ML20024D071
| ML20024D071 | |
| Person / Time | |
|---|---|
| Site: | Rancho Seco |
| Issue date: | 07/28/1983 |
| From: | Reinaldo Rodriguez SACRAMENTO MUNICIPAL UTILITY DISTRICT |
| To: | Stolz J Office of Nuclear Reactor Regulation |
| References | |
| TAC-52291, NUDOCS 8308030116 | |
| Download: ML20024D071 (4) | |
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' g uuo SACRAMENTO MUNICIPAL UTILITY DISTRICT O 6201 S Street, Box 15830, Sacramento, Canfornia 95813; (916) 452-3211 RJR 83-547 July 28,1983 DIRECTOR OF HUCLEAR REACTOR REGULATION ATTENTION JOHN F STOLZ CHIEF OPERATING REACTORS BRANCH 4 US NUCLEAR REGULATORY COMISSION WASHINGTON DC 20555 DOCKET 50-312 RANCHO SECO NUCLEAR GENERATING STATION UNIT NO 1 ALTERNATE SHUTDOWN CAPABILITY; 10CFR50 APPENDIX R Your letter of January 10, 1983, denied our request for exemption from certain provisions of Appendix R to 10CFR50 relating to the control room and indicated the need to provide information relating to the alternate shutdown capability.
Consequently, the enclosure to this letter provides a description of the equipment the District now proposes to use as well as an outline of the procedure to be followed to meet this requirement.
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R. J. Rodriguez I
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Executive Director, Nd lear l
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8308030116 030729 ll l
PDR ADOCK 05000312 l
F PDR Ah (LECTRIC SYSTEM AERVING MORE THAN 600.000 IN THE HEART OF CALIFORNIA
ENCLOSURE SMUD ALTERNATE SHUTDOWN CAPABILITY i
A.
The following indications will be provided on an alternate shutdown panel which is located in an area which is physically isolated from the Control Room by 3 hour3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br /> fire barriers:
1.
Wide Range Steam Generator Levels for both OTSGs; 2.
Wide Range Steam Generator Pressure for both OTSGs; 3
Pressurizer Level; 4
Wide Range Reactor Coolant System Pressure; 5.
Wide Range Reactor Coolant System Hot Leg Temperature (both loops);
6.
Wide Range Reactor Coolant System Cold Leg Temperature (both loops);
7.
Source Range Nuclear Instrumentation; 8.
Makeup Tank Level.
These indications will be routed such that fire damage which might occur in the Control Room will not affect their availability.
B.
Controls will be provided at locations on or near the switchgear/ motor control centers for the following equipment:
1.
High Pressure Injection Pump - P238A and HPI Valve SFY-23811; 2.
Makeup Tank Isolation Valve - SFY-23508; 3.
Makeup Pump Recirculation Valve - SFY-23645; 4.
Decay Heat Pump - P261A; 5.
Nuclear Service Raw Water Pump - P472A; 6
Auxiliary Feedwater Pump - P319; 7.
Diesel Generator Breaker - S4A08; 8
Startup Transformer #1 Supply Breaker - S4A01; 9.
Station Service Transformer - X43A.
10.
Diesel Generator Engine and Generator Controls Equipment will be provided where necessary to assure that circuits for these components and any necessary support equipment are isolated from control room circuits in the event of a fire that requires evacuation of the Control Room.
C.
The following paragraphs contain the major steps to be contained in our procedure for shutdown from outside the Control Room in the event of evacuation due to fire.
1.
Prior to leaving the Control Room, trip the Reactor and Turbine and perform routine immediate actions for these procedures. Carry out other actions to assure that the nuclear services electrical busses are energized, that auxiliary feedwater is operating, and that an HPI pump is operating to supply RCS makeup from the BWST.
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' 2.
Dispatch an operator to the A channel nuclear Lervi;e electrical switchgear roor, to open circuit breakers for selected equipment and isolate electrically those for which subsequent operation is anticipated.
This step is done to provide assurance that if the fire burns uncontrolled in the Control Room, damage does not occur which will later preclude manual operation of com>onents with control room circuitry which may be needed as the s1utdown proceeds.
3..
The Senior Control Room Operator will repcrt to the alternate i
shutdown panel and verify. proper operation of the instrumentation, the plant paging system and offsite telephones, and will assume the same responsioilities for the plant as held in the Control Room.
4.
The Control Operator will verify auxiliary busses have transferred to their standby sourceand selected loads are operating, if offsiste power is available. He will then report to the alternate shutdown panel area and assist the Senior Control Operator.
5 The Shift Supervisor will take action' to obtain outside assistance and limit damage due to the casualty and will insure reporting to outside agencies is accomplished as required. He is acting as Emergency Coordinator until relieved by the appropriate Emergency Response Organization personnel.
6 The Auxiliary Operator establishes communications with the alternate shutdown panel area and opens an HPI valve from its motor control center as directed. He is also available to isolate the makeup tank outlet valve and adjust position of the makeup tank recirculation valve as directed to insure proper HPI pump operation.
7.
Two other operators are dispatched to the OTSG AFW conteol valves complexes and establish consiunications with the alternate shutdown panel personnel for control of steam generator feed as directed.
i 8.
Additional shift personnel will report to the alternate shutdown panel for instructicns.
l 9.
The following steps are classified as subsequent actions after stable hot shutdown conditions are established:
a.
Control turbine bypass valves and/or atmosphere dump valves to control steam generator pressure; b.
If offsite power has been lest, attempt to restore it; c.
If offsite power is lost, valve in nitrogen to plant air system or start emergency diesel air compressor; d.
Place turbine on the jack when rotor stops (approximately 90 minutes following trip) and when normal power is restored; e.
Manually control reactor coolant letdown and makeup to maintain pressurizer level.
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- 10. If cooldown is desired, then cooldown to the point of going on to the decay heat removal system can be accomplished from the previously manned stations and monitored on the alternate shutdown panel indications using normal cooldown procedures (auxiliary feedwater and dump valve control).
If offsite power has been lost, the cooldown will be in accordance with the natural circulation cooldown procedure and will require at least 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> to accomplish.
- 11. Prior to going into decay heat removal mode, additional off-duty operators will be sumoned to manually line up the decay heat removal system for operation including the nuclear service cooling water requirements.
- 12. After transition to Decay Heat Removal system operation the auxiliary operator or other available operations personnel will be assigned to modulate the decay heat cooler outlet and/or bypass valve to control heat removal rate to achieve and maintain cold shutdown conditions.