ML20052H832
| ML20052H832 | |
| Person / Time | |
|---|---|
| Site: | Saint Lucie  |
| Issue date: | 04/22/1982 |
| From: | FLORIDA POWER & LIGHT CO. |
| To: | |
| Shared Package | |
| ML17212B613 | List: |
| References | |
| PROC-820422-01, NUDOCS 8205240030 | |
| Download: ML20052H832 (54) | |
Text
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DOCUMENT aEv:SzcN DISTRE3UTION SsEET - OFF NORMAL & SERGENCY CPER. ?ROCDURE W s ac Mnc,e
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DATE DOCUMENT SENT TO:
COPY TRANSMI*TAL COPY TRANSMI':" .s ,
NO. DOCUMENT EOLDER RETURNED NO. DOCUMENT HOLDER RETUPJiED -
MASTER UNCONTROI.LE COPIES 1
2 NRC-Region II Acts: EPPS 3RANCE CHIEP 3
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Ptg3 1 of 3 FLORIDA POWER & LIGHT COMPANY l f ST. LUCIE UNIT # 1 ,
OFF NORMAL OPERATING PROCEDURE NO. 1-1210030 -
REVISION 3 I i '
- 1. 0 TITLE:
Wide Range Nuclear Instrumentation Channel Malfunction l,
2.0 APPROVAL
Reviewed by Plant Nuclear Safety Committee I '
2L 19 7[
Approved by a // 8a , , ,1 , hi>-Plant Manager f,,pe /J 19_Z,f-Revision 3 Reviewed by FRG MARH 3p 19 R Approved by /22AP/g4/h Plant Manager d,en , / 2. e -19 8'R e
3.0 PURPOSE & DISCUSSION:
3.1 This procedure provides a guide for operator action in the event of a wide range nuclear instrument channel malfunction.
! 3.2 Since the wide range drawer provides pretrip, trip and logic signals to the reactor protection system. (RPS) all indi-cations should be assumed valid until proven otherwise.
4.0 SYMPTOMS
Any of the following symptoms can indicate a wide range channel malfunction:
4.1- Actuated Annunciators:
Reactor power high race of change pretrip. (L-25)
Reactor power high rate of change trip. (L-19)
Nuclear Instrumentation Channel Inoperative. (L-30) 4.2 Significant disagreement between channels as read on rate and level meters on the wide range drawer and/or RTGB 104.
4.3 Drift of bistable settings. (10-', 10-1) 4.4 Wide range drawer H.V. failure light on.
4.5 Failureofthewiderangedrawertoshiftfromtheextegded range to the wide range node of operation when > 5 X 10 CPS.
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OFF NORMAL OPERATING PROCEDURE NO. 1-1210030 REVISION 3 UIDE RANGE NUCLEAR INSTRUMEMTATION CHANNEL MANrU'iCTION
5.0 INSTRUCTIONS
~ 5.1 I= mediate automatic action 5.1.1 A Reactor trip is initiated by a two out of four coincidence logic if the rate of change of power exceeds 2.4 DPM when operating in the range of 10-4% to 15% power.
5.1.2 A control withdrawal prohibit is initiated by a two out of four coincidence logic if the rate of chan68 of power exceeds 1.3 DPM when operating above 10~"?.
power. .
5.2 Inmediate operator action 5.2.1 Acknowledge alarm (s).
5.2.2 Compare meter indications on all channels to discern a valid alarm / indication from a channel malfunction.
5.3 Subsequent actions R3 l 5.3.1 Bypass the affected channel Hi Rate trip unit.
5.3.2 Switch the wide range recorder and audio count rate (if in the startup or shutdown modes) to the ooerable channel.
5.3.3 In the event of a drawer failure to shift the fission chamber detector mode of operate fron extended to wide range: Place the vide range drawer level OPERATE /
CALIBRATE switch in the CALIBRATE one position. Observe the extended range light extinguish.
}
5.3.4 The balance of subsequent operator action is determined
- by the mode at which the reactor is operating and the number of inoperable channels. Refer to Tech Specs.
Table 3.3-1.
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l 0FF NORMAL OPERATING PROCEDURE NO. 1-1210030 REVISION 3 l UIDE RANGE NUCLEAR INSTRUMENTATION CHANNEL MALFUNCTION
5.0 INSTRUCTIONS
(Conc'd) 3.3 Subsequent ooeration action (Cont'd) 5.3.5 Notify I & C as soon.as practical.
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6.0 REFERENCES
}-
6.1 Technical Specifications l
i t 6.2 Wide Range Log Channel Model NLW-3 Operation and Maintenance Manual 8770-6860.
k l 7.0 RECORDS:
I 7.1 Nomal Log Entries 4
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NC. CCCOMENT HOLDER RETURNED NC. CCCCMENT HOLDER RE"'URNED ,
MASTER UNCCNTRCLLED CCPIES 1 N 7"d NRC-Region II 2
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FLORIDA POWER & :.IGHT COMPANY ST. LUCIE UNIT lil l .
EMERGENCY OPERATING PROCEDURE NO. 0030140 REVISION 25 l ,
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1.0 Title
F0 D INFDDMAT10N Ci.'M' This document is not contrciled. BeTo e , se,
- BI.ACKOUT OPERATION verify information with a controlled document.
2.0 Approval
Reviewed by Plan Nuclear Safety Committee (MM~i J 19/9 Approved by ' 9-d M , J Plant Manager M M / pd ;' f 19-.a Revision M Reviewed by Facility Review Group . . .. . 19 Approved by /C J, /1./ M Plant Manager 4.. 19 h j
< 3.0 Purrose or Discussion:
3 ._1 This procedure provides the action to be taken in the event of i a complete loss of off site electrical power concurrent with a turbine trip.
)
3.2 Discussion j 3.2.1 A loss of power to the 4160 V buses, results in a loss of i
power to all 480 V load cen:ers and motor control centers and to all instrumentation not fed directly or indirectly from the station battery. A reactor trip will occur from a low reactor coolant flow rate signal due to the loss of power to the 6900 V buses supplying the reactor coolant
' pumps and will be accompanied by a turbine trip and generator lockout.
- 3.2.2 Steam dump to atmosphere must be used to remove reactor decay heat. Initially, steam generator safety valves may actuate to augment the steam flow and to help control steam generator pressure i= mediately after the trip.
3.2.3 On sita power will be supplied by Emergency Generators.
3.3 A rapid reduction in steam generator water levels will occur due to the reduction of the steam generator void fraction on 3
the secondary side and also because steam flow will continue after normal feedwater flow stops. Auxiliary feedwater flow
] will automatically initiate 3 minutes after the first steam 9
generator level reaches 34% (2/4 logic).
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Page 2 of 14 1
2 DiERGENCY OPERATING PROCEDURE NO. 0030140, REV 25 ,
BLACKOUT OPERATION be 3.0 Purpose or Discussion: (Cont'd) 3.4 Core decay heat removal is accomplished by natural circulation in the reactor coolant loops.
3.5 Core damage is not expected as a result of a loss of power
- condition as the steam generators are maintained as a heat sink d and no loss of water occurs from the pressurizer.
I 3.6 If operating under blackout conditions and an engineered afety features actuation signal occurs, any non-emergency loads that are running will be automatically tripped and
~
the required emergency loads will be automatically started.
4.0 Symptoms
j i 4.1 Alarms associated with the loss of operating plant components.
4.2 Loss of normal control room lighting and DC lighting energized.
) 4.3 Reactor and turbine trip.
. 4.4 Emergency diesel generators start.
4.5 Reactor coolant pump trip and steam generator feed pump trip.
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Page 3 of 14 4
EMERGENCY OPERATING PROCEDURE NO. 0030140, REV 25 h.
BLACK 0UT OPERATION i I
5.0 Instructions
{ l 5.1 Immediate auto action ! l l
l 5.1.1 Reactor and turbine trip, generator lockout { .
~
5.1.2 Generator breakers open.
5.1.3 Incoming feeder breakers open to 4160 V and 6900 V buses. .
5.1.4 Tie breakers between Normal 4160 buses (IA2 and 1B2) and the emergency 4160 V buses (IA3 and 1B3) open. -
5.1.5 Ties between essential and non-essential sections of emergency 480 V MCC's open.
1 1 5.1.6 Breakers open for the following non-safety related loads which are normally fed from emergency buses.
NOTE: These loads can be manually reconnected to the ,,
emergency buses as needed.
5.1.6.1 Pressurizer heater transformers 1A and IB.
fi 5.1.6.2 Fire pump 1A and 1B.
- 5.1.6.3 CEA Drive M.G. lA & IB.
I 5.1.6.4 Fuel Handling 480 V MCC 1A8, IB8/
5.1.6.5 Reactor cavity sump pump 1A I
5.1.6.6 Reactor building elevator 5.1.6.7 Electrical equipment room hoist
- 5.1.6.8 120/208 power panel 121 transformer 5.1.6.9 Lighting panel transformers 110, 112, 114, 117,
' 125, 126 5.1.6.10 Incoming feeder from 1A2 & IB2 4160V buses I
5.1.6.11 RCP oil lift pumps (S pumps only - A pumps running) 6 5.1.6.12 Airborne radioactivity removal fans HVE-1&2 5.1.6.13 Pressurizer relief isol valves 1403 & 1405 /R22
- 5.1.6.14 CVCS heat tracing transformer IA & 1B 0 5.1.6.15 480V Lighting panel 2A, 2B & 2C 5.1.6.16 Waste management heat tracing transformers 2A & 2B 5.1.6.17 Air conditioner HVA-4, ACC-4.
) 5.1.6.18 Power panel 120 3
5.1.6.19 Lighting panels 113, 116, 109, 115, 130 1
5.1.6.20 Refueling equipment 5.1.6.21 Refueling water to charging pumps V-2504
] 5.1.6.22 Boric Acid batching tank heaters 5.1.6.23 Fire siren s
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EMERGENCY OPERATING PROCEDURE NO. 0030140, REV 25 1 i BLACKOUT OPERATION I
l 5.0 Instructions: (cont) i <
51 i
(cont) l I i 5.1.7 All loads on emergency buses are tripped except t i the following: L 5.1.7.1 Boric Acid makeup pumps 5.1.7.2 Charging pumps 5.1.7.3 Emergencflighting 5.1.7.4 Class I power panels 5.1.7.5 RCP oil lift pumps (A pumps only - B pumps off) -
5.1.7.6 Diesel fuel transfer pump.
5.1.8 Diesel generators A & B start and energize 4160 V emergency buses 1A3, 133, and 1AB and loads listed in step 5.1.7.
, 5.1.9 Subsequent loads are started at 3 second intervals.
See Table 1, Emergency Diesel Cenerator Loading Sequence.
5.1.10 Auxiliary Feedwater auto start sequence initiates when the first steam generator level decreases to 34:.
NOTE: Pump start and flow initiation is delayed for 3 minutes. Pumps may be started by the operator g ANY TIME.
5.2 Immediate Operator Actions 3
f 5.2.1 Trip turbine and reactor manually.
5.2.2 Check all full length CEA's are fully inserted and reactor trip breakers are open.
5.2.3 Check turbine valves are closed.
5.2.4 Check generator field and 240 KV breakers are open. .
5.2.5 Place reheater control system in manual, close TCV's.
5.2.6 Chee? that diesel generators have started and are feeding only emergency buses.
5.2.7 Open start-up transformer breakers.
5.2.8 Reduce Tavg to reference set point by manual operation of the steam du=p valves to atmosphere.
5.2.9 Isolate steam generator blowdown.
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Pega 5 of 14 EMERGENCY OPERATING PROCE URE NO. 0030140, REV. 25 4 i BLACKOUT OPERATION eum , !
5.0 Instruction
(cont'd) 5.2 Immediate Operation Action (Cont'd) 5.2.10 start steam driven aux. feed pump and establish flow
'Y to S.G.'s. If aux. feed pumps have started due to the auto start feature, the motor driven pumps may be secured 30 seconds after they start, if desired.
5.2.11 If all feedwater flow is stopped or lost and steam generator level is less than 42% then:
- 1. Reinitiate auxiliary feedwater flow as soon as possible; however, do not exceed a flow rate of 150 gpm per steam generator.
- 2. Limit feedwater flow race to 150 gpm per steam generator until continuous feedwater flow .
I to the SG has been maintained for five minutes.
J 5.2.12 If any of the automatic actions listed in 5.2.2 thru 5.2.9 do not occur automatically, then manually initiate that action.
5.2.13 Emplement the Emergency Plan as necessary in accordance with EPIP 3100021E, " Duties of the Emergency Coordinator '.
5.3 Subsequent Action 5.3.1 Ensure adequate natural circulation flow by ensuring that hot and cold leg temperatures, pressurizer pressure and level stabilize within minutes. The core AT should be less than N 46 F (AT for full power).
5.3.1.1 If the above conditions are not established:
5.3.1.1.1 Check RCS temperature and pressure to ensure that the RCS is subcooled.
5.3.1.1.2 Ensure auxillary feed flow to the steam generators has been initiated and the steam dumps to atmosphere are in operation.
- 5.3.1.2 Return at least one RCP in each loop to operation is soon as offsite power is available.
5.3.2 Start equipment in Table 1 if required. 84 1 - .-
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Pcg3 6 of 14 EMERGENCY OPERATTNG PROCEDURE NO. 0030140, j ,
REVISION 25 j j BLACKOUT OPERATION j g r I 5
5.0 Instruction
(Cont'd) l {
I i
5.3 (cont'd) ,
i 5.3.3 If one diesel fails to start, attempt a =anual start.
5.3.3.1 If manual start attempt is unsuccessful, an operator should be sent to the diesel local control station to inspect status of local alarm panel.
5.3.3.2 If no alarms are present on the local alarm panel, an inspection of the overspeed trip lever should be made to insure it has not tripped.
5.3.3.3 If the overspeed trip levers are latched, the normal isolate switches on the local control panel should be placed in the isolate position and a local start attempt should be made.
5.3.3.4 Refer to Operating Procedure 2200020, 2200050 Emergency Diesel Standby Line up and Periodic Test.
5.3.4 Locally open condenser vacuum breakers MV10-1A and MV10-13. Locally close MSR main steam block valves MV08-4, MV08-6, MV08-8, and MV08-10.
5.3.5 Check MSR warm-up valves MV08-5, MV08-7, MV-9, and MV08-11 to be closed or close manually.
5.3.6 Send an operator to align and start emergency cooling water to the instrument air compressor, then reset local handswitch and =anually start the instrument afr compressor.
j CAUTION: Do not overload the diesel generators when starting additional equipment. (3500 KW max. continuous rating).
5.3.7 When diesel generator power is available energize equipment as may be required for plant safety and to achieve an orderly shutdown within the diesel gener-ator load limitations by:
5.3.7.1 verify one set of cavity and support cooling fans operating. If not, start one set.
1 5.3.7.2 Locking out automatic starting equipment th'a t is not in service.
5.3.7.3 Manually opening all breakers on any non-vital bus or motor control center that is to be ,q re-energized.
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EMERGENCY OPERATING PROCEDURE NO. 0030140, [
REVISION 25 1 i
BI.ACK0UT OPERATION j '
'} o y 1
5.0 Instructions
(Cont) 1 !
b 5.3 (Cont) j
?
5.3.7 (Cont) 5.3.7.4 Resetting lockout relays for each required L]
bus to allow closing of feeder breakers.
5.3.8 Energize 4160 V buses lA2,132, 480 V load centers lAl, 131 and 480 MCC's lA1, 131, lA4, 134, and 1C as follows:
ACTION LOCATION
< 5.3.8.1 Strip non-vital 4.16 KV busses lA2 1B2 i (All should be opened automatically) 5.3.8.2 Insert sync plug, close 4.16 KV 1A2-20109 1B2-20309 '
non-vital breaker and hold control switch closed while closing 4.16 KV vital treaker. lA3-20209 1B3-20411 5.3.8.3 Strip non-vital load center 1Al 1B1 h
i 5. 3.8.4 Close 4.16KV feed breaker to j
ncn-vital load centers lA2-20110 182-20310
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! 5.38.5 Strip 480V MCC 1A1 1B1 1A4 1B4
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5.3.8.6 Close 480V load center feed I breaker to MCC lAl & 1B1 1Al-40115 131-40411 I
j 5.3.8.7 Close 480V load center feed breaker to MCC 1A4 & IB4 1Al-40113 1B1-40413 j
- 5. 3.8 . 8 Close 480V load center feed breaker to MCC 1C 1Al-40119 1B1-40410 5.3.9 At MCC 1C, close breakers for turning gear, bearing oil pump, air side seal oil pump and hydrogen seal
- l oil pump.
l 3.3.10 Place turbine plant cooling water pu=p in operation.
j 5.3.11 Align turbine cooling water system to the instrument air compressor back to normal alignment.
I
] 5.3.11.1 Open all Ckt's on PP-104 except Ckt's 21 & 23.
A 5.3.11.2 Close Breaker 40851 on MCC 1A1 j
5.3.11.3 Open all Ckt's on PP-146 except Ckt 1. 4 1
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EMERGENCY OPERATING PROCEDURE No. 0030140, j :
REVISION 25 t BLACK 0UT OPERATION L'S r 4
5.0 Instructions
(Cont) 2 4 fi 4 5.3.11.3.1 Open all Ckt's on PP-150 !
except Ckt's 7,9 and 11.
NOTE: PP-146 is located on the wall .
of the new cold lab just west of MCC 1Bl. PP-150 is located in the new cold lab closet.
5.3.11.4 Close Breaker 41634 on MCC 131.
5.3.12 Place turbine drain valve switch in the open position.
5.3.13 Start bearing oil pump before turbing bearing oil pressure reaches 12 psig. decreasing. Pump starts .
l automatically at 12 psig decreasing turbine bearing a oil pressure. NOTE: If bearing oil pump fails to start, the emergency DC oil pump will start at 10
-j psig decreasing bearing oil pressure. Operator should
'i start pump before 10 psig is reached. Stop the DC oil pump if it is running in addition to the bearing i oil pump.
A 1 5.3.14 Remove the following components from service:
I 5.3.14.1 Steam jet air ejectors j 5.3.14.2 Priming ejector 2 5.3.14.3 Auxiliary priming ejector
] 5.3.14.4 Auxiliary steam to R.A.B.
1 5.3.14.5 Gland seal system 9
i 5.3.15 Start CEDM cooling fans A & B.
j 5.3.16 Start reactor support cooling fans A & B.
CAUTION: Consider equipment starting requirements.
4 Alternate operation of equipment may be y
,1 l required to avoid overloading the diesel lj generators. (3500 KW Max. continuous jg rating).
' $l 5.3.17 Manually close breakers for pressurizer heater buses e on 4150 V buses lA3 and 1B3.
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Prga 9 of 14 EMERGENCY CPERATING PROCEDURE NO. 0030140, REV 25 6 e BLACKOUT OPERATION
5.0 Instructions
(cont) 5.3 (cont) . ).(
5.3.1d Check that the bearing oil lift pump starts automatically when turbine speed decreases to approximately 600 rpm.
5.3.19 Start turbine lube oil vapor extractor and generator oil vapor extractor.
5.3.20 Check that the turning gear engages and starts auto-matically when turbine speed decreases to zero rpm, -
or manually engage it.
i 5.3.21 Reduce the flow of cooling water to maintain the temperature of the oil leaving the turbine lube oil .
and the air side and hydrogen side oil coolers be-tween 95 - 1000 t.
< 5.3.22 Isolate cooling water supply to the generator hydrogen coolers.
5.3.23 If additional condensate storage tank water is I required and sufficient power is available from the i diesel generatoes, place the water treatment plant -
in service.
j 5.3.24 Place the spent fuel pit cooling pump in operation as necessary.
l NOTE: With spent fuel elements from 3-1/3 cores
~'
' present, the spent fuel pit can safely
! withstand 5 hours5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br /> without cooling before reaching the boiling point.
lJ 5.3.25 Periodically check fuel oil levels in the diesel l generator day tanks to confirm proper operation of the fuel oil transfer system and to ensure uninter-rupted diesel generator operation.
5.3.26 Sample and analyze the reactor coolant to determine
.1 if fuel element clad failure has occurred.
l/ 5.3.27 Determine expected duration of power outage. If unable 4 to do so or if outage is to be prolonged, borate RCS lj to cold shutdown concentration.
5.3.28 If the outage will exceed 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> and the RWT is available, proceed to cold shutdown conditions utilizing thermal
,j circulation, atmospheric steam dump and feedwater
' ' addition. Place shutdown cooling in service when appropriate temperatures and pressures are reached. 4 f Proceed to step 5.3.32.
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EMERGENCY OPERATING PROCEDURE No. 0030140, REV 25 BLACK 0UT OPERATION 1 [
1 u, ;
5.0 Instructions
(cont) j i 5.3 (cont) 1. 3!
r 1
5.3.2 8 (cont) '(im j NOTE: Do not begin plant cooldown until cold 1 shutdown boron concentration is verified.
5.3. 29 If the outage will exceed 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> and the RWT is not available, the Safety Injection tanks should be used for makeup to the RCS, if other sources are not available.
5.3.30 Make the following preparations:
5.3.30.1 Close either or both non-essential tie breakers for MCC 1A5 and MCC IB5 1A5 - 41230 j; 1B5 - 42027 This will provide power to the containment instrument air compressors.
5.3.30.2 If running of containment instrument air compressors is not desirable, insure that
? a turbine building instrument. air compressor
' is running and containment instrument air pressure is normal.
1 5.3.30.3 Open the 480 V AC breakers for MOV-2501 and MOV-2504.
MOV-2501 - 42021 MOV-2504 - 42017 5.3.30.4 open and lock the following valves:
, V-07009 SIT test line return to RWT penetration #41 V-3463 SIT test line return to RWT I penetration #41 V-03920 SIT test line tie to VCT inlet 7
5.3.30.5 Borate the RCS to cold shutdown boron concentration.
CAUTION: Insure that one BAMI tank ramains in service to use as a source of borated water while in mode 5.
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s EMERGENCY OPERATING PROCEDURE NO. 0030140, REV 25 -
BLACKOUT OPERATION
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5.0 Instructions
(cont) ( f A e i
5.3 (cont) {i 5.3.31 Proceed to cold shutdown conditions utilizing thermal ,,j circulation, atmospheric steam dump and feedwater addition.
5.3.31.1 When makeup to VCT is necessary, select a S.I.T. to use as makeup source. Open the appropriate tanks, fill and drain valve. -
lAl - A0V-3621 1A2 - A0V-3611 IB1 - A0V-3631 132 - A0V-3641 5.3.31.2 Close the appropriate fill and drain valve when VCT is restored to normal level.
CAUTION: Use one SIT tank at a time.
Insure RCS is 1750 psia before the second SIT tank is used.
j' 5.3.31.3 Place shutdown cooling in service when apnropriate temperatures and pressures are reached.
5.3.32 If pressurizer cooldown cannot be accomplished in a l timely manner from the addition of cooler liquid (Aux.
Spray) from the charging pump via the pressurizer spray line, proceed with the alternate positive means of depressurization as follows:
5.3.32.1 Place the switches for the power operated 5 relief valves V1402 and V1404 in the override position.
j 5.3.32.2 Initiate a high pressurizer pressure trip signal on two RPS channel trip units.
g I
g 5.3.32.3 Place the switch for either power operated 1 relief valve (V1402 or V1404) in the normal range position and vent the pressurizer to the quench tank. Return the switch to override to close valve.
I 5.3.32.4 Control the rate of cooldown and depressurization by selective operation of the power operated i relief valves in this mode until cooldown via i
che Auxiliary Spray valves can be initiated.
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5 EMERGENCY OPERATING PROCEDURE NO. 0030140, REV 25 i.
BLACKOUT OPERATION 5
s
( 5.0 instructions: (cont) bk id
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5.3 (cont)
' I f 5.3.33 When normal AC power is available: ;
i 5.3.33.1 Restore bus sections to their normal supplies.
5.3.33.2 Place the diesel generator system in standby lineup as per OP 2200020.
5.3.33.3 Restore all plant systems to normal.
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i 4 EMERGENCY OPERATING PROCEDURE NO. 5030140,REV 25 BLACKOUT OPERATION ,
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- . 6.0
References:
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,% 3 6.1 FSAR, Section 15 -
,L ,a, r 6.2 FSAR, Section 8 j;,d'-
6.3 Operating Procedure #0030130, Shutdown Resulting From ,
Reactor / Turbine Trip 6.4 Operating Procedure #0210020, Charging and Letdown L 6.5 Operating Procedure #0330020 Turbine Cooling Water Operation 6.6 Operating Procedure #0250031, Boron Concentration Control, Off-Normal 6.7 Operating Procedure #1010040, Loss of Instrument Air 6.8 Operating Procedure #1540020, Water Plant Startup and Shutdown 6.9 Operating Procedure #2200020, Emergency Diesels - Standby Lineup 6.10 Operating Procedure #0700022, Aux. Feedwater System Operation 7.0 Records / Notification:
7.1. Normal Log Entries.
7.2 Notify Duty Call Supervisor.
7.3 AP C010134 " Component Cycles and Transients"
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TABLE I "# \-
14 cM 14 5 EMERGENCY DIESEL CENERA. TOR LOADING SEQUENCE O t
b Loss of Coolant Accident . Loss of -
and Loss of Off-Site Power '
'MI-Site Power Nominal Running Timing * . Running i Load - Ku Starting Runn'ing Load - Ku Service h Load - Ea c.
f
!! PSI pump 1 400 IIP 330 From- 0.2 Sec - Cont ,
Boric acid makeup pump 1 25 llP 22 From 0 Sec - 4 hrs 1st 22 i Charging pump 1 100 llP 80 Frem 0 Sec - 4 hrs Block 80 (
Hotor operated valves Lot 60 llP 40 From 0 Sec - 1 min -
b Emergency lighting Lot 50 KW 50 From 0 Sec - Cont 50 Class I power panels 4 45KVA 40 From 0 Sec - Cont 40 .
From 5 Fuel Trnasfer Pump 1 5 llP 5 0 Sec - Cont LPSI pump 1 400 llP 330 From 3 Sec - 90 min 2nd 330 Containmnet fan coolers 2 150 IIP 245 From 3 Sec - Cont Block 167- f Cooponent coolant pump 1 450 HP 376 From 6 Sec - Cont 376 Shield bid vent fan 1 60 ILP 54 From 6 Sec - Cont 3rd -
Shield Bld Vent Sys Elec litr 1 30Kt; 30 From 6 Sec - Cont Block - !
1 D-G Bld Exh. Fan 1 lilP 1 From 6 Sec - Cont
., Intake cooling pump 1 600 llP 492 From 9 Sec - Cont 4th Block 497 Containment spray pump 1 500 HP 400 From 12 Sec - Cont 5th Block -
Auxiliary feedwater pump 1 350 llP 305 From 15 Sec - 4 hrs 6th Block 305 4 Boric acid heating I Lot 51.75 KW 51.75 From 18 Sec - 4 hrs 51.75 Auxiliary bld supply fan 1 60 ItP 54 From 18 Sec - Cont 54 k ECCS Area exhaust system 1 50 llP 44 From 18 Sec - Cont 7th 44 .
Control Room AC Outdoor tinit 1 50 llP 44 From 18 Ser - Cont Block 44 Control room AC Indoor Unit 1 7.5 llP 8 From 18 Sec - Cont 8 Control room booster fan 1 3 IIP 3 From 18 Sec - Cont 3 i Reactor Support CLG Fan 1 40 HP 37 From IS Sec - Cont 37 !
20 IIP 19 From 18 Sec - Cont 19 Reactor Cavity CLG Fan 1 l 68 From 30 Sec - Cont 8th 68 Battery Charger 1 68 KVA From 30 Sec - Cent Block 20 {
Plant Security Inverter 1 20 KVA 20 15 UPS Inverter 1 15 KVA 15 From 30 Sec - Cont Fire Pump 1 250 IIP ** From 35 Sec ** 198 Totals: 3163.75 ku 2429.75 kw ['
(maximum, 18 Sec - y-30 min)
- Counting f rom the time the D-G breaker closes
- Auto-start feature on fire pump is defeated if SIAS is.present. h
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NO. CCCCMENT ECLDER RETURNED NO. CCCCMENT ECLDER RETURNED 1
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FLORIDA POWER & LIGHT COMPANY ST. LUCIE UNIT NO. 1 EMERGENCY OPERATING PROCEDURE 0120041 REVISION No. 13
1.0 Title
STEAM GENERATOR TUBE LEAK / FAILURE
2.0 Approval
Reviewed by: Plant Nuclear Safety Cocunittee b7 19 7f Approved by: O , M./3 g,cu e M,lant Manager C J1 19 75 Revision 7 Reviewed by FRG dromov l'f 19 2 Approved by: d /Jh Adlant Manager /0 - 1 19 1 Revision 13 reviewed by FRG 4 o. .*. t 1982 Approved by 8#, ////A g
Plant Manager 4 1982. -
3.0 Purpose and Discussion:
3.1 The purpose of this procedure is to list the indications that
}
will enable the operator to identify a Steam Generator Tube failure and to provide the action to be taken to control the accidene and minimize radioactive release to the environment.
! 3.2 Discussion:
3.2.1 A Steam Generator Tube Failure causes leakage of reactor coolant into the steam system. If the leakage exceeds the j capacity of the charging pumps, pressurizer pressure will decrease rapidly, causing a thermal margin / low pressure trip. The subsequent cooldown following the reactor trip combined with the continued leakage of reactor coolant into the Steam Generator will cause a further reduction in
( '
pressurizer pressure and level, resulting in initiation of safety injection and containment isolation. The tube rup-ture will cause a reduction in reactor coolant system
- volume and due to reactor coolant leakage into the steam j
generator, the affected steam generator level will continue
- I
?
to increase after the feeduater block valves are closed by SIAS. The resulting decrease in RCS pressure and volume lt ' will result in the RCS briefly being at saturation condi-l tions. The possibility then exists for void for=ation in the reactor coolant system.
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P:ga 2 of 16 EMERGENCY OPERATING PROCEDURE 0120041, REV. 13 ,
j STEAM GENERATOR TUBE LEAK / FAILURE !
- 3.0 Purpose and Discuasion: (Cont'd) ) .
3.2 (Cont'd) ,,j ;
3.2.2 Operator action should be directed toward prompt isolation of the affected Steam Generator, to minimize contamination j
of the steam system and prevent possible radioactive release to the environment. With the exception of a compound i
- accident in which loss of power accompanies the Steam i Generator Tube failure, steam is dumped to the condenser, l
rather than the atmosphere, to prevent gross release of l contamination to the environment. Action must be taken to i identify the affected Steam Generator as soon as possible and to isolate its feedwater flow to prevent water slugging f
the steam lines.
3.2.3 The Steam Generator Tube failure accident is most severe i when it occurs at low power levels, due to the low inventory I of water initially present in the pressurizer.
i.
j 3.2.4 This procedure provides instructions for two cases, " Leak within the Capacity of the Charging Pumps" and " Tube l failure" (exceeds Charging Pump Capacity).
4.0 Symptoms
(
4.1 Unique to a Steam Generator Tube Failure / Leak:
3 i
j 4.1.1 Steam Generator Blowdown Monitor Alarm.
4.1.2 Condenser Air Ejector Monitor Alarm.
I 4.2 Possibly Caused by a Steam Generator Tube Failure:
4.2.1 Decreasing Pressurizer Level, Backup Charging Pumps Start, Pressurizer Low Level Alarm, Pressurizer Heaters Ii Deenergize.
I 1 4.2.2 Decreasing Pressurizer Pressure, Backup Heaters Energize, t'
Pressurizer Low Pressure Alarm.
4.2.3 Initial Increase in Affected Steam Generator Level, Followed by Return to Programmed Level Setpoint.
4.2.4 Feedwater Flow Less Than Steam Flow on Affected Steam
?
Generator.
'. 4.2.5 Letdown Flow Decreasing.
4.2.6 Charging Flow to Regenerative Heat Exchanger Increasing.
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Pcg3 3 of 16 DfERGENCY OPERATING PROCEDURE 0120041, REV. 13 I STEAM GENERATOR TUBE LEAK / FAILURE
5.0 Instructions
5.1 Leak Within Capacity of Charging Pumps 5.1.1 Immediate Automatic Action: ,,,l 5.1.1.1 A Steam Generator blowdown monitor alarm will actuate a high radiar. ion alarm in control and signals to trip closed the blowdown and sample valves.
5.1.1.2 Letdown Level Control Valves close to minimum value.
5.1.1.3 Backup charging pumps are started as pressurizer level decreases.
5.1.2 Immediate Operator Action:
5.1.2.1 Place additional charging pumps in operation, if not operating, to restore pressurizer level.
5.1.2.2 Notify System Dispatcher and reduce turbine load in preparation for Reactor Shutdown if:
5.1.2.2.1 Tube leakage exceeds 1 GPM or, 5.1.2.2.2 The specific activity of the secondary system is greater than 0.10 ue/gm Dose Eq I-131.
NOTE: If either of these conditions exist be in at least Hot Standby within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in Cold
. . Shutdown within the next 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />, per Standard Technical Specifications.
l 5.1.2.3 Determine affected steam generator, if possible, by:
l 5.1.2.3.1 Comparing Steam Generator levels.
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5.1.2.3.2 Compa-ing Steam generators steam flow and feed l flow.
l l 5.1.2.4 Take manual control of atmospheric dump valve controller on affected steam generator, HIC-08-2A or HIC-08-23 and close atmospheric dump valve to zero percent valve position.
5.1.2.5 Check that the condenser air ejector vent is aligned to l the plant vent.
l 5.1.2.6 Ensure that steam generator blowdown valves and sample
! isolation valves are closed.
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e DiERGENCY OPERATING PROCEDURE 0120041, REV.13 STEAM GENERATOR TUBE LEAK / FAILURE 5.0 Instructions (cont.):
5.1 (cont) 5.1.3 Subsequent Action wi 5.1.3.1 Commence Turbine Shutdown. See OP #0030125 Turbine Shutdown Full Load to Zero Load.
5.1.3.2 Commence Reactor Shutdown. See OP #0030128, Reactor Shutdown.
5.1.3.3 Commence Reactor Plant Cooldown by dumping steam to the condenser manually using the steam dumps. See OF #0030127. Reactor Plant Cooldown Hot Standby to Cold Shutdown.
5.1.3.4 Lnplement the emergency plan as necessary in accordance with EPIP 3100021E; " Duties of the Emergency Coordinator".
5.1.33 Control Feedwater Flow to maintain steam generator no-load levels. -
5.1. 3 .6 When RCS pressure is reduced to 900 psia:
5.1. 3. 6.1 Close the affected steam generators steam isolation valve. (HCV-08-1A or HCV-08-13).
5.1. 3. 6. 2 Ensure that the steam isolation bypass valve (MV-08-1A or MV-08-1B) is closed.
5.1. 3. 6. 3 Isolate feedwater to the affected steam generator.
5.1. 3 .7 Continue reactor cooldown to a cold shutdown conditbn using the unaffected steam generator.
5.1. 3 .8 Sample the condensate system to determine activity levels. t
! 5.1. 3.9 Take air particulate and air gaseous samples in the following areas:
5.1.39.1 Air ejector after condenser and gland steam condenser combined vent.
5.1.3.9.2 Steam driven auxiliary feed pump exhaust.
l 5.1.3.10 Conduct radiation survey and post radiation areas as necessary.
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EMERGENCY OPERATING PROCEDURE 0120041 REV. 13 STEAM GENERATOR TUBE LEAK / FAILURE 5.0 Instructions (Cont'd) 5.2 Tube Failure (Exceeds Capacity of Charging Pumps)
Immediate Automatic Action: ,,g 5.2.1 5.2.1.1 A Steam Generator blowdown monitor alarm will actuate a high radiation alarm in control and signals to trip closed the blowdown and sample ,
valves.
5.2.1.2 Reactor trip if pressurizer pressure decreases to the TM/LP setpoint.
1 s
5.2.1.3 Initiation of safety injection if pressurizer pressure decreases to 1600 PSIA.
5.2.1.3.1 Initiation of SIAS will cause CIS
- actuation.
5.2.1.4 Letdown control valves close to a minimum value, I the backup charging pumps are started as pressu-
! rizer level decreases.
5.2.1.5 Pressurizer low low level alarms, and pressurizer heaters deenergize.
5.2.1.6 Turbine Trip (if reactor trips)
MOTE: If turbine trip occurs the Main Feed Regulating valves will close and the 15%
Bypass Valves will open to 5% flou position.
5.2.1.7 Initiation of AFU if steen generator levels decrease to 34%.
5.2.2 Lmnediate Operator Action:
5.2.2.1 Place additional charging pumps in operation, if not operating.
5.2.2.2 Start AFW pumps. if SIAS has occurred, and control S/G levels at no-load lev els.
5.2.2.3 If all feedwater flow is stopped or lost and steam 5 generator level is less than 42% then:
- 1. Reinitiate auxiliary feedwater flow as soon as possible; however, do not exceed a flow rate of 150 gpm per steam generator.
- 2. Limit feedwater flow rate to 150 gpm per steam generator until continuous feedwater flow to the SG
, has been maintained for five minutes. q 1
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Paga 6 of 16 DiERGENCY OPERATING PROCEDURE 0120041 REV. 13 I STEAM GENERATOR TUBE LEAK / FAILURE
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5.0 Instructions (Cont'd) 5.2 Tube Failure (Exceeds Capacity of Charging Pumps) 5.2.2 Immediate Operator Action: (continued) 5.2.2.4 Notify dispatcher and reduce turbine load in preparation for reactor shutdown.
5.2.2.5 Determine affected steam generator by:
5.2.2.5.1 Comparing steam generator levels.
5.2.2.5.2 Comparing steam generators feed flow and steam flow.
5.2.2.5.3 Comparing steam generator blowdown monitors.
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EMERGENCT OPERATING PROCEDURE 0120041, REV. 13 '
STEAM GENERATOR TUBE LEAK / FAILURE
5.0 Instructions
(Cone) 5.2 (Cont'd) ,
5.2.2 (Cont'd) 5.2.2.6 Take manual control of atmospheric dump valve controllers HIC 08-2A and HIC 08-23 and close them.
5.2.2.7 Check condenser air ejector vent aligned to the plant vent.
5.2.2.8 Insure the reactor trips when pressurizer pressure decreases to TM/LP setpoint.
5.2.2.9 Carry out immediate operator action for reactor trip per OP 0030130.
5.2.2.10 After an SIAS caused by low reactor coolant system pressure and af ter it has been verified that all CEA's have been fully inserted for 5 seconds, stop all operating reactor coolant pumps.
5.2.2.11 Ensure safety injection and containment isolation actuation signals have occurred or initiate manually.
Ensure HPSI flow to the ; ore when pressure decreases f below the pump's shut-off head ( 1250 psia).
4 I
5.2.3 Subsequent Action f
5.2.3.1 Refer to Table I to ensure the proper operation 1 of engineered safety features as time and condi-tions permit.
5.2.3.2 Control feedvater flow to maintain Steam f Generator no-load levels.
5.2.3.2.1 If safety injection actuation has occurred the auxiliary feedwater system must be used to control the steam generator levels.
4
/R13 When establishing auxiliary feed flow to the steam generator, use steam generator levels as well as header flow rates to ensure each steam generator is receiving auxiliary feedwater.
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EMERGENCY OPERATING PROCEDURE 0120041, REV. 13 l STEAM GENERATOR TUBE LEAK / FAILURE
5.0 Instructions
(Cont'd) 5.2 (Cont'd) 5.2.3 Subsequent Action (Cont'd) 5.2.3.2 (Cont'd)
NOTE: If possible, the electric driven auxiliary feedwater pumps should be used; however, if the steam driven pump is used, ensure steam supply is selected i
to the non-affected steam generator.
5.?-3.3 Ensure that HPSI pumps and charging pumps restore pressurizer level and pressure.
NOTE: Pressurizer pressure will stabilize at approximately 1175 PSIA and level at aoproximately 10%.
3 i
Implement with the emerge ncy EPIP.3100021E. plan asthe Duties,of necessary in accordance Emergency Coordinator ".
j 5.2.3. 4 Restore ICW to TCW Heat Exchangers by opening MV-21-2 and MV-21-2.
5.2.3. 5 Stop emergency diesels if off site power is ,
available.
- 5. 2.3. 6 Close condenser hotwell reject valve, LCV 12-5.
5.2.3.7 Commence RCS cooldown using SBCS if available.
If the SBCS is unavailable, use steam dump to atmosphere on the non faulted steam generator.
4 5.2.3.8 Stabilize RCS cold leg temperature at 5050F.
NOTE: This temperature will ensure c.dequate NPSH for four pump operation with RCS pressure at 900 PSIA.
4 5.2.3.9 When pressurizer level increases above 30%,
energize pressurizer heaters.
5.3.2.10 De-pressurize RCS to 900 PSIA using pressurizer sprays. Throttle HPSI pumps discharge valves as required to maintain pressurizer level approximately 35%.
l 5.2.3.11 When RCS pressure is 900 PSIA, isolate the affected steam generator by closing its MSIV and bypass valve.
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- EHERGENCY OPERATING PROCEDURE 0120041, REV. 13 f I STEAM GENERATOR TUBE LEAK /FAILLTE '
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5.0 I Instructions: (Cont) l l 'md.
5.2 (Cont) 5.2.3 Subsequent Action (Cont) 5.2.3. 12 Ensure feedwater is isolated to the affected steam generator.
5.2.3. 13 To allow potential ECCS area radioactive leukage and RCS sample water, collected in the ECCS area sumps to be pumped to the Reactor Coolant Drain Tank inside containment, perform the following:
- 1. At the C.R.A.C. panel place the "ECCS Area Leakage System" control switch to the "RDT" .
position and ensure that:
HCV-06-9 "R.D. Pump Suction" closes HCV-06-7 " Sump Pump to EDT" closes j HCV-06-8 " Sump Pu=p to RDT" opens
- 2. At RTGB 105 open A0V-6301 and A0V-6302 "RDT Contmt Isol" valves by placing the switches e in reset, then open positons.
- 3. Ensure the C.R.A.C. panel annunciator'"ECCS
, Pump Room Leakage Valves Misaligned" is not
[ r lit.
NOTE: The following valves are provided with "CIS-0VERRIDE" capability:
'f A0V-5200, 5203 " Reactor Coolant Sa=ple" FCV-26-1, 3 " Containment Sample Supply" FCV-26-2, 4 " Containment Sample Return" 4 A0V-6301, 6302 "RDT Containment Isolation" f 5.2.3.14 Re-commence RCS cooldown using the non-affected i steam generator.
NOTE: Do not exceed 75 F cooldown in any one hour.
5.2.3.15 Block MSIS at 700 PSIA Steam Generator pressure, j
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I f EMERGENCY OPERATING PROCEDURE 0120041, REV. 13 i STEAM GENERATOR TUBE LEAK / FAILURE i I
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5.0 Instructions
(cont) l 5.2 (cont) l' i m
i 5.2.3 Subsequent Action (cont)
I -
1 5.2.3.16 Establish and maintain 50 0F sub-cooling in the reactor coolant system. With the Subcooling Margin Monitor (SMM) operating normally, use the nomograph on RTGB 104 in conjunction with the SM!
' to eliminate dependence on a single instrument.
With the SMM inoperable, refer to the nomograph .
utilizing control room indicators such as THOT, pressurizer pressure, and incore thermocouples to determine the margin to saturation. Sub-cooling margin can also be determined by subtracting hot ,
leg temperature frem pressurizer temperature (TE-1101).
5.2.3.17 Sample each steam generator for activity.
5.2.3.18 Sample the RCS to determine if there has been
( fuel failure.
5.2.3.19 Sample the condensate system to determine radioactivity levels.
5.2.3.20 Take air particulate and air gaseous samples in the area of the steam driven feed pump exhaust.
5.2.3.21 Conduct radiation surveys and post areas as
> required.
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l EMERGENCY OPERATING PROCEDURE 0120041, REV. 13 I
9 il 3l STEMi GENERATOR TUBE LEAK / FAILURE ! 5l i
1 I
6.0
References:
mumm 6.1 Instruction Manual - Steam Generators, St. Lucie Unit No. 1 877-=5008.
- 6.2 EBASCO Prints 8770-G-079, 080.
6.3 Accident Analysis, FSAR, Section 15.4.4, Steam Generator Tube i Failure.
7.0 Records Required:
7.1 Normal Log Entries.
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EMERGENCY OPERATING PROCEDURE 0120041, REV 13 12 of16 STEAM GENERATOR TUBE LEAK / FAILURE e
TABLE I 1.0 Safety Injection Actuation Signal ,
i ON l 1.1 Two HPSI Pumps ON 1.2 Two LPSI Punos 1.3 Eight HPSI Discharge Valves (HCV-3617, 3627, 3637, 3647) OPEN 1.4 Four LPSI Discharge Valves (HCV-3615, 3625, 3635, 3645) OPEN 1.5 Check proper operation of the Safety Injection System by the following means.
1.5.1 Check HPSI flow rates on: FI-3311, 3321, 3331, 3341.
1.5.2 Check LPSI flow ratas on: FI-3312, 3322, 3332, 3342.
1.5.3 Check decreasing Safety Injection Tank Levels on: LIA-3311, 3321, 3331, 3341.
ON 1.6 Two CCW Pumps 1.7 Two CCW Valves from SDC HX's (HCV 14-3A,
- OPEN HCV 14-3B).
ON 1.8 Four Containment Cooling Fans 1.9 Four CCW "N-Header" Isolation Valves (HCV-14-8.A, 14-9, 14-83, 14-10). SHUT 1.10 Four SIT Check Valve Leakoff Valves (V-3618, 3628, 3638, 3648). SHUT 1.11 Two R. A.D. Main Supoly Fans (HVS-4 A, 4D) ON 1.12 Two ECCS Area Exhaust Fans (HVE 9A, 9B) ON*
1.13 Eight Aux Bldg Dampers (D-5A, 6A, 9A, 12A, 5B, 6B, 9B, 12B) SHUT a
1.14 Four Aux Bldg /ECCS Pump Room Dampers (D-13, 14, 15, 16) OPEN 1.15 Four Reactor Coolant Pump CCW Isolation Valves (HCV-14-1, 14-2, 14-6, 14-7). SHUT 1.16 Two WP Discharge Valves (MV-09-1 MV-09-2) SHUT 1.17 Two Feedwater Block Valves (MV-09-7; MV-09-8) SHUT 1.18 Two Charging Pumps ON 1.19 Two Boric Acid Makeup Pumos ON SHUT 1.20 Two Letdown Isolati~t Valves (V-2515: V-2516)
SHUT 1.21 VCT Outlet Valve (V-2501) 1.22 Two Gravity Feed Valves (V-2508: V-2509) OPEN 1.23 Emergency Borate Valve (MV-2514) OPEN 1.24 Two Bam Pump Recire Valves (V-2510 V-2511) SHUT SHUT 1.25 Blender Outlet Valve to VCT (V-2512)
SHUT 1.26 Load Control Valve (MV-2525)
SHUT 1.27 Boric Acid Header Discharee Valve (MV-2161) 1.28 Two Rx Cavity Sump Isol Valves (LCV 07-11A; SHUT LCV 07-11B) 1.29 Two Intake Cooling Water Pumos ON 1.30 Two ICW to TCW Hx Isol valves (MV-21-2; MV-21-3) SHUT SHUT 1.31 'A' ICW Lube Wtr. Supply to CW Pumps (FSU-21-3A)
ICW Lube Wtr. Supply to CW Pu=ps (FSU-21-33) SHUT 1.32 'B'
- NOTE: Only one ECCS area exhaust fan is required, the other fan 4 should be shutdown and kept in standby.
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1 4 EMERGENCY OPERATING PROCEDURE 0120041, REV 13 ~
STEAM GENERATOR TUBE LEAK / FAILURE i TABLE 1 2.0 Containment Isolation Actuation Signal 2.1 Tvo Shield Building Vent Fa- s (MVE-6A, MVE-63) ON*
2.2 Two Control Room Vent Cooster Fans (HVE-13A. HVE-133) ON 2.3 Two Letdown Isolation Valves (V-2316, V2515) SHUT 2.4 Two RCS Samole Isolation Valves (V-5200, V-520I) SHUT i 2.5 Four Pressuriaer Sa...ple Valves (V-5201, V-5202, V-5204, V-5205) SHUT 2.6 One Instru=ent Air To Containcent Isolation Valve CIV-18-1) SHUT -
2.7 Six Containment Purge Valves (FCV-23-1, 25-3, 25-5, 25-6, 25-4, 25-2) SHUT 1 2.8 Two Containment Pur:;e Oxhaust Fans (HVE-8A, HVE-83) CFF 2.9 One Nitrogen to Containment Supolv Valve (V-6741) SHUT 2.10 Two Containment Waste Gas deader Isolation Valves (V-6554, V-6555) SHUT 2.11 Two Containment Sump Pump Discharge Valves (LCV-07-11A, LCV-07-11B) SHUT 2.12 Four Steam Generator Blowdown Isolation Valves (FCV-23-3, i
1 FCV-23-5, FCV-23-4, FCV-23-6) SHUT 2.13 Two Steam.Cenerator Blowdown Sample Isolation Valves i (FCV-23-7 and 9) SHUT I 2.14 Two Reactor Drain Tank Dif.; charge Isolation Valves (V-6301, V-6302) SHUT 2.15 Four Control Room Air Inlet Valves (FCV-25-16, FCV-25-17, j FCV-25-14, FCV-25-15) SHUT 7 2.16 Two Control Room Kitchen Air Exhaust Valves (FCV-25-24, FCV-25-25) SMUT 1
2.17 Two Control Room Toilet Air Exhaust Valves (FCV-25-18, i FCV-25-19) SHUT j 2.18 Six Containment Radiation Sample Suction and Return Valves (FCV-26-2. 4, 6. FCV-26-1, 3, 5) SHUT 2.19 Primar'f Makeup Water Isol Valve 01V-15-1) SHUT 2.20 Two RCP Controlled Bleedof f Isol Valves (V-2505 and ISE-01-1) SHUT
- NOTE: Only one shield building vent fan is required, the other should be shutdown and kept in standby.
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I
. EMERGENCY OPERATING PROCEDURE 0120041, REV 13 :
STEAM GENERATOR TUBE LEAK / FAILURE TABLE 1 m
j 3.0 Contain=ent Spray Actuatien Signal 3.1 Two Containment Spray Pumps ON 3.2 Two Containment Spray Header Inlet Valves (FCV-07-1A, FCV-07-13) OP E'i 3.3 Four NACH (Caustic) Admission Valves (FSE-07-1A, FSE-07-2A, FSE-07-1B, FSE-07-2B) OPEN 3.4 Verify Containment Spray Flow in FI-07-1A and FI-07-13.
3.5 Verify NA0H (Caustic) Flow on Post Accident Panel "A"
'(FI-07-2, FR-07-2)
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EMERGENCY OPERATING PROCEDURE 0120041, REV 13 h STEAM GENERATOR TUBE L"uut/ FAILURE 1
l TABLE 1 m-i 4.0 Recirculation Actuation Signal 0FF 4.1 Two LPSI Pumac ~
4.2 Two Safety Injection !!iniflow Recirc. Valves (V-3659, SHUT V-3660) OPEN 4.3 Two Containment Sumo Outlet Valves (MV-07-2A, MV-07-2B)
SHUT
- 4.4 Two RUT Outlet Valves (NV-07-1A, MV-07-13) 4.5 Verify HPSI flow to core continues after RAS on FI-3321, FI-3341, FI-3311, FI-3331.
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EMERGENCY OPERATING PROCEDURE 0120041, REV 13 .
STEAM GENERATOR TUBE LEAK / FAILURE I J
TABLE I 5.0 Main Steam Isolation signal -
Two Main Steam Isolation valves (HCV-03-1A, HCV-08-13) SHUT 5.1 5.2 Two Main Steam Isolation Bypass Valves (MV-08-IA, .l SHUT MV-08-1B) :l 5.3 Two Main Feedwater Pump Discharge Valves (MV-09-1, SHUT MV-09-2) I SHUT 5.4 Two Main Feedwater Block Valves (MV-09-7. MV-09-8) l s
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DOCUMENT .E/ISION DISTRI3UTION SHEET - OF NOR".AL & E!IRGENCY OPER. PROCEDURI DOCUMENT TITLE /uld) y
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DOCUMENT ?!LE NUMBER O /Jdd M2.
DOCUMENT REv:SION NUMBER '
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DATE DOCUMENT SENT TO:
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TRANSMITTAL COPY TRANSMIT"'A' No. DOCU M HOLDER RETURNED NO. DOCUMENT HOLDER PNTED
. MASTER UNCONTROLLED COPIIS
' 1 2
NRC-Region II 3
Attn: EPPS 3RANCE CH M E. Paduano - GO '
A'. ~J. Saliay 5 N. G. Roos 6 G. Anglehar: - CI TSC ,,,_
7 "- % 3 8 Training Training l
9 Watch Engineers I 191,8. /, a u. A j 10 11 g.p /,e<4,s g John Holwell-Backft:
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. R. R. Jaanings H. M. Mercer NRC - IE : EQ
! ~j Aten: Chief, Nuclear Response 1 3 ranch 3
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J PROCESSED ST: MM DATE V '12. #F f
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- Nota: New distribution per instrue:1cus. Eff ective 9-12-79.
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e i FLORIDA POWER & L p C M M ST. LUCIE UNIT No. I g GENCY PROCEDURE 0120042 h, q
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gg **76flINFO'JZT!0M00LE . .
This document is not controlled. Before use, LOSS OF REACIOR COCLANT verify information with a controlled document.
j 2.0 Aporoval:
Reviewed by Plant Nuclear Safety Commi: tee 19 U
- , Approved by - b Plant Supr.,
19__
4 Revision 12 R v1 w by Facil* *y Review Group Dge. /O 197 9 Approved by / /. ; , 2 / .anager /h_, iT 19 7 /
Revision 13 Mediewed by Fa'cility Review Group .. . . 19 '
- Approved $y (d ./)ff// f h ,. Plant Manger .A L . 2 9 19 re Revision 22 Reviewed by Facility Review Group - . l / 19 ' '.
Approved by /DMu_/.M, Plant Manager Alde e / fo - 19A
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3.0 Purtose and Discussion:
i 3.1
Purpose:
This procedure provides instructions to be followed in t.ne event that leakage from the Reactor Coolant System is in
-I excess of operable charging pump capacity.
1 i 3.2 A loss of coolant accident is defined as any mechanism where the loss of coolant from the Reactor Coolant System exceeds
' the capacity of the operable charging pumps. When conditions in the Reactor Coolant System degrade to the point that a I;1miting Safety System Setting is approached the Reactor Protective System will initiate a reactor trip, making the reactor suberitical. This will stop the production of power in the core. Cooling of the core however, must continue to remove the considerable decay heat that remains. the Safety Inj ection System automatically provides a flow of subcooled water to the core for decay heat removal. Failure to keep the core covered will result in overheating of the fuel, failure ^of the cladding, and a release of gross amounts of j fission products to the containment atmosphere.
m 1
The spectrum of breaks which would cause a LOCA is from
) approximately a .2 inch diameter break up to a double-ended hot leg rupture. For an example: Analysis show that the flow j frem an unrestricted .3 inch diameter break is approximately
~
180 gp3 at 2250 psia. A major concern for these small breaks is that the flow through the break may not be sufficient for i decay heat removal. In those circumstances it is imperative j that a secondary heat sink be available. This in turn dictates (
the use of the Auxiliary Feedwater System as the main feed-water system is disabled due to an SIAS.
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+l 4,
C EMERGENCY PROCEDURE 0120042, REV. 22 $
LOSS OF REACTOR C001.\NT j l
i l 3.0 Purpose and Discussion (Cont'd) 3.2 (Cont'd)
- I Operator actions should be directed toward ensuring proper operation of the Safety Injection and Containment Isolation Systems, ensuring all automatic functions have initiated properly, and taking action to protect plant personnel. Long term action is directed toward placing the plant in a cold .
shutdown condition. For small breaks where the ECCS will maintain RCS volume and pressure, operator action must be directed toward establishing and maintaining subcooled condi-tions in the RCS during the cooldown to prevent void formation.
l 4.0 Symptoms / Precautions:
Pressurizer level may not always be a true indicator of RCS fluid inventory. Pressurizer steam space ruptures, reference leg failures, and reference leg flashing msy cause indications which are contrary
- to true conditions.
All available indications should be used to aid in diagnosing the event since the acci.ient may cause irregularities in a particular instrument reading. Critical parameters must be verified when one or more confirmatory indications are available. With the Subcooling i Margin. Monitor (SMM) operating normally, use the nomograph on RTGB 104 in conjunction with the SM to eliminate dependence on a s, ingle instrument. With the SMM inoperable, refer to the nomograph utilizing control room indicators such as THOT, pressurizer pressure, and incore thermocouples to determine the margin to saturation. Subcooling margin can also be determined by subtracting hot leg temperature from pressurizer temperature (TE-1101) .
When establishing auxiliary feed flow to the steam generators, use steam generator levels as well as header flow rates to ensure each steam ger.erator is receiving auxiliary feedwater.
i The diagnostic chart on Page 20 may be of some value in analyzing j
parameters.
4.1 Reactor coolant system leak exceeds the capacity of the operable charging pumps.
, 4.2 Reactor trip (Thermal Margin / Low Pressure) 4.3 Safety Injection Actuation Signal and Containment Isolation Actuation signal.
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1 EMERGENCY PROCEDURE 0120042, PIV. 22 LOSS OF u.ACTCR COOLANT 4.0 Symotems/ Precautions:
4.4 Any one or more of the following indications or alar =s may be present:
WI 4.4.1 Decreasing pressurizer pressure.
4.4.2 Increasing contaic=ent pressure and temperature.
4.4.3 Rising water level in the reactor cavity sump.
k 4.4.4 Righ containment radiation.
4.4.5 Decreasing or increasing pressurizer level.
4.4.6 Quench tank high 12 vel.
I 4.4.7 Quench tank high temperature.
- 4.4.8 Quench tank high pressure.
)
4.4.9 Tavg decreasing or at saturation te=perature for RCS j pressure.
j REV 16 4.4.10 Safety or relief valve (s) open alars H-il.
3 l
. CAUTION: Some instru=ents (valve position, temperature
- pressure, level indication, etc.) specified j for use in this procedure have not been de-
}
signed for lonS term post LOCA conditions
- inside the containment. Therefore, the
- operator should be especially alert that the
.j potential exists for erroneous indication
'i after >15 minutes have elapsed following a
{ LOCA event.
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EMERGENCY PROCEDURE 0120042, REV. 22 r. I LOSS OF REACTOR C00LANI ? % -
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5.0 Instructions
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5.1 I= mediate Automatic Actions Reactor trip / turbine trip 5.1.1 5.1.2 Safety injection actuation signal 5.1.3 Containment isolation actuation signal 5.1.4 Containment spray actuation signal 5.2 Immediate Operator Action 1
5.2.1 Carry out immediate operator actions for reactor trip per OP 0030130.
5.2.2 After an SIAS caused by low reactor coolant system pressure and after it has been verified that all CEA's have been fully inserted for 5 seconds, stop all 3
, operating reactor coolant pumps.
5.2.3 Ensure safety injection and containment isolation actuation signals have occurred or initiate manually.
a} Ensure HPSI flow to the core when pressure decreases I below the pump's shut-off head ( 1250 psia).
5.2.4 Establish and maintain steam generator levels at 65%
with auxiliary f eedwater system.
) CAUTION: Do not exceed 75 F/hr cooldown rate.
1 5.2.5 If all feedwater flow is stopped or lost and steam R22 generator level is less than 42% then:
- 1) Reinitiate auxiliary feedwater flow as soon as possible; however, do not exceed a flow rate of 150 gpm per steam generator.
l 2) Limit feedwater flow rate to 150 gpm per steam generator until continuous feedwater flow r.o the SG has been
- maintained for five minutes.
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5.2.6 If conditions permit, attempt to locate and isolate the source of the leak. Possible leak locations include, h but are not limited to the PORV's, the letdown line, and sample lines.
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LOSS OF REACTOR COOLANT -l
} l
5.0 Instructions
(Cont'd) 5.3 Subsequent Actions Observe all available indications to determine conditions 4 within the RCS. Use SMM display, RCS hot leg temperature, ;
bus RCS cold leg temperature, incore thermocouple temperature, and RCS pressure to determine if the RCS is subcooled or saturated. An increase in temperature above the saturation t temperature for the existing pressure is an indication of voiding in the RCS. If this occurs the operator must ensure that the RCP's are turned off, the SIS is providing makeup to t!A RCS, and that the steam generators are removing heat from j the RCS. The operator may be assured that a heat sink is
) available by observing steam generator feedflow and steamflow, by indications that steam generator levels and pressures are being controlled, and by observing that operation of the steam generators is maintaining or decreasing RCS temperature and pressure.
5.3.1 Refer to Table I to ensure the proper operation of engineered safety features as time and conditions permit.
j 5.3.2 Implement the emergency plan as necessary in accordance with EPIP 3100021E, " Duties of the Emergency Coordinator".
j j 5.3.3 Ensure that containment spray is actuated if containment pressure exceeds 10 psig, and check the following:
2 containment spray pumps ON i'
2 spray header inlet valves OPEN
) 4 NaOH admission valves OPEN NaOH flow indication in control %30 gpm room on post accident panel 4
- 5.3.4 When containment pressure decreases to less than 10 psig, stop 1A and 1B containment spray pumps, close FCV 07-LA and FCV 07-1B, reset CSAS channels A and B, and return containment spray pumps and FCV switches to the " auto" position.
i 5.3.5 Within one (1) hour, but without exception no later than one (1) hour stop RCS/BAMT boration via the charging pumps.
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P;gn 6 of 21 EMERGENCY PROCEDURE 0120042, REV. 22 I LOSS OF REACTOR COOLANT
,F a 1
5.0 Instructions
(Cont'd) i f
- [
5.3 (Cont'd) '
] 4
- 5.3.6 Continue to ensure proper operation of the safety y:
injection system by checking flow rates and S.I.T.
levels.
s After any SIAS, operate the SIS until RCS hot and cold leg temperatures are at least 50 F below saturation temperature for the RCS pressure and a pressurizer level is indicated, unless the cause of the SIAS has been i verified to be an inadvertent actuation. If 50 F 1 subcooling cannot be maintained after the system has been stopped, the high pressure injection system must i be started.
e
' CAUTION: Minimum pressure - temperature operating restrictions take precedence over requirements
.) for operation of the high pressuge injection
- or charging system to achieve 50 subcooling i during operation of the shutdown cooling system.
t
$ 5.3.7 Implement the Emergency Plan as necessary in accordance
) with EP 3100021E, " Duties of Emergency Coordinator".
5.3.8 To allow potential ECCS area radioactive leakage and RCS
[ sample water, collected in the ECCS area sumps to be i pumped to the Reactor Coolant Drain Tank inside contain-ment, perform the following:
- 1. At the C.R.A.C. panel place the "ECCS Area Leakage j System" control switch to the "RDT" position and j ensure that:
HCV-06-9 "R.D. Pump Suction" closes HCV-06-7 " Sump Pump to EDT" closes HCV-06-8 " Sump Pump to RDT" opens
- 2. At RTGB 105 open A0V-6301 and A0V-6302 "RDT Contmt Isol" valves by placing the switches in reset, then
!j open positions.
- 3. Ensure the C.R.A.C. Panel Annunciator "ECCS Pump j Room Leakage Valves Misaligned" is not lit.
l? NOTE: The following vlaves are provided with l "CIS-0VERRIDE" capability:
A0V-5200, 5203 " Reactor Coolant Sample"
) FCV-26-1, 3 " Containment Sample Supply" FCV-26-2, 4 " Containment Sample Return" 3
A0V-6301, 6302 "RDT Containment Isolation" (
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EMERGENCY PROCEDURE 0120042, REV. 22 ;
LOSS OF REACTOR COOLANT l
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5.0 Instructions (cont) ;
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- 5.3 (cont) ,. ,
s 5.3.9 Immediately prior to the receipt of the Recirculation Actuation Signal restore power to V3659 and V3660.
5.3.10 Commence RCS cooldown as soon as possible and in any case, within one (1) hour. Reduce steam generator .
pressure to <985 psig. (safety setting). Refer to OP 0030127, Reactor Plant Cooldown.
CAUTION: Ensure RCS is maintained in a subcooled ,
condition.
5.3.10A If steam dump to condenser is available, close the Atmospheric Steam Dumps, and begin dumping steam to condenser.
5.3.10B If offsite power is lost, steam dump to atmosphere must be used for cooldown.
5.3.10C Continue auxiliary feedwater flow to the steam
~
g generators during cooldown.
) 5.3.10D Do not exceed the 750F/ hour cooldown rate.
5.3.10E If the RCS pressure remains greater (after stabili-zation) than the shutoff head of the LPSI pumps, stop l both pumps.
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', CAUTION: Feedvater is norma *1y provided to both steam generatora. Isolat. ion of a single steam
! generator per OP0120041 (Steam Generator Tube Leak / Failure) is mandatory if a steam generator tube rupture is detected in that
] generator to prevent lifting of the safety valves or reseat them if they have lifted.
This action will also reduce the amount of
- radioactivity released. For small breaks in the RCS where steam generators are
! inportant for heat removal one steam l
generator must be used for this purpose I_
even if primary to secondary leaks are detected.
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EMERGENCI PROCEDURE 0120042, REV. 22 '
LOSS OF REACTOR COOLANT .
}
1
) 5.0 Instructions (cont.) l
- 5.3 (cont.) Q l
5.3.10 When the RW level reaches 6.f c., ensure that at least one (1) containment spray pump is running. Open the necessary valve (s) as indicated by pump conditions to l provide cooled water from the shutdown cooling heat
{ exchanger (s) to the HPSI pump (s) during recirculation.
1 MV-3662 S.D.C. to 13 and 1C HPSI pumps
' MV-3663 S.D.C. to lA HPSI pump This is the preferred line-up for long term cooling.
! 5.3.11 Ensure that Recirculation Actuation (RAS) occurs when
! the RWI level decreases to 3 f t. indicated - (4 ft.
from the bottom of the tank) and check the following:
f 2 LPSI pumps TRIP 2 Miniflow recire valves SHUR 2 Containment sump outlet valves OPEN CAUTION: Ensure HPSI flow to the core . continues after RAS. Do not allow the HPST pumps to operate " dead-headed". HPSI shutoff head (no flow) 1250 psig.
5.3.12 Ensure V3659 and V3660 are closed, then de-energize the valves using key operated switches on RTGB 106.
5.3.13 If all HPSI pumps and charging pumps are operating and l-the HPSI pumps are delivering less than 75 gpm per pump, turn off the charging pumps one at a time and then HPSI l'
l pumps one at a time until only one HPSI pump remains l
operating. This will ensure that minimum flow require-l1 ments will be met by the flow through the pump to the l RCS for the smallest break size that results in a SIAS.
I
! 5.3.14 Monitor R. A.B. radiation levels and sump levels af ter
! RAS to detect safety injection system leakage. Even if
,' leaks are detected at least one HPSI pump must remain in operation to provide flow to the RCS.
i<
'i 5.3.15 As soon as possible, but without exception, within ten (10) hours, hot leg injection shall be initiated to the core in conjunctf on with the existing cold leg injection being sustained by the HPSI pumps per Appendix A.
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EMERCENCY PROCEDURE 0120042, REV. 22 a i LOSS OF REACTOR COOLANT 5.0 Instructions (cont.) i l-5.3 (cont.) -.
5.3.16 If the pressure and inventory control with the SIS cannot be established af ter eight hours and RCS pressure is less than 300 psig, continue the hot and cold leg injection.
NOTE: It may be necescary to fill the pressurizer solid to regain pressure control and to achieve 500F subcooling. If this is the case the HPSI discharge valves will have to be carefully throttled during the cooldown to reduce system pressure.
5.3.17 If pressure and inventory centrol with the SIS are established af ter eight hours and RCS pressure is greater -
than 300 psig, conduct one of the following activities.
The activities are listed in order of decreasing preference.
- 5. 3.17 A RCS pressure above 300 psig indicates that the system has refilled and subcooling has occurred. Verify this by checking the saturation pressure for the existing tem-perature. Realign the safety injection system for cold leg injection. Continue to maintain cubcooling and reduce RCS pressure to <268 psia for shutdown cooling by reducing the flow delivered by the high pressure injection and charging pumps. While reducing pressure and after shutdown cooling is initiated, maintain RCS pressure with the charging pumps and/or the HPSI pumps to continue to maintain at least 50 subcooling, or CAUTION: If there is a high radioactivity level in the reactor coolant system, circu]3 tion of this fluid in SDC may result in high area radio-activity readings in the auxiliary building. The activity level of the RCS should be determined prior to l initiating SDC flow.
1
- 5. 3.17 B Continue to remove decay heat using auxiliary feedwater and steam dumps if adequate condensate is available and (A) cannot be implemented, or
- 5. 3.17 C Open pressurizer power operated relief valves and align the safety injection system for cold leg injection if (A) or (3) cannot be implemented.
To open the PORV's, pull two RPS pressurizer high
' pressure trip unit bistables. #$
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EMERGENCY PROCEDURE 0120042, REV. 22 :
LOSS OF REACTOR COOIXIT 5.0 Instructions (cont.) , l l n 5.3 (cont.) jj l 5.3.18 Place both Hydrogen Recombiners in service per Appendix B.
5.3.19 If containment hydrogen concentration cannot be maintained below 3.5% as indicated on the containment hydrogen sample system by tw (2) hydrogen recombiners, then place the containment hydrogen purge system into operation per
! Appendix B.
1 6.0
References:
6.1 FSAR Chapters 4, 6, Appendix 6C, 7, 8, 9, 15.
7.0 Records Required:
7.1 Normal Log Entries 2
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I Page 11 of 21 EMERGENCY PROCEDURE 0120042, REV 22 (
LOSS OF REACTOR COOLANT APPENDIX A i HOT LEG INJECTION j j
,; L 0 i
- 1. Prerequisite 8 a) Recirculation actuation signal has been initiated and required automatic functions have occured.
b) RCS pressure <250 psia. If RCS pressure is greater than 250 psia, continue cool-down until less than 250 psia.
- 2. Precautions a) Observe suitable radiological precautions -
1 at manual operating stations.
- b) Ensure a minimum flow path to avoid dead-heading the HPSI, containment spray, and LPSI pumps.
c) Containment spray pump flow shall not exceed 1500 CPM.
I i d) LPSI pump flow shall not exceed 3500 GPM.
}
- 3. Primary method of hot leg injection using l
1 LPSI pumps via hot leg suction line.
l 3 a) Ensure RCS/ containment AP less than 150 I psid.
l
! b) Select operable LPSI pump and use applicable 4 valve lineup
-j A LPSI operable B LPSI operable I c) Shut V3207 and 3432 3206 and 3444 d) Open V3400 V3484 e) Shut HCV 3615, 3625 HCV 3615, 3625 3635, 3645 3635, 3645 f) Open V3651 and 3652 V3481 and 3480 g) Start LPSI 1A LPSI 1B h) Monitor flow FT3306 & 3332 FT3306 & 3322
- 1) Maintain minimum flow of 250 gpm f NOTE: If power is lost to one set of SDC hot leg suction valves, notify electrical
] department to install jumpers.
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si Page 12 of 21 EMERGENCY PROCEDURE 0120042, REV 22 il 1 LOSS OF REACTOR COOLANT q
i, APPENDIX A (cont)
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- 4. Alternate Me*: hod: Hot leg injection using
{
HPSI pumps via pressurizer auxiliary spray.
a) Stop charging pumps and shut V-2336, 2337, 2339.
b) Open V-2340 CV a to HPSI Auxiliary header X connect.
c) Shut ISE-02-01 and I-SE-02-02, IB1 and 1A2 loop chargine isolation valves.
< d) Shut PCV-1100E and F, pressurizer spray .
valves.
] e) Unlock and open I-SE-02-03 and I-SE-02-04 auxiliary spray valves.
a f) One HPSI ptop (B or C) must remain available to recirculate water from containment i sump to HPSI header.
1 -
l 1) To use A HPSI pump for hot leg in-3 jection, shut valves HCV 3617, 3627, a 3637 and 3647 and maintain minimum flow of 200 gpm through auxiliary j spray by monitoring charging flow indicator FT 2212.
- 2) To use C HPSI pump for hot let in-I3 jecticn (A pump not available), unlock and shut MV3653 and open MV3655. Shut i) '
HCV 3617, 3627, 3637 and 3647 and maintain flow of 200 gpm through auxiliary spray by monitoring charging j flow indicator FT 2212.
- 5. Secondary Alternate Method: Hot leg injection ij using CS pump via hot leg suction line Il 4 l3 a) Condition, RCS/ containment AP <150 psid.
- i b) With 1 B containment spray pump running; open or check to be open V-3457.
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l Ji c) Place HIC-3306 Keyswitch in the Auto lj j position.
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Page 14 of 21 '
il EMERGENCY PROCEDURE 0120042, REV 22 Il LOSS OF REACTOR COOLANT "--
l' APPENDIX 3 PLACING H., RECOMBINER AND I
CONTAINMENT ~H PURGE IN SERVICE 2
i . . _ . ;
- 1. Place re e biners in service as follows: 'l 1A 13
- 2. Set the power adjust potentiometer at zero (ooo)
- 3. Check that power is available to the ,
power supply panel by observing the
" power available" white light on the control panel is illuminated.
- 4. Set the Power Out Switch on the control panel to the "0N" position. The red light on the switch will illiminate.
- 5. Gradually turn the Power Adjust potent-iometer to 70 KW as indicated on the
) Power Out Wattmeter.
CAUTION: There is a lag in the meter reading, so turn the potent-iometer know slowly. Do not exceed 75 KW.
- 6. Periodically check the temperature of the three thermocouples using the temperature channel selector switch.
And, when the temperature reaches 1250 F, adjust the power adjust potentiometer to maintain temperature between 1250 F and 1400 F.
CAUTION: Do not let the temperature
,i exceed 1400 F as indicated by the thermocouple readout.
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Page 16 of 21 1 i EMERGENCY PROCEDURE 0120042, REV 22 }
LOSS OF REACTOR COOLANT m'
TABLE 1 2.0 Containment Isolation Actuation Siknal j 2.1 Two Shield Building Vent Fans (HVE-6A, HVE AB) ON*
2.2 Two Control Room Vent Booster Fans (HVE-13A, HVE-133) ON
- a. 2.3 Two Letdown Isolation Valves (V-2516, v2515) SHUT 2.4 Two RCS Sample Isolation Valves (V-5200, V-5203) SHUT 2.5 Four Pressurizer Sample Valves (V-5201, V-5202,. V-5204, V-5205) SHUT 2.6 One Instrument Air To Containment Isolation Valve (MV-18-1) SHUT
- b. 2.7 Six Containment Purge Valves (FCV-25-1, 25-3, 25-5, 25-6, j
25-4, 25-2) SHUT 2.8 Two Containment Purge Exhaust Fans (EVE-8A. HVC-8B) OFF 2.9 One Nitrogen to Containment Supolv Velve (V-6741) SHUT 2.10 Two Containment Waste Gas Header Isolation Valves (V-6554, V-6555) SHUT 2.11 Two Containment Sump Pump Discharge Valves (LCV-07-llA, LCV-07-11B) SHUR 2.12 Four Steam Generator Slowdown Isolation Valves (FCV-23-3, FCV-23-5, FCV-23-4, FCV-23-6) SHUT 2.23 Two Steam Generator Blowdown Sample Isolation Valves (FCV-23-7 and 9) SHUT 2.14 Two Reactor Drain Tank Discharge . Isolation Valves (V-6301, V-6302) SHUT 2.15 Four Control Room Air Inlet Valves (FCV-25-16, FCV-25-17, FCV-25-14, FCV-25-15) SHUT 2.16 Two Control Room Kitchen Air Exhaust Valves ,(FCV-25-24, FCV-25-251 SHUT 2.17 Two Control Room Toilet Air Exhaust Valves (FCV-25-18, 4
FCV-25-19) SHUT 2.18 Six Containment Radiation Sample Suction and Return Valves (FCV-26-2, 4, 6, FCV-26-1, 3, 5) SHUT 2.19 Primary Makeup hater Isol Valve (MV-15-1) SKUT 2.20 Two RCP Controlled 31eedoff Isol Valves (V-2505 and ISE-01-1) SHUT
- NOTE: Only one shield building vent fan is required, the other j should be shutdown and kept in standby. Open FCV-25-13, Cross connect valve.
- NOTE: Due to the possibility of NAMCO position indication switch failure on the letdown isolation valves, V2515, V-2516, containment purge valves FCV25-3, FCV25-4, and radiation monitor isolation valves FCV26-1, FCV26-3, FCV26-5, perform the following on receipt of valid CIS.
- a. V2515, V2516: Close valves using switch on RTCB, ensure valves closed by observing letdown flow, press, etc.
- b. FCV25-3, FCV25-4: Ensure other valves in the line are closed .
(FCV25-1, FCV25-2, FCV25-5, FCV25-6)
FCV26-1, FCV26-3, FCV26-5: Close valves using RTGB switch, close l c.
manual valves at monitor cabinet, ensure no flow indication on monitor.
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s EMERGENCY PROCEDURE 0120042, REV 22 l
[ LOSS OF REACTOR COOLANT .
1 l l
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J TABLE 1 y
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4.0 Recirculation Actuation Signal Two LFSI Pumps OFF 4.1 '
[ 4.2 Two Safety Injection Miniflow Recire. Valves (V-3659, 1: ' SHC c q
V-3660) OPEN Two Containment Sumo Outlet Valves (MV-07-2A, MV-07-28) 4.3 Two RWI Outlet Valves (MV-07-1A, MV-07-13) SHUT 4.4 l 4.5 Verify HPSI flow to core continues af ter RAS on FI-3321, FI-3341, FI-3311, FI-3331.
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j TABLE I -
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1.0 Safety Inj ection Actuation Signal 1.1 Two HPSI Pumps ON 1.2 Two LPSI Pumps ON 1.3 Four AUX HPSI Discharge Valves (HCV-3617, 3627, 3637, 3647) OPEN 1.4 Four HPSI Discharge Valves (HCV 3616, 3626, 3636, .
3646) nerv 1.5 Four LPSI Discharge Valves (HCV-3615, 3625, 3635, 3645) OPEN 16 Check proper operation of the Safety Injection System by the follouing means.
1.5.1 Check HPSI flow rates on: FT-3311, 3321, 3331, 3341.
I 1.5.2 Check LPSI flow rates on': FI-3312, 3322, 3332, 3342, 1.5.3 Check decreasing Safety Injection Tank Levels on: LIA-3311, 3321, 3331, 3341.
- 1. 7 Two CCW Pumps ON
' l.3 Two CCW Valves from SDC EX's (HCV 14-3A, HCV 14-3B). OPEN 1.9 Four Containment Cooling Fans ON 1.10 Four CCW "N-Header" Isolation, Valves (HCV-14-8A, 14-9, 14-8B, 14-10). SHUT 1.lk Four SIT Check Valve Leakoff Valves (V-3618, 3628, 3638, 3648). SHUT 1.12 Two R. A.E. Main Supply Fans (HVS-4A, 4B) OM l.13 Two ECCS Area Exhaust Fans (HVE 9A, 9B) ON*
i 1.14 Eight Aux Bldg Da=pers (D-5A, 6A, 9A, 12A, 5B, 63, 9B, 12B) SHUT 1.15 Four Aur. Bldg /ECCS Pump Room Dampers (D-13, 14, 15, 16) OPEN 1.16 Four Reactor Coolant Pump CC7 Isolation Valvec (HCV-14-1, 14-2, 14-6, 14-7). SHUT 1.17 Two FWP Discharge Valves (MV-09-1; MV-09-2) SHUT 1.18 Two Feedwater Block Valves (MV-09-7; MV-09-8) SHUT ~~
1.17 Two Charging Pumps ON 1.27 Two Boric Acid Makeup Fumos ON 1.21' Two Letdown Isolation valves (V-2515; V-2516) SHUT SHUT 1.22 .VCT Qutlet Valve (V-2501) 1.23 Two Gravity Feed Valves (V-2508; V-2509) OPEN l
1.24- Emergency Borate Valve (MV-2514) OPEN SHUT 1.25 Two Bam Pumo Recire Valves (V-2510. V-2511)
SHUT a'
1.26- Blender Outlet Valve to VCT (V-2512)
SHUT 1.27 Load Control Valve (MV-2525)
SHUT 1.28 Boric Acid Header Discharre Valve (MV-2161) i 1.29 Two Rx Cavity Sump Isol Valves (LCV 07-llA; ,
SHUT I LCV 07-11B)
Two Intake Cooling Water Pumos ON 1.30 i
1.3 L Two ICW to TCW Hx Isol Valves (KV-21-2; MV-21-3) SHUT A
1.32 'A' ICW Lube WTR Supply to CW Pumps (FLV-21-3A) SHUT __
SRUT 1.33 'B' ICW Lube WTR Sucolv to CW Pumos (FLV-21-1B)
- NOTE: Only one ECCS area exhaust fan is required, the other fan 24 should be shutdown and kept in standby.
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