ML20039D634
| ML20039D634 | |
| Person / Time | |
|---|---|
| Site: | Prairie Island  |
| Issue date: | 12/18/1981 |
| From: | NORTHERN STATES POWER CO. |
| To: | |
| Shared Package | |
| ML20039D631 | List: |
| References | |
| TAC-11094, TAC-11095, NUDOCS 8201050290 | |
| Download: ML20039D634 (110) | |
Text
{{#Wiki_filter:- l l l l l 9 NORTHERN STATES POWER COMPANY PRAIRIE ISIAND NUCLEAR GENERATING PIANT I UNITS 1 & 2 DOCKET NOS. 50-282 50-306 FIRE PROTECTION SAFE SHITfDOWN ANALYSIS COMPLIANCE WITH 10 CFR PART 50, APPENDIX R, SECTION III.C L L Prepared by: Gasser Associates Submitted: December 18, 1981 I I l
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r: IABLE OF CONTENTS Page 1.0 Introduction 1 2.0 Description of Functions and Equipment Required 2 for Hot and Cold Shutdown 3 2.1 General Description 2 2.2 Function 1 - Emergency Electrical Power Supply 3 2.3 Function 2 - Removsl of Decay Heat 4 2.4 _ Function 3 - Maintenance of the Reactor Coolant 6 Systen Inventory 2.5 Function 4 - Borate the Reactor Coolant System 8 to Cold Shutdown Xe Free Conditions 2.6 Function 5 - Cool the Reactor Coolant System to 8 Cold Shutdown Conditions 2.7 Function 6 - Monitor Critical System Parameters 8 2.8 Support Functions
) 9 3.0 Description of Method of Analysis to 4.0 Results of Analysis 12 4.1 Primary Components and Equipment 12 4.2 Associated ~ Circuits 13 5.0 Corrective Actions 17 5.1 Hot Shutdown Functions 17 5.2 Cold Shutdown Functions 18 6.0 Plans and Schedules 19 e
7.0 Exemption Requests 20 ,o TABLE OF CONTENTS (cont) l l i I TABLES ~ Page 1 Safe Shutdown Equipment List - Units 1 & 2 1-1 4 .
- 2 Safe Shutdown Equipment and Cable Matrices 2-1 3
. 3 Separation - Hot Shutdown Equipment 3-1 j in Conunon Fire Area 4
0 4 Separation - Cold Shutdown Equipment '4-1 1 in Conunon Fire Area > 5 Valves Subject to Spurious Operation 5-1 FIGURES i 1 Cable Routing Tabulation - Example 22 i ! 2 Fire Hazards Sununary 23 i i l-
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1.0' INTRODUCTION This report was developed to describe the Safe Shutdown Analysis ; conducted for Prairie Island Nuclear Generating Plant, Units 1 ! 1
, and 2, in accordance with 10CFRSO Appendix R, Section III G, and the results of that analysis. Corrective actions, including plans and schedules for modifications, and exemption requests are also provided in this report.
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2.0 DESCRIPTION
OF FUNCTIONS AND EQUIPMENT REQUIRED FOR HOT AND (OLD
, sg SHUTDOWN 2.1 General Description It has been demonstrated previously in the Prairie Island Final Safety Analysis Report that a loss of all a-c power to the station auxiliaries will not result in any adverse condition in the reactor e
core as long as decay heat is transfered from the reactor coolant system. Additionally,.the analysis shows that there will be no loss of reactor coolant from the pressurizer relief valves. With this being the case, then the analysis must demonstrate that the fire will~ not affect the ability of the operator to (1) provide emergency electrical power, (2) maintain heat transfer from the reactor coolant system to the environment, (3) maintain reactor coolant inventory, (4) borate the reactor. coolant system to cold shutdown, Xe free (5) continue to cool the reactor coolant system to cold shutdown conditions, and (6) monitor critical reactor
,, coolant system parameters. The systems which will be used to (q) l fulfill the functions for safe shutdown are as follows.
Function 1 - Provide emergency electrical power - emergency diesel generators, batteries, safeguards power buses, and associated distribution equipment Function 2 - Maintain heat transfer from the reactor coolant system to the environment - condensate storage tank , auxiliary feedwater, steam safety relief valves, power operated relief valves, cooling water system. Function 3 - Maintain reactor coolant inventory - charging system, safety injection system, RWST, component
. cooling system, cooling water system.
Function 4 - Borate the reactor coolant to cold shutdown. Xe free - charging system, safety injection system, RWST, component cooling system, cooling water system. (3 [)
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Function 5 - Cool the reactor coolant system to cold shutdown conditions - residual heat removal system,. component cooling system, cooling water system. Function 6 - Monitor critical system parameters - process instru-ments and sample system. The following is a description of the plant systems required to , perform the desired functions listed above. The systems described are for one unit of this two unit plant. The description applies to both units. Two trains of equipment are designated for each function. A detailed equipment list is provided in Table 1 2.2 Function 1 - EMERGENCY ELECTRICAL POWER SUPPLY Instrument and Control Power Non-interruptible loads are automatically transferred to the battery-inverter sources of power. These include:
- a. The four safeguards instrument buses for both Units (Panels 112, 111, 114, and 113 for Unit 1 and Panels 211, 213, 214, fN and 212 for Unit 2).
t') b. Control room annunciators.
- c. Computer buses (Panels 116 and 216).
- d. Public address and telephone systems.
- e. Emergency lighting,
- f. In general, any instrumentation needed for operation of safe shutdown equipment or for personnel safety.
Emergency (Safeguards) A-C Power Two emergency diesel generators are provided which serve both units. The emergency diesel generatore will start automatically on loss of offsite power. Aloadrejectionandvoltaghrestor-ation scheme assures that the diesel generators are not overloaded. The diesel engines themselves are started using air reservoirs which need no external services except control signals powered from non-interruptible power. Fuel for the diesels is via gravity feed for the initial hours of operation. Fuel for subsequent op-eration is supplied from the dedicated emergency diesel frol (v) i
- = - ,. . -
storage tank. The fuel transfer pump is powered from a safe-(*g 1x, guards bus. Cooling water inlet to the engine is via an air-operated inlet valve which' fails open. 4 Power Distribution In addition to the generation of emergency power, the appropriate power distribution equipment (safeguards buses and motor control centers) must remain free of fire damage to assure that safe shutdown equipment will function. Two independent trains of safeguards buses, DC panels and motor control centers, and cabling are provided. 2.3 Function 2 - REMOVAL OF DECAY HEAT Removal of decay heat after reactor trip is maintained by natural circulation within the reactor coolant loops. Feedwater must be supplied to the steam generators, where it absorbs heat and is
-discharged as steam. Feedwater is supplied by the auxiliary feed-water system, and steam is discharged via the steam safety relief m
) vdives and the power operated relief valves.
Auxiliary Feedwater Two auxiliary feedwater pumps are provided; one steam driven turbine pump and one motor driven pump. The steam driven aux-iliary feedwater pump starts automatically on a. loss of main feedwater pumps, and it will operate without additional electrical' power. It is driven by steam from the steam generators. The turbine auxiliary feedpump can be supplied with driving steam from either steam generator associated with that unit. The two steam isolation valves are motor operated valves powered from a safeguards bus and are maintained in the open position. The air
, operated steam inlet valve fails open on loss of air. A governor throttle valve is provided to prevent turbine overspeed. This - - valve is normally open. The driving steam exhausts to atmosphere.
The turbine bearings are charged with oil once each 24 hours to assure sufficient lubrication will be available for turbine start-up. Once started, a shaft driven oil pump supplies lub-f-* rication for continued operation. U
/ The motor driven auxiliary feedwater pump is powered from the diesel generator and is automatically loaded according to the voltage restoration scheme. The oil pump which supplies lubri-cation for pump operation is powered from a safeguards power source.
There are two sc. trees of water supplying the auxiliary feedpump. , suction header. The first is the condensate storage system via a header which is normally supplied by both Unit 1 and 2 condensate storage tanks. The suction valves are kept in an open~ position to assure condensate will be available for the pumps. The second source of auxiliary feedwater suction is from the cooling water system. Supply valves to the punp suction are motor operated and powered from safeguards buses. The cooling water system also supplies water for turbine casing cooling and for lube oil cooling for both pumps. - The inlet valves are air operated fail open. The auxiliary feedwater pump discharge valves are maintained in an open position to assure auxiliary feedwater will be supplied to O da steam generators. Power Operated Relief Valves and Steam Safety Relief Valves Power operated relief valves are available for controlled release of steam from the steam generators thereby controlling cooldown. rate. These valves are air operated and have handwheels avail-able for manual operation. The power to these valves is supplied from safeguards buses. In addition, each steam generator is equipped with five self-actuating safety relief valves to assure a heat transfer path to the environment. These valves open at a pre-set pressure automatically and require no external actuation. Cooling Water System . The diesel driven cooling water pumps start automatically on a loss of normal power to the motor driven cooling pumps. The engines themselves are started using air reservoirs which need no external services except control signals powered from the g non-interruptible power source. The receivers can be recharged from air compressors provided for each diesel cooling pump. Fuel for the diesels is provided via gravity feed initially. O V Fuel for subsequent operation is supplied from dedicated emer-gency diesel fuel storage tanks. Two tanks are provided with one normally aligned to each diesel, but with a manual cross-tie available for either tank to supply either diesel. Fuel transfer pumps are powered from safeguards buses. The cooling water pumps supply their own requirements for engine
. jacket cooling and lubrication and gear oil cooling. An air op-erated' valve admits cooling water to the engine jacket cooling heat exchanger. The air supply is provided from the diesel starting reservoirs, and fails open (cooling water inlet open) on loss of air. No valves are required to change position to admit cooling water to the gear oil cooler.
Cooling water pumps are sized so that one pump can supply the cooling requirements of both units. The pump discharges are manifolded so that either pump may supply either unit. L) 2.4 Function 3 - MAINTENANCE OF THE REACTOR COOLANT SYSTEM INVENTORY Addition of wat'er to the reactor coolant system will be accomplished by using either charging system Train A or the safety injection system Train B. The Train A charging system utilizes a charging pump which is powered from_a safeguards power supply. The pump normally takes suction from the volume control tank. An alternate source of water provided for the charging pump is the refueling water storage tank (RWST) The RWST is maintained at a specified level of boron concentration. Water discharged from the charging pump enters the reactor coolant system through two normal flow paths. The first
. is the seal injection line which contains normally open manual valves and will be in service whenever the plant is in operation.
The second path is via the normal charging line which will also be in service during plant operation. This line contains one air operated valve which fails open and one air operated valve which
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) fails closed with an open bypass line around it.
i [) Seal leak-off from the reactor coolant pumps will return to the
-- volume control tank. Component cooling water will be supplied to the seal leak-off return heat' exchanger to cool the water prior' to entering the volume control' tank.
The Train B safety injection system utilizes a safety injection . pump which11s powered from a safeguards power supply.- The pump a will take water from the RWST through a normally closed motor valve powered from a safeguards power supply. The flow path from the pump to the reactor coolant system is maintained open. The valves are motor operated valves which are open and the: motor breakers are locked in the open position.. When the safety in-jection pump is used for adding water to the reactor coolant system, the component ' cooling system is required to cool the safety injection pumps. and to prevent damage to the reactor coolant pump seals. Component Cooling Water System ( Cooling for the seal water heat exchanger,' safety injection' pump, reactor coolant pump thermal barriers .and residual heat removal system will be provided by A and B trains of=the component cooling water system. The component cooling water system is~ designed to provide a closed ! cooling water loop which transfers heat from systems containing !. highly radioactive fluids to the cooling water system which uses i water from the river. Each train is provided with a pump, heat. exchanger.necessary piping and valves and a shared surge tank. The component. cooling pumps are powered from independent safeguards buses. The system is equiped.with motor operated valves to allow f either train of pump and heat exchanger to serve all safeguards
.- cooling loads. These valves are powered from safeguards power sources. The cooling water system which cools the component cooling system has been previously described.
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^N 2.5 Function 4 - BORATE THE REACTOR COOLANT SYSTEM TO COLD SHUTDOWN C' Xe FREE CONDITIONS Boration of the reactor core to cold shutdown conditions will be accomplished using the same systems as described above in Section 2.4. . For boration, the charging system will use only the RWST as a source of water.
2.6 Function 5 - COOL THE REACTOR COOLANT SYSTEM TO COLD SHUTDOWN e CONDI".9NS The auxiliary feedwater system and the power cperated relief valves will be used as described in Section 2.3 to cool the reactor coolant system and reduce pressure until the coolant pressure is below 500 PSIG. Once below 500 PSIG the residual heat removal system will continue the cooling process to cold shutdown and then maintain those con-ditions as long as necessary.
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The residual heat removal (RHR) system is designed to transfer
- decay heat from the reactor coolant system to the component cool-ing water system, and thereby eventually to the environment. It further has the ability to transfer water from the refueling water storage tank to the reactor for make-up.
Two RHR trains are provided which each consist of suction piping to remove water from the reactor coolant system, an RHR pump, discharge piping to an RHR heat exchanger, and return piping for returning cooled reactor coolant to the reactor coolant system. Cross-over lines with manual valves are provided to allow either pump to operate with either heat exchanger. Power for pumps and
, motor valves for the two trains of RHR is provided by independent safeguards power sources. .
2.7 Function 6 - MONITOR CRITICAL SYSTEM PARAMETERS Process Instrumentation System Decay heat removal, via natural circulation, and availability [' ' . of a heat sink are observable by monitoring reactor coolant s
' system pressure' and temperature and steam generator level in at l , least one steam generator. _ Maintenance of reactor. coolant system t
inventory is monitored by pre ~ssurizer level. When cooldown has. progressed to the point of using the residual heat removal = system, monitoring of steam generator level is not necessary. The only 1 parameter needed to monitor maintenance of cold shutdown is reactor-coolant system temperature. Redundant process instrumentation channels are available for each of the above parameters. Sample System The process sample system is provided to allow a sample of reactor ) coolant to be drawn for chemical analysis. Reactor coolant chem-istry and in particular, boron concentration , will be monitored in this way. The system is equipped with series isolation valves and a sample cooler'for each sample point. The coolers are served by the component cooling system. 2.8 SUPPORT FUNCTIONS Station and Incerument Air System Three station air compressors powered from safeguards buses are provided which can supply filtered dehumidified air to control valves throughout the plant. The system also provides unfiltered air to the station air distribution system for maintenance and other service use. Isolation valves are provided which are capable of isolating the supply to the station air system in the event of a loss of pressure in that portion of the system which may threaten the supply for vital instrument use. One compressor only is required for instrument support. Two compressors, one from each train, were evaluated in chis analysis. Om
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3.0 DESCRIPTION
OF METHOD OF ANALYSIS kJ . Appendix R requires that one of the two alternate systems intended to.
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provide a hot shutdown function, must remain free of damage in the event of a fire in any single fire area, and that thi.a be demonstrated by analysis.
.- The analysis was accomplished by identifying the' functions-required for hot and cold shutdown, and identifying the systems which could-perform those functions. Two alternate. systems or trains'of a single system were chosen which were then analyzed in detail.
Within the chosen systems the portions of the system required to operate were identified, and the individual active components listed. The flow paths and circuits required were identified on P.& ID's, electrical drawings and circuit diagrams. A tabulation.of equipment, which *--in it belonged to, the time period in.which it was required to operate, control and power cabling serving the equipment, associated remote devices, and other information was assembled. Using NSP computer printout (NC-40099, 5-12-81, Cable Identification and Routing List) each cable identified-as required for safe shutdown was listed by system and then by function, i.e., from 125V distribution panel 26 to terminal box 2480, from terminal box 2480 to hot shutdown panel, etc. Also, the cable trays or conduit thru which each cable-passed were listed. This tabulation of information was set up so that A train ard B train functions were shown opposite each other. An example of the form of this tabulation is shown in Figure 1. Physical equipment arrangement drawings and cable tray arrangement drawings were obtained which also depicted fire area boundaries. Using' ,
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i the previously prepared flow sheets and the drawings, each item of safe shutdown equipment was located and each cable tray or conduit serving ' s that equipment was traced to the fire areas in which the active comp-- c
.onents were found. A second tabulation was compiled similar to the first which indicated fire areas for each piece of equipment or cabling, f
j A column was provided in this tabulation for recording spatial separ-ation of trays carrying cables serving similar functions in redundant
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trains.
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These tables were then used to perform an area by area physical review
\ of the plant.
The physical review was conducted on cable trays, equipment location,
, fire area characteristics, etc. , on a two (2) part basis.
- 1. Where A & B trains were located and routed in separate fire areas, a visual inspection was made to assure that components were in the proper designated area.
- 2. Where system components or redundant trains were located in the same fire area, physical measurements were made to determine horizontal separation.
If distance between cable trays or equipment serving redundant functions did not meet the minimum 20' separation criteria, the measurement was conservatively rounded to the lower whole figure. (Example - distance between trays LAG-TA24 and 1AG-TBS was measured at 7'-8", recorded as 7'.) In determining horizontal distance between cable trays or equipment in redundant divisions, no intervening combustible material or fire
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hazards were permitted. Cables in cable trays or conduit were not considered to be combustible material for this purpose. e E m 4.0 RESULTS OF ANALYSIS
,,) 4.1 Primary Components and Equipment-The analysis. determined that areas exist within 'the plant where redundant components or cables for a hot or cold shutdown function are located within tna same fire area.
Table 2 provides the results of the equipment and cable survey
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in detail, giving each required component and the cabling for all primary and associated circuits which could affect component operation. This table is structured so that each train of equipment is shown on a separate page with redundant components arranged to fall on the same lines. The fire areas in which-the components and their cabling are located are indicated by X's. Spatial separation (SEP) refers to the minimum separation between any A Train and B Train component for. the same shutdown function. Table 3 lists, by fire area, the redundant hot shutdown components ( ) which fall within the same' fire area. Table 4 lists, by fire -area, the redundant cold shutdown components (not listed on Table 3) which fall'within the same fire area. Separation dictances are-also given. Tables 3 and 4 are simplifications of the .information in Table 2 and include only those safe shutdown components and cables not meeting the acceptance criteria of Appendix R, Section III.G. O tv i 4 f 4.2 Associated Circuits The definition of associated circuits is that given in Enclosure 2 to Generic Letter 81-12 dated February 20, 1981. Item (1) of this enclosure provides the following clarification: i-
, Safety related and non-safety related . cables that are associated.
with the equipment and cables of the alternative, or dedicated method of shutdown are those that have a separation from the fire area less than that required by Section III.C.2 of Appendix R to 10 CFR 50 and have either (1) a common power source with the al- ' ternate shutdown equipment and the power source is not electrically protected from the post-fire shutdown circuit of concern by. coor-dinated circuit breakers , fuses or similar devices, (2) a connection
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! to circuits of equipment whose spurious operation will adversely-
, affect the shutdown capability, e.g. , RHR/RCS Isolation Valves ,' or (3) a common enclosure, e.g. , raceway, panel, junction box, with alternative shutdown cables and are not electrically protected-
,_,) fc om the post-fire shutdown circuits of concern by circuit break-ers , fuses or similar devices.
Associated circuits, included in categories (1) and.(3) of the above definition were evaluated as follows: All safety related, safe shutdown electrical loads are groupsd-together on a series of safeguards AC buses and motor control centers. During normal station operation and whenever of f-site electrical supply is 'available, the safeguards and normal loads are powered from common trans formers and buses. In the event of a loss of off-site power safeguard buses will automatically be disconnected form normal buses and will .be sequentially loaded onto the diesel generator units according to a load res toration scheme which assures the ui *el will not be overloaded. 4
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The safeguards loads are strictly separated into A train and p) ( B train loads providing redundancy for each function and com-ponent. Color coding is used throughout the plant to denote A train versus B train cables and cable trays serving the respective electrical loads. For plant system components, the coding scheme is orange denoting A train and green denoting B train. For plant
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safety related instrumentation the same division of redundancy is observed and the colors white and blue denote A train instru-mentation and red and yellow denote B train. All cables and trays serving the various A and B train instrumentation and components are idelibly marked with the appropriate colors. No A train and B train cables are allowed to share the same cable trays. (The analysis uncovered one exception and it is addressed in section 5 of this report.) No safeguard cables are allowed to run in non-safeguards cable trays, and all cables within safeguards trays are color coded and treated as safeguards cables. This division and isolation of safeguards cabling not only covers O) ( safeguards power and control circuits, but also includes position indication circuits and all non-safety circuits connected to safeguards equipment; for example, a safeguards DC panel may power another ncn-safeguards instrument panel. The cable that connects the two is color coded and routed in safeguards cable trays all the way to the non-safety panel. Such cabling is also electrically protected by fuses or circuit breakers. In the course of the analysis all such associated circuits, not only primary power and control circuits, were identified and subject to the same separation criteria check. Additionally, the analysis verified that protective fuses or breakers were provided. Where problems were found, these have been listed in Tables 3 and 4 and corrective actions specified in section 5 of this report.
f% v) Associated circuits included in category (2) of the above definition were evaluated as follows: A number of valves were identified in this analysis, whose spurious operation could potentially affect proper function of a ,
. safe shutdown system. These valves fall into two categories.
The first category includes passive motor operated valves in a safe shutdown system which are either open or closed in normal operation and do not have to change position for the system to function to achieve shutdown. The second category includes air operated control valves which fail safe if either power or air supply is cut off to the valve. The fail safe ~ position is one which does not hamper the ability of the system to function to-achieve shutdown. It has been postulated in the development of the Appendix R criteria that in certain circumstances fire damage to cables within the same tray could cause a hot short between power cables
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causing a passive valve to change position or a fail safe valve- N' to remain in an uncontrolled and unsafe position. This is extremely unlikely at the Prairie Island facility since all AC and DC power is. carried in armored cable or conduit. The cable armor or conduit is grounded and the. cable trays carrying the. armored cable are-also-grounded. All power cables are connected to their power. sources through ci n it breakers or fuses. It is inconceivable that fire damage could occur to adjacent armored cables'where power conductors would short to each other without shorting to ground and opening the breaker or fuse. For safeguards valves whose spurious operation could affect shutdown, all power and control cables are trained with the associated safeguards train. These cable trays will be protected by fire' barriers, distance, automatic suppression systems, and automatic detection i systems provided for the associated safeguards shutdown system. 4 v
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s i- ., 4 4 - For non-safeguards valves whose spurious operation could affect shutdown, it has been determined that sufficient warning ..
-of improper function will be available for -the plant.' operators
!. to take corrective action and-manually position the valve or take
- f ' ~ some other compensating action. We believe this is permissible j since manual operation of normally remote or automatically operated safe shutdown equipment is permitted by the Appendix
} R acceptance criteria.
- i. 6 4-All valves identifed in our analysis are lis.ted'in. Table 5.
l, Plant safe shutdown procedures will identify each of these j valves, symptoms of improper function, and preventive or corrective 4 i action. 4 4
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'5.0 Corrective Actions
- 5.1 Hot Shutdown Functions 5.1.1 Fire Areas #1 and #71 - Reactor Building, Units 1 and 2 {
i No corrective action is required inside the containment j buildings. -All. safe shutdown cables are separated by at'.least 20 feet. 5.1.2 Fire Area #18 - Relay and Cable Spreading Room l See exemption request 7.1. Control cables for. redundant power operated relief valves routed within the same tray in this area will-be're-routed to provide separation of at least.20 feet. 5.1.3 Fire Areas #31 and #32 - A and B-Train Hot Shutdown Panel and Instrument Air Rooms One train of power cables within these fire areas will be protected with an accepted one-hour fire barrier. The existing installed fire suppression systems will be expanded to. provide additional coverage
. to areas that are not currently. protected. These are spaces above-
[ ~ ~ }' ' adjacent fire areas. Fire detection equipment is already installed . in this area. For control circuits from the hot -shutdown panels see exemption request 7.2. 5.1.4 Fire Area #41 - Screenhouse No corrective actions are required since all redundant cabling is
- separated by > 20', and automatic fire suppression system is pro-vided, and fire detection equipment is installed.
5.1.5 Fire' Areas #58 and #73 - Auxiliary Building Ground Floor, Units 1&2 . One train of redundant cablingLin these fire areas will be protected-with.an accepted one hour fire barrier where those cables are < 20' feet apart. Automatic fire suppression systems will be installed in these areas to provide full area coverage. Fire detection equip-
.. ment is already installed in this area.
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('~'g 5.1.6 Fire Areas #59 and #74 - Auxiliary Building Mezzanine Floor,
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,) Units i and 2 One train of redundant cabling in the'se fire areas will be protected with an accepted one hour fire barrier where those cables are < 20 feet apart. Automatic fire suppression systems will be installed in' these areas to provide full area coverage. Fire detection equip-
-ment is already installed in this area.
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5.1.7 Fire Areas #60 and #75 - Auxiliary Building Operating Floor, Units 1 and 2 Control cables for redundant power operated relief valves' routed within the same tray in this area vill be re-routed to achieve adequate separation. If > 20' separation cannot be attained throughout the new route, then accepted one-hour fire barriers will be applied to non-complying segments. Automatic fire' suppression systems will be installed in these areas to provide' full area coverage. Fire detection equipment is already installed in this area. 5.1.8 Spurious Valve Operation - Preventive or Corrective Action j Written safe shutdown procedures will contain provisions
-/ for operator action to prevent or compensate for spurious operation of valves located in, or having power or control cables routed through, each fire area.
5.2 Cold Shutdown Functions Procedures will be developed which address the checkout and repair of cold shutdown functions that may be damaged in a fire. Materials will be stocked on site which will be required to make repairs or replacements. O 4 n< s_-
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6.0 Plans and Schedules - Corrective actions described.in Section 5 will be scheduled for completion in accordance with-the following schedule: Description Completion Date , a. .One-hour fire barriers August 17, 1981- , ou one train of redundant cables in fire areas 31, 32, 58, 59, 73, 74, and possibly 60 and 75. b.- Extension of fire suppres- January 1, 1983 sion systems for fire areas 31 and 32.
- c. Procedures for hot shut- August 17, 1981 down.(including spurious valve operation) and cold shutdown (including necessary repairs).
- d. Stocking of materials on August 17, 1982 site required to make repairs to postulated g fire damaged cold shut-( down equipment.
- e. New automatic fire suppres- January 1, 1983-sion. systems for fire areas 58, 59, 60, 73, 74, and 75 e
7.0 Exemption-Requests is s' 7.1 Fire Area #18 - Relav and Cable Spreadine Room Exemption - Relief is requested from the requirement to provide a one-hour barrier around DC distribution panels 15, 16, 26, and 26 and cables to _ panels 151, 161, 251, and 261. Relief is requested from the requirement to provide a one-hour barrier around auxiliary feedwater pump control circuits. Basis - Providing an effective barrier around these panels, cables, and control circuits is judged to be virtually impossible. No ignition sources are located in this area. The fire loading consists entirely' of low flammability cable insulation. The area is protected by ionization detectors and an automatic heat actuated Cardox total flooding system which will achieve a minimum carbon dioxide concentration of 50%. The system is sized to allow a second flooding action of the same volume which will achieve a concentration of about 70% carbon dioxide. Local manual control of-the auxiliary feedwater pumps can be taken in the g- g event of damage to the normal control circuits. Safe shutdown procedures (_,) will provide for this possibility. 7.2 Fire Areas #31 and #32 - A and B Train Hot Shutdown Panels and Instrument Air Rooms Exemption - Relief is requested from the requirement to provide a one-hour fire barrier around control circuits from the shutdown panels to the s auxiliary feedwater pumps located in the opposite hot shutdown areas (the area containing A hot shutdown panel contains B turbine auxiliary feedwater pump and vice versa). Basis - Providing an effective barrier around these control circuits is
, judged to be' impractical. These circuits are now enclosed in conduit which provides physical protection and some fire resistance. The areas in - question have a light fire loading.
The turbine auxiliary feedwater pumps are designed to run AC free and require no outside control once started. They are provided with s mechanical governor valves. Motor operated auxiliary feedwater pumps s ,/ can be started locally from the motor starters and cross connected to the other unit's_ steam generators. Safe shutdown procedures will provide i for these' options. t
7.3 Schedule for Installing Additional Suppression Svsters Exemption - Iteus (b) and (c) of the corrective actions described in . Section 6 of this report require an exemption from the implementation date in paragraph (c) (2) of 10 CFR PArt .50, Section 50.48 in addition to the schedule relief requested in our March 13, 1981 exemption request. Basis - Design and installation of the required automatic suppression systecs cannot be accomplished in less than ten to twelve months. We expe ct the installation to be complicated by clearance problets with installed equipaent near the ceiling in the areas to be protected and the need to carefully schedule and control work in critical plant areas Additional time to complete these suppression systems will not compromise the health and safety of the public. These areas now have automatic fire detection systems, hose stations for manual fire fighting, and portable extinguishers . ' A fire brigade of five trained individuals is available b) I on site at all times to respond to a fire. The plant is within the municipal boundary of Red Wing, Minnesota. This city has an exception-ally well qualified and equipped fire department. 4 v) . 1 I i i
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i 4 TABLE 2
- SAFE SHUTDOWN EQUIPMENT AND CABLE MATp. ICES Legend - Cable Type (p) - power cable i (c) - control cable
- 0 (1) - instrumentation 4
i Legend - Corrective Action 1 - Components are in separate fire areas with 3-hour barriers. No corrective action required. 2 - Alternate cable tray to be provided with 1-hour barrier. Automatic fire suppression system to.be provided. Automatic fire detection system to be provided. 3 - Exemption request to be submitted. 4 - Procedures tc 3e developed. 5 - Cable to be re-routed.
- If no corrective action code, separation is greater than 20 feet within a conson fire area. Automatic fire suppression and automatic fire detection to be provided.
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