.

BVPS-2 UFSAR Rev. 20 9.5A-143 2RHS*P21A and B are located side by side on elevation 707 ft. Each residual heat removal pump is protected by an open head

deluge spray system. The deluge spray is actuated by heat

detectors and is automatic in nature with the exception of the containment isolation valve which is operated from the control

room. The heat detectors also provide alarms in the control

room.

In addition to the heat detectors, photo-electric smoke detectors (early warning detection system) provide fire alarms

in the control room.

Each pump's associated cables are routed in opposite directions

in the annulus area to its respective penetration in the cable penetration area; 20 ft separation is maintained throughout.

2RHS*P21B power cable is routed in armored cable from the pump

to the electrical penetration area.

Although strict conformance with BTP CMEB 9.5-1 is not fully achieved due to intervening combustibles in the form of cables

in trays, the design attributes discussed in the RC-1 fire area analysis (Section 9.5A.1.3.29) and the spatial separation afford

an equivalent level of protection to that required in BTP CMEB

9.5-1.

Spurious Actuations

The RHS valves located inside containment will not spuriously operate for a fire in RC-1. However, operability may be lost. The RHS suction valve open permission and auto-close interlocks are controlled by pressure transmitters located outside

containment. In addition, the power is removed at the motor control center for one series MOV in each redundant suction

path.

e. Safety Injection Accumulator Isolation/Venting

Prior to depressurizing the RCS below 600 psig it will be

necessary to perform the following:

1. Either isolate the safety injection (SI) accumulators or;

2. Vent the SI accumulators.

The above actions are required to prevent repressurizing the RCS

prior to RHS operation.

Two out of three of the SI loop isolation valves are purple powered and the remaining valve is orange powered. Each accumulator is provided with two redundant vent paths (orange/purple). Although the vent and isolation valves for

each accumulator are located within 20 ft of each other, the fact that there are no intervening combustibles and that all

cables in the area of the accumulators are enclosed in conduit, it is not considered credible to lose both methods due to a

single fire.

BVPS-2 UFSAR Rev. 15 9.5A-144

SUBJECT:

Safe Shutdown Circuitry Item C.5.b:

The Standard Review Plan states that one of the redundant trains is to be free of fire damage so that safe shutdown can be achieved. This can be achieved by:

a) Separating redundant trains by a fire barrier having a 3-hour rating.

b) Separating redundant trains by a horizontal distance of more than 20 feet with no intervening combustibles or fire hazards. In addition, fire detectors and an automatic fire suppression system should be installed in the fire area. c) Enclosing one redundant train in a fire barrier having a 1-hour rating. In addition, fire detectors and an automatic fire suppression system should be installed in the fire area. Differences from the SRP: The following areas have redundant circuitry and do not meet the guidelines of C.5.b, nor is alternate shutdown capability provided for the following areas except SB-4 which relies on the ASP for monitoring of certain instrumentation and ventilation

control (Refer to Section 9.5A.1.3.33).

 (1) Cable Vaults (CV-1, CV-2, CV-3, CV-4, and CV-5)  (2) Primary Auxiliary Building (PA-4)  (3) South Safeguards Building (SG-1S)  (4) Service Building Normal Switchgear (SB-4) 
(5) Primary Auxiliary Building (PA-3)  (6) Alternate Shutdown Panel (ASP)  (7) Emergency Switchgear Rooms (SB-1 and 2)  (8) Service Building Cable Tray area (SB-3)  (9) Reactor Containment (RC-1)

Justification:

(1) Fire Areas CV-4 and CV-5 contain redundant circuitry for various components of the emergency switchgear ventilation systems. The combustible loading for each area is less than 1/2 hour. All cables in these areas are routed in conduit. In addition, orange cables for the equipment have been adequately protected using a fire-wrap material. Fire detection for these areas consists of area ionization detectors which alarm locally and in the control room. Portable fire extinguishers are located in these areas with manual hose stations located immediately adjacent to these areas. Based on the low combustible loading fire detection present, and the fact that redundant cabling required for shutdown has been provided with additional protection, the means of suppression is adequate to protect the hazard and provide the required separation. 

BVPS-2 UFSAR Rev. 15 9.5A-145 (2) The auxiliary building, elevation 755 ft-6 in. contains redundant circuitry for various shutdown components. The combustible loading for this area is less than 1/2 hour. This area is compartmentalized for radiological and safety-

related concerns.

Various cabling has been adequately protected using a fire-wrap material. Fire detection for these areas consists of area ionization detectors which alarm locally and in the control room. Portable fire extinguishers are located in the area and manual hose stations are located in the stairwells adjacent to this area. Based on the low amount of combustible loading, the fire detection present, and the fact that redundant cabling required for shutdown has been provided with additional protection, the means of suppression available is adequate to protect the hazard and

provide the required separation.

(3) The south safeguards building contains redundant circuitry for various components of the auxiliary feedwater system.

The loading for the combustible fire area is less than 1/2 hour. Purple cables for this equipment have been adequately protected using fire-wrap material. Fire detection for this area consists of area ionization detectors which alarm locally and in the control room. Portable fire extinguishers and manual hose stations are located in this area. Based on the low combustible loading, the fire detection present, and the fact that redundant cabling required for shutdown has been provided with additional protection, the means of suppression is adequate to protect the hazard and provide the required

separation.

(4) The service building normal switchgear room contains redundant circuitry for the ventilation systems to the emergency diesel generator building. The combustible loading for this fire area is less than 1 hour. Orange cables for the equipment have been adequately protected using a fire-wrap material. Fire detection for this area consists of area ionization smoke detectors which alarm 

locally and in the control room. Portable fire extinguishers and manual hose stations are located in the area. Based on the low combustible loading, the fire detection present, and the fact that redundant cabling required for shutdown has been provided with additional protection, the means of suppression is adequate to protect

the hazard and provide the required separation.

(5) The auxiliary building, elevation 735 ft-6 in. contains redundant circuitry for various shutdown components. The combustible loading for this area is less than 1/2 hour.

This area is compartmentalized for radiological and safety-related concerns. Various cabling has been adequately protected using a fire-wrap material. Fire detection for these areas consists of area ionization detectors which alarm locally and in the control room. Portable fire extinguishers are located in the area and manual hose stations are located in the stairwells adjacent to this

BVPS-2 UFSAR Rev. 15 9.5A-145a area. Based on the low amount of combustible loading, the fire detection present, and the fact that redundant cabling required for shutdown has been provided with additional protection, the means of suppression available is adequate

to protect the hazard and provide the required separation.

(6) The charging system suction valve area which is located on the 718'-6" and 710'-6" elevations of the auxiliary building contains redundant circuitry for the charging pump suction valves 2CHS*LCV115D and B, 2CHS*MOV350 and 2CHS*FCV113A. The fire loading for this area is less than 1/2 hour. All cables in this area are routed in conduit. In addition, for radiation hazard reasons, these areas are restricted access and are out of normal plant travel routes. The cables for 2CHS*LCV115D have been adequately protected by a fire-wrap material. Due to the fact that only one out of the four valves has to operate, the area contains negligible combustibles and the area is provided with general area fire detection, hose racks and portable fire extinguishers; a fire in the area will not prevent safe shutdown and adequate separation is provided.

(7) Spurious Operation of the PORVs A deviation from the requirements of BTP CMEB 9.5-1, Section C.5.b has been identified relative to the separation of the electrical circuits of the pressurizer power operated relief valves and their associated motor operated block valves. The circuits for redundant valves which isolate the high-low pressure interface lines do not meet the separation criteria of C.5.b. A potential for spurious operation of the pressurizer power operated relief valves has been identified for fire areas ASP, CV-1, CV-2, CV-3, RC-1, SB-1, SB-2, and SB-3, and the normally open block valve could also be rendered inoperable. Alternate shutdown capability has not been provided for these fire areas. In the event of a serious fire in these areas, the operator will open the d-c circuit breakers to deenergize the electrical power to the PORV.

The PORV circuits affected are ungrounded 125 VDC circuits and are routed in thermoset cable. A single fire-induced cable-to-cable hot short will not result in spurious opening of the PORVs. With the power circuit deenergized, in order to open a single PORV, multiple shorts of the proper polarity, on thermo-set multiconductor cables, would be required. EPRI TR-1003326, Characterization of Fire-Induced Circuit Failures: Results of Cable Fire Testing, Final Report December 2002, indicates that inter-cable (cable to cable) shorting is much less likely than intra-cable shorts. One area discussed by this report is the potential duration of spurious operation events. The testing strongly suggests that fire induced hot shorts will likely self-mitigate (e.g., short to ground) after some limited period of time. The test data shows that a majority of the circuit failures resulting in spurious operation had a duration of less than 1 minute. Less than 10% of all failures lasted more than

BVPS-2 UFSAR Rev. 15 9.5A-145b 5 minutes, with the longest duration recorded for the tests equal to 10 minutes. From this it may be concluded that the chance of having two such faults at the same time on the specific conductors to cause a spurious actuation of sufficient duration to affect safe shutdown would be extremely unlikely. BV Design Analysis Calculation No. 10080-DMC-0820 has determined that no core damage would occur in the event of a spurious PORV opening under credible fire protection scenarios. Acceptability of this deviation is documented in accordance with 10080-DEC-0254. Item C.5.c, Alternative or Dedicated Shutdown Capability Item C.5.c(7) requires that the alternate safe shutdown equipment and systems be isolated from associated circuits such that a postulated fire will not prevent safe shutdown. Alternate safe shutdown capability, which has been provided for fire areas CB-1, CB-2, CB-3, CB-6, and CT-1, does not provide for isolation of the pressurizer PORVs in the event of multiple cable-to-cable hot shorts. Technical justification for the alternate shutdown fire areas is the same as documented under C.5.b above.

BVPS-2 UFSAR Rev. 0 9.5A-146

SUBJECT:

Hydrogen Piping Item C.5.d(5):

The SRP states that hydrogen lines in safety-related areas should be either designed to seismic Class I requirements, or sleeved such that the water pipe is directly vented to the

outside, or should be equipped with excess flow valves so that in case of a line break, the hydrogen concentration in the affected areas will not exceed 2 percent.

Difference From the SRP:

The term "Seismic Class I" is undefined and the Regulatory Guide 1.29 classification "Seismic Category I" is not applicable to hydrogen piping at BVPS-2 as described in the Regulatory Guide.

Justification:

BVPS-2 has seismically designed all hydrogen piping in safety-related areas to Seismic Category II requirements, as defined in UFSAR Section 3.2.1.2. This piping is designed and supported to withstand SSE inertia loading, and the integrity of the pressure boundary is maintained in accordance with Appendix F of the 1972 ASME Code Winter Edition which states that the faulted condition design procedures contained in subparagraph F-1300 are provided for limiting the consequences of the specified event. They are intended (see NA-1130) to assure that violation of the pressure retaining boundary will not occur in components or supports which are in compliance with these procedures. Therefore, the pressure boundary of piping designed in accordance with these criteria will remain intact during a seismic event and no leakage will result. BVPS-2 UFSAR Rev. 0 9.5A-147

SUBJECT:

Continuous Line-Type Heat Detectors Item C.5.e(2):

The Standard Review Plan states that cable trays containing portions of redundant safety-related cable systems outside the cable spreading room should be provided with continuous line-

type heat detectors. Difference from the SRP:

BVPS-2 has been equipped with alternate means of detecting cable fires. Justification:

Safety-related cable areas are provided with smoke detectors as part of the early warning detection system and will annunciate in the main control room and alarm locally. General area coverage smoke detector systems are provided in all areas containing safety-related cables except the reactor containment building (See deviation documented for Containment - General Area Detection, Item C.7.a(l)(c). The response time of smoke detectors is at least as effective in detecting cable fires as the line-type heat detectors.

BVPS-2 UFSAR Rev. 13 9.5A-148

SUBJECT:

Concentrated Cable Tray Areas Item C.5.e(2):

The Standard Review Plan states that manual hose stations may be relied upon to provide the primary suppression for safety-related cable trays of a single division that are separated from redundant cables by a 3-hour fire barrier and are normally accessible for manual firefighting if all of the following conditions are met:

(a) The number of equivalent standard 24 in. wide cable trays is six or less, (b) The cabling does not provide instrumentation control, or power to systems required to achieve and maintain hot shutdown, and 

(c) Smoke detectors are provided in the area of these cable routings, and continuous line-type heat detectors are provided in the cable trays. Difference from the SRP: The following areas do not have automatic fire suppression and

are provided with cable trays that: a) Exceed six trays

b) Contain cabling necessary for shutdown

c) Are not provided with continuous line-type heat detectors: Reactor Containment (RC-1)

Auxiliary Building (PA-3 and PA-4)

Justification: The reactor containment (Fire Area RC-1) contains concentrations of cable trays in excess of the six tray limit between the crane wall and containment wall, which have not been provided with automatic suppression. The cables in these trays are all IEEE-383 for safety related applications or similarly qualified for non-safety applications (Refer to Section 8.3.3 for further details), and the trays with major power cables ("L" and "H" cables) have been provided with metal tray covers. The cable trays have been laid out such that all trays can be effectively reached by a fire hose stream, and the fire severity for the

reactor containment is less then 1 hour. The safe shutdown analysis summary for this area is provided in Section 9.5A.1.3.29 and demonstrates that safe shutdown is not prevented

by a fire in the cable trays.

BVPS-2 UFSAR Rev. 13 9.5A-149 The Auxiliary Building (Fire Areas PA-3 and PA-4) contains four 30-inch wide cable trays. This exceeds the limit of six 24-inch wide trays as defined in BTP CMEB 95-1. These areas that contain slightly higher than recommended cable tray

concentration have been laid out such that all trays can be effectively reached by a hose stream.

The early warning smoke detection system assures that the fire brigade has sufficient time to respond to a fire. The fire severity for PA-3 and PA-4 is less than 1/2 hour each. Transient combustibles are administratively controlled and do not constitute a significant increase in combustible loading. The safe shutdown summaries for PA-3 and PA-4 (see Sections 9.5A.1.3.23 and 24, respectively) demonstrate that safe shutdown is not prevented by a fire in these areas. The smoke detection system, the fact that only IEEE-383 for safety related applications or similarly qualified cables for non-safety applications (Refer to Section 8.3.3 for further details) are used, required safe shutdown cables are adequately protected in place by a fire wrap material for PA-3 and PA-4, and the accessibility of all cable trays to fire hose streams, provide adequate assurance that any postulated fire can be readily

contained and that safe shutdown is not prevented.

BVPS-2 UFSAR Rev. 13 9.5A-150

SUBJECT:

Cable Rooms: CO Vs Water Item C.5.e(2):

The SRP states that in other areas where it may not be possible because of other overriding design features necessary for reasons of nuclear safety to separate redundant safety-related cable systems by 3-hour-rated fire barriers, cable trays should be protected by an automatic water system with open-head deluge or open directional spray nozzles arranged so that adequate

water coverage is provided for each cable tray. Such cable trays should also be protected from the effects of a potential exposure fire by providing automatic water suppression in the area where such a fire could occur. The capability to achieve and maintain safe shutdown considering the effects of a fire involving fixed and potential transient combustibles should be evaluated with and without actuation of the automatic suppression system and should be justified on a suitably defined basis.

Difference from the SRP: The following fire areas use CO as the primary automatic suppressant instead of water: a) Control Building (Fire Areas CB-1, CB-2, and CT-1) b) Cable Vaults (CV-1, 2, and 3) c) Service Building Elevation 745 ft-6 in. (SB-4) Justification: The automatic or manual, double-capacity, total flooding CO system, in conjunction with the hose rack stations and portable fire extinguishers, provides adequate protection to extinguish

fires and ensure the safety of these areas. Two potential fires are postulated for these areas: a short-circuit-induced cable fire and a fire involving transient combustibles. Hazardous quantities of transient combustibles are not expected in these areas for several reasons. First, the areas are not near any major plant traffic route. Second, maintenance and operations in these areas do not involve the use of combustible materials. Third, accessibility to these areas is restricted to personnel performing essential duties. The potential for a cable fire is limited by the use of IEEE 383 for safety related applications or similarly qualified cable for non-safety applications throughout (Refer to Section 8.3.3 for further details). The cable trays are provided with cable tray covers and/or bottoms to conform with Regulatory Guide 1.75.

Fire detection is provided by the early warning fire detection system which provides fire alarms locally and in the control room.

BVPS-2 UFSAR Rev. 0 9.5A-151 The CO system is designed to attain a 50-percent concentration as recommended for cable fires (NFPA-12). Automatic actuation of the CO system is provided by the "XL-3" fire detection system which is a "Priority" system with local and control room alarms. The alarms enable the control room to be aware of the

status and availability of the CO system at all times. A timed delay is provided in the CO initiation cycle to provide for personnel evacuation. CO supply capacity is available for a second manual application. CO will penetrate to the source of the fire and is less likely to cause damage to electrical equipment. Hose racks are provided at the entrance to the cable

spreading room, and all trays can be reached by hose streams. Penetrations to these areas are sealed to prevent leakage of CO to occupied spaces. Operating personnel of Unit 1 have had several years of experience with total flooding CO systems. All personnel are trained in alarm recognition and evacuation procedures. The systems are generally disarmed only during an outage for major maintenance functions, and a fire watch is

posted during the disarmed period. The system is not disarmed during daily operational activities in the area. In the unlikely event of a fire in this area, the fire brigade would be

required to have breathing apparatus. The cable trays located in these areas are utilized largely for instrumentation and control cables. These trays will be

provided with flat, unventilated covers and/or bottoms. The

presence of tray covers inhibits the ability of water to reach potential tray fires. CO by virtue of its gaseous state, will penetrate into the cable trays and provide fire suppression to the fire in its incipient stage and will prevent a deep-seated fire from occurring. Due to the stack arrangements of the cable

trays and the fact that the trays are provided with covers and/or bottoms, a ceiling-mounted automatic water suppression

system would not provide adequate assurance that a fire will be

extinguished. BVPS-2 UFSAR Rev. 0 9.5A-152

SUBJECT:

Control Room Ventilation Item C.5.f(3):

The SRP states that power supply and controls for mechanical ventilation systems should be run outside the fire area served by the system where practical.

Difference from the SRP:

The controls for the redundant ventilation systems serving the control room are located in the control room.

Justification: BVPS-2 relies on several alternate methods of ventilating the

control room if necessary. The primary smoke removal for the BVPS-2 control room is

provided by one of the two 100-percent capacity fans of the control room air conditioning system. If a single fire renders both fans inoperable, other methods of smoke removal are available. Since this is a common control room for both Units 1 and 2, the Unit 1 ventilation system, which is completely separated from the Unit 2 system, can be utilized. If additional smoke removal is required, the double doors to the outside can be opened for natural ventilation. If further ventilation is necessary, two portable gasoline driven emergency exhaust fans can be utilized. These fans are part of the fire brigade equipment inventory located in the brigade staging area.

BVPS-2 UFSAR Rev. 16 9.5A-153

SUBJECT:

Lighting of Yard Areas Item C.5.g(l):

The SRP states that fixed self-contained lighting consisting of fluorescent or sealed-beam units with individual 8-hour minimum battery power supplies should be provided in areas that must be manned for safe shutdown and for access and egress routes to and from all fire areas.

Difference from the SRP: BVPS-2 is equipped with emergency lighting for access and egress routes used in performance of alternate shutdown procedures. For outside yard areas, an alternate form of lighting is used for such routes. The fire brigade room has 2-hour rated emergency lighting instead of 8-hour rated lighting.

Justification:

For certain fire scenarios, the operators may be required to follow outdoor pathways to achieve and maintain safe shutdown

from outside the control room. The security perimeter lighting system consists of permanently

mounted lights on poles and on outside building walls. This permanent lighting system is powered from motor control center MCC-l-37 located in the security guardhouse which, on loss of offsite power, would be supplied from the security diesel generator (NHS-EG-1). This emergency diesel generator has a fuel supply capable of operating for at least 24 hours. This

system is common for both Units 1 and 2. The security perimeter lighting circuits powered from MCC-1-37

are not routed through any fire areas where safe shutdown equipment or cables are located. For all BVPS-2 fire areas of concern, the security diesel generator and transfer circuitry

are independent. Operators performing the alternate safe shutdown procedure are provided with flashlights to enhance the permanently installed outdoor yard area emergency lighting system. Portable lighting would supplement the fixed emergency lighting system to provide versatility and effectiveness for operators to perform their intended shutdown functions.

The security perimeter lighting system would provide emergency outside yard area lighting capability equivalent to the guidelines of BTP CMEB 9.5-1 (8-hour battery power supply) based

on the following:

a. The security perimeter lighting system including its emergency power supply are independent of fire areas where control room evacuation may be required under the postulated fire scenario.

BVPS-2 UFSAR Rev. 16 9.5A-154 b. The security lighting system provides an acceptable margin of safety equivalent to the guidelines of BTP CMEB 9.5-1.

c. Use of portable flashlights would offer more flexibility with respect to aiming which may be needed for unexpected transient hazards or any unanticipated

events. The 2-hour rated emergency lighting is adequate for the fire brigade room. The expected time duration for use of the fire brigade room as a staging area would be less than 30 minutes; therefore, 2-hour lighting is acceptable.

BVPS-2 UFSAR Rev. 0 9.5A-154a

SUBJECT:

Fire Detection Item C.6.a(l):

The Standard Review Plan states that detection systems should be provided for all areas that contain or present a fire exposure to safety-related equipment.

Difference from the SRP:

Certain areas that contain safety-related piping required for safe shutdown and which do not contain or present a fire hazard (that is, any cables present are in conduit, and any oils

present are contained in valves, piping, or pumps) will not be provided with fire detection coverage.

Justification:

Fire detection coverage is provided within areas that contain safety-related equipment/cables required for safe shutdown and where combustible loadings (cables and oils), which could

present a fire hazard, are normally present. The only safety-related equipment required for safe shutdown contained in the areas described above is the piping associated with the charging, service water, and component cooling water systems. These areas do not contain or present a fire hazard as defined above. Also, hazardous quantities of transient combustibles

would not be expected in these areas for the following reasons: a) These areas are not adjacent to or near any major plant traffic route.

b) Storage of transient combustibles in these areas is prohibited by plant administrative procedures.

c) Maintenance and operations activities in these areas do not involve the use of large quantities of combustible materials. d) The accessibility to these areas is restricted due to the security system.

Table 9.5A-3 provides the list of areas where fire detection coverage is not provided since they do not contain or present a fire hazard as defined above.

BVPS-2 UFSAR Rev. 0 9.5A-154b

SUBJECT:

Fire Hydrant Spacing Item C.6.b(7):

The Standard Review Plan states that hydrants should be installed approximately every 250 feet on the yard main system.

Difference from the SRP: Fire Hydrant No. 16, located outside of the southwest corner of

the Turbine Building, is located 340 feet from Fire Hydrant No. 15 which is located outside of the South Office Shops Building.

Justification: Fire Hydrant No. 16 has been relocated due to field interferences. Sufficient lengths of hose have been provided in the associated hose cart houses to provide coverage in the event of a fire. The specific hazards in the area are the main

transformer and the two station service transformers. These transformers have been provided with automatic deluge suppression systems.

BVPS-2 UFSAR Rev. 18 9.5A-155

SUBJECT:

Containment (General Area Detection)

Item C.7.a(l)(c):

The Standard Review Plan states that general area fire detection capability should be provided in the primary containment as

backup to detection systems for specific hazards.

Difference from the SRP:

The reactor containment is not provided with a general area

detection system.

Justification:

Specific hazards within the reactor containment are provided with fire detection systems. The residual heat removal (RHR) pumps and cable penetrations are provided with smoke detectors and a water spray deluge system. The reactor coolant pumps have been provided with an oil collection system.

Due to the compartmentalization of the containment, the fact that fire detection is provided for specific hazards, the low amount of transient combustibles, and the large volume of the containment along with the dilution caused by the ventilation high recirculation flow, general area fire detection would be

ineffective.

BVPS-2 UFSAR Rev. 16 9.5A-156

SUBJECT:

Control Room Item C.7.b:

The SRP states that:

a. Peripheral rooms in the control room complex should have automatic water suppression and should be separated from the control room by noncombustible construction with a fire resistance rating of 1 hour. Ventilation system openings between the control room and peripheral rooms should have automatic smoke dampers that close on operation of the fire detection or suppression system.

b. Area automatic fire suppression should be provided for underfloor and ceiling spaces if used for cable runs unless all cable is run in 4 in. or smaller steel conduit. c. There should be no carpeting in the control room.

Differences from the SRP:

a. The shift supervisor's office is constructed as an integral part of the control room and does not require 1 hour separation or dedicated ventilation or suppression features.

b. Aluminum conduit is run under a portion of the raised floor section. Steel conduit, equal to or smaller than 4 inches, is used in the raised floor sections for the operator consoles, which meets the requirements of the BTP.

c. Carpeting may be provided in the control room to enhance operator comfort and reduce fatigue (human factors).

Justification:

a. The shift supervisor's office is constructed of low hazard materials. Its contents are those which would normally be expected to be found in the control room regardless of the addition of the office walls. Since

the office is largely constructed of glass and the control room is occupied at all times, fires in the room would be quickly noticed and extinguished using

equipment available in the control room.

b. The aluminum conduit is located in a small portion of raised floor which is less than 3 feet in width and exists between the vertical section and benchboard section of the main control board. Since smoke

detectors are installed in the vertical board section and the main control room is continuously manned, a fire will be detected in its incipient stages and

extinguished.

BVPS-2 UFSAR Rev. 16 9.5A-157 c. The benefits to control room comfort outweigh the slight potential for igniting the carpet based upon the carpet test results. The carpeting has a critical radiant flux

which exceeds the minimum of 0.45 watts per cm (ASTM E648) used to define Class 1 interior finishes in

accordance with NFPA 101 Life Safety Code.

BVPS-2 UFSAR Rev. 13 9.5A-158

SUBJECT:

Cable Spreading Room Item C.7.c:

The Standard Review Plan states that:

a. The primary fire suppression in the cable spreading room should be an automatic water system.

b. A 3 feet wide by 8 feet high aisle separation should be provided between tray stacks.

c. Continuous line-type heat detectors should be provided for cable trays.

Differences from the SRP:

a. The primary fire suppression system for the BVPS-2 cable spreading room is an automatic or manual, double-capacity, total flooding CO system. Hose rack stations and portable fire extinguishers are provided as backup suppression.

b. There are certain aisles in the cable spreading room which are partially blocked by structural members resulting in aisle dimensions which are less than the 3 feet wide by 8 feet high criterion.

c. BVPS-2 has been equipped with alternate means of detecting cable fires.

Justification:

a. The automatic or manual, double-capacity, total flooding CO system, in conjunction with the hose rack stations and portable fire extinguishers, provides adequate protection to extinguish fires and ensure the safety of

the cable spreading room.

Two potential fires are postulated for the cable spreading areas: a short-circuit-induced cable fire and a fire involving transient combustibles. Hazardous quantities of transient combustibles are not expected in these areas for several reasons. First, the areas are not near any major plant traffic route. Second, maintenance and operations in these areas do not involve the use of combustible materials. Third, accessibility to these areas is restricted to personnel performing essential duties. The potential for a cable fire is limited by the use of IEEE 383 for safety related applications or similarly qualified cable for non-safety applications throughout (Refer to Section 8.3.3 for further details). The cable trays are provided with

BVPS-2 UFSAR Rev. 0 9.5A-159 cable tray covers and/or bottoms to confirm with Regulatory Guide 1.75. Fire detection is provided by the early warning fire detection system which provides fire alarms locally and in the control room. The CO system is designed to attain a 50-percent concentration as recommended for cable fires (NFPA-12). Automatic actuation of the CO system is provided by the "XL-3" fire detection system which is a "Priority" system with local and control room alarms. The alarms

enable the control room to be aware of the status and

availability of the CO system at all times. A timed delay is provided in the CO initiation cycle to provide for personnel evacuation. CO supply capacity is available for a second manual application. CO will penetrate to the source of the fire and is less likely to cause damage to electrical equipment. Hose racks are provided at the entrance to the cable spreading room, and all trays can be reached by hose streams. Penetrations to the control room complex are sealed to prevent leakage of CO to occupied spaces. Operating personnel of Unit 1 have had several years of experience with total flooding CO systems. All personnel are trained in alarm recognition and evacuation procedures.

The systems are generally disarmed only during an outage for major maintenance functions, and a fire watch is posted during the disarmed period. The system is not disarmed during daily operational activities in the area. In the unlikely event of a fire in this area, the

fire crew would be required to have breathing apparatus. The cable trays located in this area are utilized largely for instrumentation and control cables. These trays will be provided with flat, unventilated covers and/or bottoms. Power cables are run in rigid conduit. The presence of tray covers inhibits the ability of water to reach potential tray fires. CO by virtue of its gaseous state will penetrate into the cable trays and provide fire suppression to the fire in its incipient stage and will prevent a deep-seated fire from occurring. Due to the stack arrangements of the cable

trays and the fact that the trays are provided with covers and/or bottoms, a ceiling-mounted automatic water suppression system would not provide adequate assurance

that a fire will be extinguished.

Finally, in the unlikely event of a total fire area burnout, BVPS-2 has alternate shutdown capability.

BVPS-2 UFSAR Rev. 0 9.5A-160 b. The BVPS-2 cable spreading room is accessible to the fire brigade from three remote and separate entrances. Sufficient aisle separation between cable tray stacks is provided for adequate accessibility for fire fighting. Those stations are located at each end of the cable spreading room and at the cable tunnel interface and are capable of providing hose stream coverage to the entire

room, thereby enhancing manual fire fighting capability.

c. Refer to the justification provided for Item C.5.e(2).

BVPS-2 UFSAR Rev. 0 9.5A-161

SUBJECT:

Safety-Related Pumps Item C.7.k:

The Standard Review Plan recommends that pump houses and rooms housing redundant safety-related pump trains should be separated from each other and from other areas of the plant by fire

barriers having at least 3-hour ratings. Difference from the SRP:

The fuel pool cooling pumps are not required for safe shutdown following a fire and are protected by means other than 3-hour barriers. (For safety-related pumps and tanks used for safe shutdown, see Item C.5.b - Safe Shutdown Components.)

Justification: The fuel pool cooling pumps are not required for safe shutdown as a result of fire in any plant area. Fire detection is accomplished by the use of ionization detectors, which have audible alarms locally and audiovisual annunciation in the main control room. Portable extinguishers and hose rack stations are available for fire suppression.

These pumps are located in areas with low combustible loading. Refer to the fire hazards analysis for area FB-1. In the event that both fuel pool cooling pumps are lost, the fuel pool can be cooled with service water through a connection provided for this purpose. BVPS-2 UFSAR Rev. 0 9.5A-162

SUBJECT:

New Fuel Area Item C.7.1:

The Standard Review Plan states that automatic fire detection should alarm and annunciate in the control room and alarm locally. Difference from the SRP:

Automatic detection in the new fuel storage area is not required.

Justification: The new fuel storage area is an enclosed cubicle within the fuel

building. Combustible loading in the area, and the building in general, is extremely low. Administrative controls will be implemented for the new fuel storage area such that the door

will be locked and combustible storage in the area will be prohibited. A postulated fire in any area of the fuel building will not impact the ability to safely shut down the plant.

Since the fuel building access is controlled, and the building is a low traffic area, potential for accumulation of transient combustibles is negligible. Fire hose stations and portable

extinguishers are provided.

BVPS-2 UFSAR Rev. 0 9.5A-163

SUBJECT:

Spent Fuel Pool Area Item C.7.m:

The Standard Review Plan states that automatic fire detection should alarm and annunciate in the control room and alarm locally. Difference from the SRP:

Automatic detection in the spent fuel pool area is not required. Justification:

The spent fuel pool area is void of any concentration of combustibles which could pose a threat to the building or, more

importantly, plant safety in general. A postulated fire in any area of the fuel building will not impact the ability to safely shut down the plant. Since the fuel building access is controlled, and the building is a low traffic area, potential for accumulation of transient combustibles is negligible. The fuel pool cooling pumps are provided with detection coverage by ionization detectors which alarm locally and in the control room. Fire hose stations and portable extinguishers are provided.

BVPS-2 UFSAR Rev. 0 9.5A-164

SUBJECT:

Radwaste and Decontamination Areas Item C.7.n:

The Standard Review Plan states that automatic fire suppression and detection should be provided.

Difference from the SRP: Radwaste and decontamination areas are provided with partial suppression and/or detection to the extent necessary considering the fire hazards in the area. This may include automatic suppression or detection for specific hazards only.

Justification:

Radwaste and decontamination areas are considered to be the waste handling building (WH-1), the condensate polishing building (CP-1), and the decontamination building (FB-1).

The condensate polishing building area (CP-1) is largely free of combustibles which could be considered significant hazards. For areas such as the resin storage area, and the primary chemistry lab, where concentrations of combustibles occur, automatic water suppression with control room indication is provided. Local

alarms are also provided. The decontamination building is void of any concentration of

combustibles which could pose a threat to the building, or more importantly, plant safety in general. Automatic detection and suppression are not necessary.

The waste handling area (WH-1) is essentially free of combustibles which could be considered significant hazards. For the radwaste baler area where concentrations of combustibles occur, automatic water suppression with control room indication is provided. Local alarms are also provided.

All of these buildings are separated from other structures by 3-hour fire barriers and contain no equipment used for safe

shutdown of the plant. Manual hose stations and portable extinguishers are provided throughout the buildings.

BVPS-2 UFSAR Rev. 8 9.5A-165 9.5A.3 References for Section 9.5A CEI 1985. Letter dated August 1, 1985, from M. R. Edelman (Cleveland Electric Illuminating Company) to B. J. Youngblood (U.S. Nuclear Regulatory Commission) proposing revised conduit sealing criteria.

USNRC 1985. Supplemental Safety Evaluation Report (SSER) 7 dated November, 1985, for Cleveland Electric Illuminating Company's Perry Nuclear Power Plant (Document No. 50-440)

BVPS-2 UFSAR Tables for Section 9.5A

BVPS-2 UFSAR Rev. 10 1 of 4 TABLE 9.5A-2 FIRE DOORS WITH SECURITY MODIFICATIONS Door No. Areas Separated Fire Severity

  (hours)

Type of Fire Suppression Primary Backup A-10-1 PA-3 Stairwell <1/2 <1/2 Portable ext.

Portable ext. Hose rack

Hose rack

A-12-1 CT-1

Stairwell <3

<1/2 Total flood COPortable ext. Portable ext.

Hose rack

Hose rack A-18-2 PA-3 Stairwell <1/2 <1/2 Portable ext.

Portable ext. Hose rack

Hose rack A-30-1 Hallway Stairwell <1/2 <1/2 Portable ext.

Portable ext. Hose rack

Hose rack A-35-2 CV-1

Hallway <2 <1/2 Total flood COPortable ext. Portable ext. Hose rack Hose rack

A-35-6 WH-1

PA-3 <1/2

<1/2 Portable ext.

Automatic Sprinkler (Radwaste Area)

Portable ext. Hose rack

Hose rack A-35-7 PA-3 Stairwell <1/2 <1/2 Portable ext.

Portable ext. Hose rack

Hose rack A-45-1 SB-3

Stairwell <1 <1/2 Total flood COPortable ext. Portable ext. Hose rack Hose rack A-55-1 CV-3

Stairwell <2

<1/2 Total flood COPortable ext. Portable ext.

Hose rack

Hose rack A-55-3 PA-4 Stairwell <1/2 <1/2 Portable ext.

Portable ext. Hose rack

Hose rack A-60-1 SB-4 Stairwell <1/2 <1/2 Portable ext.

Portable ext. Hose rack

Hose rack A-73-3 PA-5 Stairwell <1/2 <1/2 Hose rack

Portable ext. Portable ext.

Hose rack BVPS-2 UFSAR Rev. 10 2 of 4 TABLE 9.5A-2 (Cont)

Door No. Areas Separated Fire Severity

  (hours)

Type of Fire Suppression Primary Backup A-74-1 PA-5 WH-2 <1/2 <1/2 Hose rack

Automatic

Sprinkler Portable ext. Portable ext.

Hose rack SB-30-1 SB-1 Stairwell <1 <1/2 Portable ext.

Portable ext. Hose rack

Hose rack SB-30-2 SB-1 SB-6 <1 <1/2 Portable ext.

Portable ext. Hose rack

Hose rack SB-30-3 SB-1 SB-7 <1 <1/2 Portable ext.

Portable ext. Hose rack

Hose rack SB-30-4 SB-2 SB-8 <1 <1/2 Portable ext.

Portable ext. Hose rack

Hose rack SB-30-5 SB-2 SB-9 <1 <1/2 Portable ext.

Portable ext. Hose rack

Hose rack SB-30-6 SB-2 Stairwell <1 <1/2 Portable ext.

Portable ext. Hose rack

Hose rack SB-45-1 SB-3

Stairwell <1 <1/2 Total flood CO Portable ext. Hose rack Hose rack SB-45-2 SB-3

Pipe chase <1 <1/2 Total flood COPortable ext. Portable ext.

Hose rack

Hose rack SB-45-3 SB-3 Stairwell <1 <1/2 Total flood COPortable ext. Portable ext. Hose rack Hose rack

SB-60-2 SB-4 Stairwell <1/2 <1/2 Portable ext.

Portable ext. Hose rack

Hose rack SB-80-1 SB-5 PA-5 <1/2 <1/2 Hose rack

Hose rack Portable ext.

Portable ext. F-35-1 FB-1 Outside <1/2 <1/2 Portable ext.

Portable ext. Hose rack

Hose rack F-67-1 FB-1 PA-1 <1/2 <1/2 Portable ext.

Hose rack Hose rack

Portable ext. BVPS-2 UFSAR Rev. 0 3 of 4 TABLE 9.5A-2 (Cont)

Door No. Areas Separated Fire Severity

  (hours)

Type of Fire Suppression Primary Backup CV-35-1 CV-1 Hallway <2

<1/2 Total flood COPortable ext. Portable ext.

Hose rack

Hose rack CV-35-2 Stairwell Hallway <1/2 <1/2 Portable ext.

Portable ext. Hose rack

Hose rack CV-35-3 CV-1

SB-1 <2 <1 Total flood COPortable ext. Portable ext. Hose rack Hose rack

CV-67-1 PA-5 CV-5 <1/2 -- Hose rack

Portable ext. Portable ext.

Hose rack CV-80-1 SB-5 Stairwell <1/2 <1/2 Hose rack

Portable ext. Portable ext.

Hose rack DG-32-2 DG-2

Outside <3 <1/2 Total flood COPortable ext. Portable ext. Hose rack Hose rack DG-32-3 DG-1

Outside <3

<1/2 Total flood COPortable ext. Portable ext.

Hose rack

Hose rack DG-32-4 DG-1 Outside <3 <1/2 Total flood COPortable ext. Portable ext. Hose rack Hose rack

W-22-1 WH-1

Stairwell <1/2

<1/2 Portable ext.

Automatic sprinkler (Radwaste Area)

Portable ext. Hose rack

Hose rack

BVPS-2 UFSAR Rev. 0 4 of 4 TABLE 9.5A-2 (Cont)

Door No. Areas Separated Fire Severity

  (hours)

Type of Fire Suppression Primary Backup W-35-1 WH-1 CP-1 <1/2

 <3 Portable ext. 

Automatic

sprinkler (Radwaste Area) Portable ext.

Hose rack

Hose rack W-35-2 WH-1

Stairwell <1/2

 <1/2 Portable ext. 

Automatic

sprinkler (Radwaste Area) Portable ext.

Hose rack

Hose rack

W-44-1 WH-1

Stairwell <1/2

 <1/2 Portable ext. 

Automatic

sprinkler (Radwaste Area) Portable ext.

Hose rack

Hose rack

S-35-68 CB-3 Stairwell <1/2 <1/2 Portable ext.

Portable ext. Hose rack

Hose rack C-35-4 CP-1 Stairwell <3 <1/2 Portable ext.

Portable ext. Hose rack

Hose rack C-74-7 CP-1 CP-1D (Primary Chem Lab)

<3 

<3 Portable ext.

Automatic

sprinkler Hose rack

Portable ext.

GW-35-1 Gaseous Waste Storage Vault Stairwell <1/2

<1/2 Portable ext. 

Portable ext.

BVPS-2 UFSAR Rev. 12 1 of 1 TABLE 9.5A-3 AREAS CONTAINING SAFETY-RELATED PIPING REQUIRED FOR SAFE SHUTDOWN WHICH DO NOT CONTAIN OR PRESENT A FIRE HAZARD (FIRE DETECTION NOT PROVIDED) Fire Area Description Elevation Remarks PA-3 Auxiliary 710'6" Auxiliary Building basement floor area not provided with

general area detection. PA-3 Auxiliary 718'6" General area detection provided for aisle-ways and

blender cubicle. Individual cubicles and pipe vault on

west side of area are not provided with detection. PA-5 Auxiliary 773'-6" Component Cooling Surge Tank cubicle not provided with

general area detection.

DG-1 DG-2 Diesel Generators (purple & orange) 759'-0" Diesel Generator Building Top elevation not provided with

general area detection. PT-1 Pipe Tunnel 725'0" Pipe tunnel around Safeguards Building not provided with

general area detection. SG-1N SG-1S North & South

Safeguards 737'6" Recirculation spray pump cubicle and hydrogen recombiner cubicle not

provided with general area detection. VP-1 VP-2 BV-2 Service Water Valve Pits 718'6" The BV-2 Service Water Valve Pits (VP-1 & VP-2) are not provided with general area detection.}}