ML20038C476
| ML20038C476 | |
| Person / Time | |
|---|---|
| Site: | Saint Lucie  |
| Issue date: | 11/19/1981 |
| From: | FLORIDA POWER & LIGHT CO. |
| To: | |
| Shared Package | |
| ML17212B187 | List: |
| References | |
| PROC-811119-01, NUDOCS 8112110101 | |
| Download: ML20038C476 (65) | |
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yLORIDA POWER & LIGHT CCMPANT Sr. LUCII UNIT #1 EMERGENCT OPERATING PROCEDURE 0030141 REVISION I
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F0:1 I::FrW.T!D!! Oill.Y y Control Room Inaccessibility Lis dem l-is re cc+cled. 3efo o use. 2.0 Aoprovali Reviewed by ? N Approved b7 aae Sa.fsc7 Commuittee 1 12 1977 Al . I4 Planc Manager v 19 7
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Revision 8 Reviewed by FRG Ney ea b y ._/4 _ _19 ? t Anuroved by #)Eg&h Plant Manager /,b. / F" - 198./.n 00 Purpose & Discussion: 7 .---. 3.1 The purpose of this procedura is to provide instructions for placing the plant in a safe condition when operations cannne safely be conducted from the control room.
- 3. 2. The reactor and turbine are =anually cripped prior to leaving the control toon if possible or locally from the Reactor Trip Switch-gear and the turbine front se,ndard.
3.3 A heat sink is provided by. automatic steam dump to the conderier and/or to at:nosphere. 3 . 4. Level is =aintained in the steam generators by manual control of and' d n 7 feedwater valves with flow furnished by the- am4 7 d ar7 feedvater pumps. 3.5 Pressuriter level and. pressure are =aintained by manual control of pressuriter heaters, spray valves and letdown valves and are monitored at the hoc shut?cwn panel. 3.6 Isolacic1r switches. located in the Reactor Auxiliary 3uilding Electrical , Equipment Room,. the Turbine Su11 ding Switchgear Roos, the Diesel
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Generator Rooms, and the Reactor Am411ary Building are ==*11 7 selected to the isolate position to prevent inadvertent operation of vita.1 equipment due to possible electrical malfunction in the unattended control room 3.7 A copy of this procedure- v1The posted at each =anned operating staticu required for planc shutdown from outside the control center. 3.1 A list:.ng of.1 solation switches will be posted ou each of the following pansls,. MCO's and distribution buses. a) Load Canters 1A 13, lA3 b) Isolation. Switch Pancis A, 3, LAB [ c) MCO 1AS, lA6, 135, 136 l d) 41607 Buses. lA3,133, lAa a) 4160V 3uses 1A2, 132 f) 6900V 3uses lA1,131
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l g) Diesel Generator 1 & 3 Control' Panels l l l t
4 , Pags 2 of 28 i DfERGENCY OPERATING PROCEDURE 0030141 RETISION 3 l 3.0 Purpose & Discussion: (con't.) 3.9 The Plant Sup- . visor will utilize additional personnel as available
, to assist in required subsequent actions.
4.0 Symptoms
4.1 Conditions existing such that the Control Room becomes uninhabitable and must be evacuated. 4 e 5 4 I i i l I 4 1 i l 9 4 i i I i I e I 1 i dm== 4 ___ ,,_. .. % . -.ee w == -
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s-Pego 3 of:28__* i - p EMERGENCY OPERATING PROCEDURE 0030141 REVISION 8
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5.0 Instructions
5.1 Immediate Action 5.1.1 Manually trip the Reactor and Turbine before leaving the Control Room, if possible. 5.1.2 Announce evacuation of the Control Room over the P.A. system. 5.1.3 Man and take control of emergency Hot Shutdown Stations as follows: 5.1.3.1 Control Center Operator "A" - Hot Shutdown Control . Panel 5.1.3.1.1 Establish communications on the Sound Power Phone System 5.1.3.1.2 Monitor available plant parameters on the Hot Shutdown Control Panel. 5.1.3.1.3 Start motor or steam driven Auxiliary Feed Pumps and Feed Steam Gens. as required. 5.1.3.1.4 Control' pressurizer pressure and level by manual control of pressurizer heaters, spray valves and Letdown valves. 5.1.3.2 Nuclear Plant Supervisor - Electrical Equipment Room /R5 EL 43: Reactor Auxiliary Building , 5.1.3.2.1 Open or check open Reactor Trip Breakers . TCB1-8 5.1.3.2.2 Place isolation switches in the isolate position on the following switchgear in , the order listed:
- 1) 480V Bux 1A3 Pressurizer heaters
- 2) 480V Bux 133 Pressurizer heaters
- 3) 480V L.C. lA2
- 4) 4160V Bus LA3
- 5) 480V MCC 1A5
- 6) 480V MCC 1A6
- 7) 480V L.C. 132
) 8) 4160V Bux 1B3 i 9) 480V MCC 136 . 10) 480V MCC 135
- 11) 480V MCC 1A3
- 12) Isolation Panel LAB 13). Isolation Panel 1A i
- 14) Isolation Panel 13
- 15) Evacuation Alars Isolate Panel
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, . TMERGENCY OPERATING PROCEDURE 0030141
- REVISION 8
.- 5.0 Instructions:
. 5.1.3.2.2 Assist CCO operator "A" in monitoring j ,
unit parameters from Hot Shutdown Control Panel. 4 - ;., q* ,
, 5.1.3.'3' control Center coerator "3" - Turbine Operating
. Level
, . g 5.1.3.3.1 Locally trip or verify tripped Unit No.
g , 4 ( l Turbine.
, , .-- i 5.1.3.3.2 Verify Turbine Stop Valves and Control
,, Valves are shut, and if not, initiate i turbine trip from turbine front standard.
t , 5.1 3.3.3 Proceed to Turbine Building Switchgear
+
'\ s Room and establish consnunications on the Sound Powered Phone circuit.
5.1.3.3.4 Place Isolate switches to isolate position on 4160V Bus IA2, 132 Bus feeders, 6900V w ,, Bus lAl, 131 Bus feeders.
. - , *s . -~ 5.1.3.3.5 Shutdown lA & 13 Steam Gen. Feed Pumps, V' ,
lA & 13 Heater Drain Pumps and one conden-
, ., ; sate pump by opening their respective i breakers. 'f CAUTION: Insure that one condensate pump j
remains in service.
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*, '. 5.1.54 Nuclear Ooerator - Reactor Auxiliary Building l
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'i * . 5.1.3.4.1 Place isolation switches in isolated /
local position on 4160V Bus LAB, 480V L.C.
! v , LAB
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5.1.3.4.2 Proceed to D.G. 31dg. and place isolation t switches on A & 3 Diesel Control Panels in isolate position.
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5.1.3.4.3 Proceed to charging pump area and
. ?? establish communications on the Sound Powered Phone circuit.
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Ptge 5 of 28 EMERGENCY OPERATING PROCEDURE 0030141 b REVISION 8 5.0 Ins;: ructions: (con't) 5.2 Subsequent Action 5.2.1 Maintain pressurizer level at the "0" load setpoint. 5.2.2 Maintain pressurizer pressure at approximately 2100 psia. 5.2.3 Maintain Reactor Coolant System temperature at or below 532 F (lA cold leg temp) by use of atmosphere steam dump and/or selective shutdown of Reactor Coolant pumps. 5.2.3.1 Shutdown Reactor Coolant pumps as required by opening pg the Reactor Coolant pump breakers in the turbine building switchgear room. i 5.2.5 Maintain steam generator level at the "0" load setpoint
- by operation of the auxiliary feedwater pumps and discharge valves to the steam generators.
- 5.2.6 After RCP coast down, shut down reactor coolant pump bearing lift pumps as required, by opening breakers in the Reactor AnH 14 =7 Building Electrical Equipment Room (MCC 1AS, 135, j IA6,1B6) and reclosing the breakers af ter one minute.
i 5.2.7 Isolate steam generator blowdown by manually closing isola-tion valves at the closed blowdown heat exchangers(valves j
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,23-112, 23-113, 12-137, 23-138).
i 5.2.8 When turbine speed decreases to "0" RPM, verify that the , , turning gear oil pump and the turning gear are in operation. t l 5.2.9 Periodically check the habitability of the main control j room and when conditons permit, reoccupy the Control Room. I Return isolation switches to normal for switches and { controls that are operational and maintain the Unit at hot standby until a complete evaluation has been made. l 5.2.10 If Control Room accessibility is not possible, make pre-parations to place the Unit in a cold shutdown condition by utilizing Operating Procedure OP 0030127 Reactor Plant Cooldown - Hot Standby to Cold Shutdown, as a guide and substituting local manual operations where required. NOTE: Prior to depressurization bele.w 1600 psia, a manual blocking of all equipment associated with SIAS must be accomplished to prevent SIAS actuation.
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EMERGENCY OPERATING PORCEDURE 0030141 REVISION 8
- ISOLATION SWITCHES Isolation Panel lA - Auxiliary Bldg. Electrical Equipment Room um
- 1. SS/189-1 Amiliar:r Spray valve l 2. SS/158 ' Letdown &-Spray- Valves *:Cohtrol
- 3. SS-3/603 S.G. lA Press. & Lavel Indication
- 4. SS-1/603 S.G. lA Atmospheric Steam Dump Control
- 5. SS1/380 S.G. lA Level (wide range)
- 6. SS/130 ,
- Bressuri' ereLevelrand.Presse-Indication I
- 7. SS-1/157 Letdown Isolation Valve I f 6
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Pags 7 'of 28 _- t FLORIDA POWER & LIGHT COMPANY l ST. LUCIE UNIT #1 EMERGENCY OPERATING PROCEDURE 0030141 I REVISION 8 ISOLATION SWITCHES 480 V Bus lA3 - Pressurizer heater bus, Aux 414= 7 building Electrical Equipment Room
- 1. Heater bank P-1
- 2. Heater Bank B-1
- 3. Heater Bank B-2
- 4. Heater Bank B-3 t
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Paga 8 of _28.__, 1 FLORIDA POWER & LIGHT COMPANY ST. LUCIE UNIT #1
, EMERGENCY OPERATING PROCEDURE 0030141 , REVISION R:
j ISOLATION SWITCHES i 480 V Bus 133 - Pressurizer heater bus,- Auxiliary bldg. Electrical Equipment Room "
- 1. Heater Bank P-2
- 2. Heater Bank B-4 ;
4
- 3. Heater Bank B-5
- 4. Heater Bank 3-6 i
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4 Page 9 of 26' l i-i EMERGENCY OPERATING PROCEDURE 0030141 i. REVISION 8 i i e i 1 i
, lA2 480V Load Center - AM11ary Building Elect.rical Equipment Room ,W
- 1. SS Transformer 1A2 .
< g j 2. Bus Tie to 430V 1AB ! !, 3. Air Recire Fan HVS 1A
- 4. Air Recirc Fan HVS 13 ,
- 5. Charging Pump 1A
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Page 10 of 28 ~ ELORIDA POWER & LIGHT CCMPANY ,
; ST. LUCIE UNIT #1 EMERGENCY OPERATING PROCEDURE 0030141 REVISION 8 ISOLATION SWITCHES 4160 V Bus lA3, Anv414mry Building Electrical Equipment Room 1g
- 1. "A" HPSI pump
- 2. "A" LPSI pump
- 3. "A" Containment Spray Pump ,
- 4. Feed to Pressurizer Heater Transformer 1A
- 5. "A" Component Cooling Pump.
- 6. "A" Intake Cooling Pump
- 7. Feed to 4160 7 Bus LAB
- 8. Feed from 4160 V Bus lA2
- 9. Feed to 480 V Station Service Transformer 1A2
- 10. Feed from Energency Diesel "A"
- 11. "A" Anviliary Feed Pump i
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Paga ll of~28 FLORIDA POWER & LIGHT COMPANY 4 ST. LUCIE UNIT #1 g EMERGENCY OPERATING PROCEDURE 0030141 j REVISION 3 > ISOLATION SWITCHES { MCC 1A5 Isolation Switches - Anv414mry Building Electrical Equipment Room " '
- 1. V-2514 - Makeup bypass to charging pumps
- 2. MV-14 Air Recirculation Cooler inlet Header "A"
- 3. MV-14 Air Recirculation cooler outlet Header "A" .
- 4. MV-09 Anxiliary F.W. pump "A" discharge to "A" Steam Generator
- 5. MV-09 Anriliary F.W. pump "A" discharge to "B" Steam Generator e
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d Page 12 of 281 FLORIDA POWER & LIGHT COMPANY STL LUCIE UNIT #1 EMERGENCY OPERATING PROCEDURE 0030141 I REVISION 8 l ISOLATION 5"JITCHES MCC 1A6 Isolation Switches - A M 11ary Bldg. Electrical Equipment Roota
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- 1. Boric Acid Makeup Pump 1A
- 2. Boric Acid Makeup Pump 13
- 3. HVA-3A - Control Room Outdoor Air Conditioner .
- 4. HVE-6A - Shield building Exhaust Fan
- 5. HVE-13A - Control Room Booster Fan e
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i I Pags 13 of 28 '_ j EMERGENCY OPERATING PROCEDURE 0030141 , REVISION 8 i c a I i 132 480V Load Center - Auxiliary Bldg. Elect. Equip. Room ; ; l 4
- 1. SS Transformer 132 !
- )
- 2. Bus Tie to 480V 1AB ,
- 3. Air Recirc Fan HVS 1C i 4. Air Recire Fan HVS 1D
- 5. Charging Pump 13 4
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i 1 Pag 2 14 'of ~ 28 ~ FLORIDA POWER & LIGHT COMPANY ST. LUCIE UNIT #1 EMERGENCY OPERATING PROCEDURE 0030141 REVISION F ISOLATION SWITCHES 4160 V Bus 133 - Anv414mry Building Electrical Equipment Roon
- 1. Feed from Emergency Diesel "B"
- 2. Feed to 480 V Station Service Transformer 132
. 3. Feed to Pressurizer Heater Transformer IB
- 4. "B" Component Cooling Pump
- 5. "3" HPSI pump
- 6. "3"!I2SI; pump
- 7. "B" Containment Spray pump
- 8. Feed to 4160 V Bus IAB
- 9. "B" Intake Cooling Pump .
- 10. Feed from 4160 V Bus IB2 11, "B" Aur114 ary Feed Pump.
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1 . . Page ~15'of 28- i FLORIDA POWER & LIGHT COMPANY t ST. LUCIE UNIT #1 EMERGENCY OPERATING PROCEDURE 0030141 REVISION 8 ISOLATION SWITCHES men MCC-136 -- Auri14ary Building. Electrical Equipment Room
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- 1. HVE-6B - Shield building Erhaust Fan l 2. EVA-3B - Control Room Air Conditioner
- 3. HVE-13B - Control Room booster fan ,
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paga j 6 3f 28 , { FLORIDA POWER & LIGHT COMPANY ; ST. LUCIE UNIT #1 i EMERGENCY OPERATING PROCEDURE 0030141 REVISION 8 h ISOLATION SWITCHES l MCC 135 - AuM 1427 Building Electrical Equipment Room
- 1. V-2508 - BA Tank 13 Gravity Feed
- 2. V-2509 - BA Tank 1A Gravity Feed.
- 3. MV-09-10-- AnH11ary F.W. pump "3" discharge to "B" S.G.
. 4. MV-14 Air Recirculation Cooler OUTLET Edr. "B"
- 5. MV-14 Air Racirculation Cooler INLET Hdr. "B" l 6. V-2504 - RWT to charging pumps.
i ! 7. MV-09-14. t e i e I t e a
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Page 17 of 281 , i FLORIDA POWE2 & LIGHT COMPANY ST. LUCIE UNIT #1 j EMERGENCY OPERATING PROCEDURE 0030141 i REVISION 8 ! ISOLATION SWITCHES , { mm> MCC-1AB - Anviliary Building Electrical Equipment Room
- 1. EVA-3C - Control Room Air Conditioner, Indoor _ Unit.
- 2. MV-09 And T4=ry Feed Pump IC discharge to "A" Steam Generator
- 3. MV-09 Anviliary Feed pump IC discharge to B Steam Generator .
- 4. MV-14 CCW discharge Valve - A Edr.
- 5. MV-14 CC7.' discharge valve - B Edr.
; 6. MV-14 CCW discharge Valva - A Edr.
- 7. MV-14 CCW discharge Valve B Edr.
- 8. MV-08-13 "A" Sem HDR Supply Viv to "1C" Aux F.W. Pump
- 9. MV-08-14 "3" Stm HDR Supply Viv to "lC" Aux F.W. Pump e
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Page l_8_o f_k8 EMERGENCY OPERATING PROCEDURE 0030141-REVISION '8 ISOLATION SWIT 'HES Isolation Panel 1A3 - Auxiliary Bldg. Electrical Equipment Room ,
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- 1. Auxiliary FWP 1C Turbine Governor and Speed Indication .SS/631
- 2. Auxiliary FWT 1C Stop Valve. ss/632 i
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f Page '19 of 28 I -' DERGENCY OPERATING PRCOEDtiRI 0030141 ! REVISION 8 i ISOLATION SWITCHES Isolation Panel IB - Auxiliary Building Electrical Equipment Room __ i 1. SS-4/604 SG LB Press. & Level Indication
- 2. SS-2/603 Atm. Sem. Dump control ,
- 3. SS/189-2 Aux. Spray Valve
- 4. SS-2/157 Letdown Stop Valve l S. SS2-380 S.G.1B Level (vide range) R/7 i
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f EMERGENCY OPERATING PROCEDURE 0030141 , REVISION 8 1 ISOLATION SWITCHES j Isolation Panel, Comm2nications Room , Reactor Auxiliary Bldg. -
- 1. Fire Alarm / Site Evacuation - Control Console, Isolation Switch
! 2. Control Room PA Isolation Switch
- 3. Code Call Isolation Switch.
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FLORIDA POWER & LIGHT COMPANY I ~ ST. LUCIE UNIT #1 I EMERGENCY OPERATING PROCEDURE 0030141 REVISION $- ISOLATION SWITCHES men 4160 V Bus LAB - Ground floor Reactor Aimiliary building
- 1. "C" HPSI. pump - " Local" Switch-Position
- 2. "C" Component Cooling Pump -
" Local " Switch Position ,
- 3. "C" Intake Cooling Pump -
" Local" Switch Position
- 4. Feed from 4160 V Bus lA3 l' 5. Feed from 4160 V Bus 133 1,
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1AB 480V Load Center - Reactor Anv414mry Building - Ground floor m i .
- 1. Bus tie to 480V 1A2
- 2. Charging Pump 1C
- 3. Bus Tie to 480V Swgr 132 t
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I l FLORIDA POWER & LIGHT COMPANY i ST. LUCIE UNIT #1 n j DfERGENCY OPERATING PROCEDURE 0030141
~ ) REVISION 8' i j
ISOLATION SWITCHES l
- A. Diesel Generator Control Panel i
4 num 1 1. Voltage Control
- 2. Frequency Control
- 3. Start Circuit I
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Page 24_of 28, l FLORIDA POWER & LIGHT COMPANY ST. LUCIE UNIT #1 DfERGENCY OPERATING PROCEDURE 0030141 REVISION # l ISOLLTION SWITCHES B. Diesel Generator Control Panel ,
- 1. Voltage Control
- 2. Frequency Control
- 3. Start Circuit i
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! ?ags 25_of28 FLORIDA POWER & LIGHT COMPANY ST. LUCIE UNIT #1 EMERGENCY OPERATING PROCEDURE 0030141 i REVISION 2-j ISOLATION SWITCHES 4160 V Bus lA2 - Turbina Building Switchgear Room "
- 1. Feed to 480 V Station Service Transfor:ner 1Al
- 2. Feed to 4160 V Bus lA3
- 3. Feed from S.U. Transfor:ner LA 9
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t FLORIDA POWER & LIGHT COMPANY ST. LUCIE UNIT #1 i EMERGEhCY OPERATING PROCEDURE 0030141 REVISION 4.
~ ISOLATION SWITCHES 6900 V Bus lAl - Turbine building "
1 Switchgear Room
- 1. Feed from S.U. Transformer LA 9
1 4 4 i f { f V 4 i ! > l3 i ~ i 6
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' Pega .27 'of 28 FLORIDA POWER & LIGHT COMPANY ST. LUCIE UNIT pl 1
EMERGENCY OPERATING PROCEDURE 0030141 REVISION P. ISOLATION S4 ITCHES j . 4160 V Bus 132. - Turbine Building , Switch Gear Room.
- 1. Feed to Station Service Transformer IBl
- 2. Feed to 4160 V Bus 133 .
- 3. Feed from S.U. Transformer 1B i
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Paga 28 of" 28' FLORIDA POWER & LIGHT COMPANY ST. LUCIE UNIT #1 I EMERGENCY OPERATING PROCEDURE 0030141 REVISION 8 ISOLATION SWITCHES 6900 V Bus 131 - Turbine Building ' i Switchgear Room amm
- 1. Feed from S.U. Transfor:ner 13
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FLORIDA ?OWER & LIGHT CCMPANT , r ST. LUCIE UNIT NO. 1 / ZMERGENCT OPERAT NG PRCCEDURE 0120041 RE71SION NO. 9 ,
1.0 Title
6
. ,,,e STEAM Mvm'"0R TUBE L2AK/ FAILURE
2.0 Annroval
Reviewed by: Plant Nucleab- Safety Cesaittee b7 19 N Approved.by: o. N, /3 he Art / Plant Maoager c- 21 19 7,s
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Revisiou 7 Reviewed by FRG .4;'e bou" 19 19~79 19.2 2,_ Approved Ey: d /J/L W AS.lant Manager /O'- 1 Revision 9 reviewed $yFRd A/o n m I s /,_1981 1981. Approved.by /CM_ , ///h Plant Manager
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3.0 P d5os'e and Disc 6ssion: _ , r 3.1 The purpose of this procedure is to list the indicati.:ns that wd " enable the operator to identify a Steam Generntor T be failure and to provide the action to be taken to contial the - accident and -4""4 e radioactive release to the enviror ent.
3.1 Discussien
3.2.1 A Stean Generator Tube Failure causes leakage of reactor coolane into the stesn systen. If the 1*nage exceeds the capacity of the charging pumps, pressurizar pressure will decrease rapidly, causing a ther=al sargin/ 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 resulcing in initiation of safety injection and contahenc isolation. The tube rup-ture v111 cause a reduction in reactor coolant system volume and due to reactor coolant leakage into the steam generator, the affected steam generator level will continue to increase after the feedwater bicek valves are closed by SIAS. The resulting decrease in RCS pressure and velume will result in the RCS briefly being at saturation condi-a tions. The possibility then ar'sts for void formatian in .
' the reactor coolanc system.
F O R OF002.MT!00 0 01.Y This document is not controlled. Before use, J verify information with a controlled document. I e , e e = e.e.o. _ h _. 4 ep*#.pIr*
- Pag's 2 of14 EMERGENCY OPERATING PROCEDURE 0120041, REV. 9 4
STEAM GENERATOR TUBE LEAK / FAILURE j
- 3. 0' Purpose and Discussion: (Cont'd) 3.2 (Cont'd) '
numm 3.2.2 Operator action should be directed toward prompt isolation
; of the affected Steam Generator, to minimize contamination of the steam system and prevent possible radioactive release to the environment. With the exception of a compound accident in which loss of power accompanies the Steam Generator Tube failure, steam is dumped to the condenser, rather than the atmosphere, to prevent gross release of contamination to the environment. Action must be taken to ident.ify the affected Steam Generator as soon as possible ,
and to isolate its feedwat~er flow to prevent water slugging the steam lines. 3.2.3 The Steam Generator Tube failure accident is teost severe when it occurs at low power levels, due to the low inventory
! of water initially present in the pressurizer.
3.2.4 This procedure provides instructions for two cases, " Leak within the Capacity of the Charging Pumps" and " Tube failure" (exceeds Charging Pump Capacity). 1
4.0 Symptoms
4.1 ' Unique to a Steam Generator Tube Failure / Leak: l 4.1.1 Steam Generator Blowdown Monitor Alarm. i 4.1.2 Condenser Air Ejector Monitor Alarm. i i 4.2 Possibly Caused by a Steam Generator Tube Failure: k 4.2.1 Decreasing Pressurizer Level, Backup Charging Pumps
; Start, Pressurizer Low Level Alarm, Pressurizer Heaters
- Deenergize.
4.2.2 Decreasing Pressurizer Pressure, Backup Heaters Energize, Pressurizer Low Pressure Alarm. , I' 4.2.3 Initial Increase in Affected Steam Generator Level, ll Followed by Return to Programmed Level Setpoint. i
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4.2.4 Feedwater Flow Less Than Steam Flow on Affected Steam
' ~
Generator. A ,! - 4.2.5 Letdown Flow Decreasing. 1 4.2.6 l Charging Flow to Regenerative Heat Exchanger Increasing. i << i
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s DiERGENCY OPERATING PROCEDURE 0120041, REV. 9 STEAM GENERATOR TUBE LEAK /FAII.URE
. 5.0 I
.s 3 4 nsifuerions:
. -5.1' Leak k*ichin Capacity of Charging Pumps
~, 5.1.1 Immediate Automatic Action: .l
_ . 5.1.1.1 A Steam Generator blowdown ronitor alarm will actuate
..", s.
a high radiation alarm in control and signals to trip I
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closed the blowdown and sample valves.
~ 1- 5.1.1.2 Letdown Level Control Valves close to minimum value.
< \ ,N 3 'N 5.1.1.3 Backup charging pumps are started as pressurizer level decreases. .
s N 5.1.2 Immediate Operator Action: l 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 gre'acer than 0.10 uc/gm Dose Eq - 's .
I-131. . NOTE: If either of these conditions exist be in at least Hot Standby within 6 hours and in Cold Shutdown within the next 30 hours, per Standard
, Technical Specifications.
l i 5.1.2.3 Determine affected steam generator, if possible, by: 5.1.2.3.1 i_ Comparing ~SteWGenerator levels. _ __ _ 5.1.2.3.2 Comparing Steam generators steam flow and feed ! flow. 5.1.2.4 Take manual control of atmospheric dump valve controller j on affected steam generator, HIC-08-2A or HIC-08-2P. l ' and close atmospheric dump valve to tero percent valve l position. h!
! 5.1.2.5 Check; that the condenser air _ ejector vent. is aligned to ,.
3 the plant vent. j 5.1.2.6 Ensure that steam generator blowdown valves and cample isolation valves are closed, i e a - g 6 a
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Pega 4 of 14 DERGENCY OPERATING PROCEDURE 0120041, REV. 9 STEAM GENERATOR TU3E LEAK / FAILURE 5.0 Instructions (cont. ) : 5.1 (cont) 5.1.) Subsequent Action amm ' 5.1.3.1 Comunence Turbine Shutdown. See OP #0030125, Turbine Shutdown Full Load to Zero Load. 5.1.3.2 Conumence Reactor Shutdown. See OP #0030128, Reactor Shutdown. 5.1.3.3 C5iiinence Reactor Plasit C661d5w~n~b'y- dumping steam to . the condenser manually using the steam dumps . See OP #0030127, Reactor Plant Cooldown Hot Standby to Cold Shutdown. , 5.1.3.4 Control Feedwater Flow to maintain steam generator no-load levels. 5.1.3.5 When RCS pressure is riidu1c to 900 psia: 5.1.3.5.1 Close the affected steam generators steam isolation valve. (HCV-08-1A or HCV-08-1B). 5.1.3.5.2 Ensure that the steam isolation bypass valve (MV-08-1A or MV-08-13) is closed. 5.1.3.5.3 Isolate feedwater to the affected steam generator. 5.1.3.6 Continue reactor cooldown to a cold shutdown conditbn using the unaffected steam generator. 5.1.3.7 Sample the condensate system to determine activity levels. 5.1.3.8 Take air particulate and air gaseces samples in the following areas: 5.1.3.8.1 Air ejector af ter condenser and gland steam condenser combined vent. 5.1.3.8.2 Steam driven auxiliary feed pump exhaust. I 5.1.3.9 Conduct radiation survey and post radiation areas as necessary. mWe
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Prg2 5 of 14 EMERGENCY OPERATING PROCEDURE 0120041 REV. 4 STEAM GENERATOR TU3E LEAK / FAILURE 5.0 Instructions (Cont'd) 5.2 Tube Failure (Exceeds Capacity of Charging Pu=ps) 5.2.1 I= mediate Automatic Action: ,,, 5.2.1.1 A Steam Generator blowdown mon'.cor 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. 5.2.1.3 Laitiation of safety injectiou it pressuri:er pressure decreases to 1600 PSin. 5.2.1.3.1 Initiation of SIAS will cause CIS actuation. 5.2.1.4* Letdown control valves close to a mini =um value, the backup charging pumps are started as pressu-riser level decreases. 5.2.1.5 ' Pressurizer low low level alar =s, and pressurizer heaters deenergize. 5 . 2.1. '6 Turbine Trip (if rcactor trips) NOTE: If turbine trip occurs the Main Feed Regulating valves will close and the 152 Bypass Valves will open to 52 flow position. 5.2.2 I= mediate Operator Action: 5.2.2.1 Place additional charging pu=ps in operation, if not operating. 5.2.2.2 Notify dispatcher and reduce turbine load in prepara-tion for reactor shutdown. 5.2.2.3 Determine affected steam generator by: 5.2.2.3.1 Comparing steam generator levels. 5.2.2.3.2 Comparing steam generators feed flow and stems flow. 5.2.2.3.3 Comparing steam generator blewdown monitors. i e s }
f Pago 6 of 14 l EMERGENCYOPNRATINGPROCEDURE 0120041, REV. 9 STEAM GENERATOR TUBE LEAK / FAILURE
5.0 Instructions
(Cont) 5.2 (Cont'd) . 5.2.1 (Cont'd) 5.2.2.4 Take manual control of atmospheric dump valve controllers HIC 08-2A and HIC 08-23 and close them. 5.2.2.5 Check condenser air ejector. vent aligned to the plant vent. 5.2.2.6 Insure the reactor trips when pressurizer pressure decreases to IM/LP setpoint. 5.2.2.7 Carry out innediate operator action for reactor trip per OP 0030130. 5.2.2.8 After an SIAS caused by low reactor coolant i system pressure and after it has been verified that all CEA's have been fully inserted for 5 se,conds, stop all operating reactor coolant pumps. 5.2.2.9 l uure safety injection and containment isolation _ctuation signals have occurred or initiate manually. Ensure HPSI flow to the core when pressure decreases below the pump's shut-off head ( 1250 psia). 5.2.3 Subsequent Action 5.2.3.1 Refer to Table I to ensure the proper operation of engineered safety features as time and condi-tions permit, i 5.2.3.2 Control feedwater flow to maintain Steam 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 ;
non-affected steam generator level. I When establishing auxiliary feed ficw 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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1 Pago 7 of 14 DERGENCY OPERATING PROCEDURE 0120041, REV. 9 } STEAM GENERATOR TU3E LEAK / FAILURE
5.0 Instructions
(Cont'd) 5.2 (Corc'd) 5.2.3 Subsequent Action (Cont'd), um 5.1.3.2 (Cont'd) NOTE: If possible, the electric driven ^ l auxiliary feedwater pumps should hc used; however, if the steam driven pump is used, ensure steam supply is selected - to the non-affected steam generator. 5.2.3.3 Ensure that HPSI pumps and charging pumps restore pressurizer level and pressure. NOTE: Pressurizer pressure will stabilize at approximately 1175 PSIA and level at approximately 10%. l 5.2.3.4 Restore ICW to TCW Heat Exchangers by opening MV-21-2 and MV 21-3. 5.2.3.5 Stop emergency diesels if off site power is available. 5.2.3.6 Close condenser hoewell reject valve, LCV 12-5. 5.2.3.7 Commence RCS cooldewn using SBCS if available. If the SBCS is unavailable, use steam dump to atmosphere on the noa faulted steam generator. 5.2.3.8 Stabilize RCS cold leg temperature at 505 F. NOTE: This temperature will ensure adequate NPSH for four pump operation with RCS pressure at 900 PSIA. 1 5.2.3.9 When pressuriser level increases abeve 30%, energize pressurizer heaters. 5.3.2.10 De-pressurice RCS to 900 PSIA using pressuriser sprays. Throttle HPSI pumps discharge valves
- as required to maintain pressurizer level approximately 35%.
! 5.2.3.11 When RCS pressure is 900 PSIA, isolate the j affected steam generator by closing its MSIV
. and b3 pass valve. 1 - t i p . . ..
Page 8 of 14 DfERGENCY OPERATING PROCEDURE 0120041, RE". 9 STEAM GENERATOR IU3E LEAK /FAILCRE
5.0 Instructions
(Cont'd) 5.2 (Cont'd) 5.2.3 Subsequent Action (Cont'd) ' mim 5.2.3.12 Ensure feedwater is isolated to the affected steam generator. 5.2.3.13 Re-co::::ence RCS cooldewn using the non-affected steam generator.
. NOTE: Do not exceed 75 F cooldown in any one hour. -
5.2.3.14 Block MSIS at 600 PSIA Steam Generator pressure. 5.2.3.15 Establish and = air.cain 50 F sub-cooling in the reactor coolant system. With the Subcooling Margin Monitor (SMM) operating normally, use the nomograph on RTG3 104 in conjunction with the SMM to eliminate dependence on a single instrument. With the SMM incperable, refer to the comograph utilizing control room indicators such as TEOT, pressurizer pressure, and incore thersoccuples to determine the margin to saturation. Sub-cooling margin can also be determined by subtracting hot leg temperature from pressurizer temperature (TE-1101). 5.2.3.16 Sample each steam generator for activity. i 5.2.3.17 Sa=ple the RCS to determine if there has been fuel failure. 5.2.3.18 Sample the condensate system to determine radio-activity levels. 5.2.3.19 Take air particulate and air gaseous samples in the area of the steam driven feed pu=p exhaust. t 5.2.3.20 Conduct radiation surveys and post. areas as required. i i dD- S h
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Ptgs 9 of 14 I DfERGENCY OPERATING PROCEDURE 0120041, REV. 9 STEAM GENERATOR TU3E LEAK / FAILURE i i i 6.0
References:
ml 3 6.1 Instruction Manual - Steam Generators, St. Lucie Unit No.1 8770-5008. 6.2 EBASCO Prints 8770-G-079, 080.
- 6.3 Accident Analysis, FSAR, Section 15.4.4, Steam Generator Tube
] Failure. I 7.0 Records Required: i 1 7.1 Nor:nal Log Entries.
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EMERCENCY OPERATING PTSCEDURE 0120041, REV9Ptss 10 of 14- I STEAM GENERATOR TUBE LEAK / FAILURE TABLE I 1.0 Safety Infection Actuation Signal 1.1 Two HPSI Pumps ON 1.2 Two LPSI Pu=os ON 1.3 Eight EPSI Discharge Valves (HCV-3ol7, 3627, 3637, 3647) OPEN i.4 Four LPSI Discharge Valves (HCV-3015, 3625, 3635, 3645) OPEN
. 1.5 Check proper operation of the Safety Injection System by the following neans.
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. 1.6 Two CCW Pumos ON 1.7 Two CCW Valver from SDC H1's (UCV 14-3A,
- HCV 14-3B). OPEN 1.8 Four Containment Cooling Fans ON 1.9 Four CCW !'N-Header" Isolation ValveI(HCV-14-8A, ,
14-9, 14-8B. 14-10). SHUT , 1.10 Four SIT Check Valve Leakoff Valves (V-3bl8,
. 3628. 3638, 3648). SHUT 1.11 Two R. A.B. Main Supplv Fans (HVS-4A 4D) ON 1.12 Two ECCS Area Exhaust Fans (HVE 9A. 93) ON*
1.13 Eight Aux Bldg Dampets (D-5A, 6A, 9A, 12A, SB, bB, 9B. 12B) SHUT - 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 Feedvater Block Valves (MV-09-7: MV-09-8) SHUT 1.18 Two Charging Pumps ON 1.19 Two Boric Acid Makeup Pumps ON 1.20 Two Letdown Isolation Valves (V-2515: V-2516) SHUT 1.21 .VCT Outlet valve (V-2501) SHUT i 1.22 Two Gravity Feed valves (V-2508: V-2509) OPEN 1.23 Emergency Borate Valve (MV-2514) OPEN 1.24 Two Bam Pumo Recire Valves (V-2510, V-2511) SHUT i 1.25 Blender Outlet Valve to VCT (V-2512) SHUT 1.26 Load Control valve (MV-2525) SHUT 1.27 Boric Acid Header Discharge Valve (MV-2161) SHUT
; 1.28 Two Rx Cavity Sump Isol Valves (LCV 07-llA; LCV 07-113) SHUT 1.29 Two Intake Cooling Water Pumps ON
!] 1.30 Two ICW to TCW Hx Isol Valves (MV-21-2; MV-21-3) SHUT i
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I.3I 'A' IC7 Lube Wtr. Stipply to.CW Pumps (PSU-21-3A) .ShW I. 12 '3' ICW Lube Wtr. Supply to CW Pumos (FSU-21-33) ~ SHUT-
- NOTE: Only one ECCS area exhaust fan is required, the other fan should be shutdown and kept in standby. .
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Pcg311 of 14 IMERGENCY OPERATING PROCEDURE 0120041, REV 9 STEAM GENERATOR TUBE LEAK / FAIL'JRE TABLE 1 mmm 2.0 Containment Isolation Actuation Signal 2.1 Tvo Shield Building Vent Fa-'s (HVE-6A, HVE-6B) ON* 2.2 Two Control Room Vent Booster Fans (HVE-13A, HVE-138) CN 2.3 Two Letdown Isolation Valves (V-2516, V2515) SHUT
. 2.4 Two RCS Sanole Isolation Valves (V-5200, V-5203) SHL7 2.5 Four Pressuriser Sample Valves (V-5201, 7-5202, V-5204, V-5205) M7 2.6 One Instrument Air To Containment Isolation Valve 01V-18-1) SHUT 2.7 Six Containment Purge Valves (FCV-25-1, 25-3, 25-5, 25-6, 25-4, 25-2) SHUT 2.8 Two Contain: cent Purge Dthaust Fans (HVE-8A, HVE-8B) OFF 2.9 One Nitrogen to Containment Sucolv Valve (V-6741) SHUT 2.10 Two Containment Waste Gas lieader Isolation Valves (V-6554, .
V-6555) SHUT 2.11 Two Containment Sump Pump Discharge Valves (LCV-07-llA, LCV-07-113) SHUT 2.12 Four Steam Generator Blowdown Isolation Valves (FCV-23-3, FCV-23-5, FCV-23-4, FCV-23-6) SHUT 2.13 Two Steam, Generator Blowdown Sample Isolation Valves (FC*T-23-7 and 9)' SHUT 2.14 Two Reactor Drain Tank Discharge Isolation Valves (V-6301, V-6302) SHLT
~~
2.15 Four Control Room Air Inlec 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-25-25) MN 2.17 Two Control Room Toilet Air Exhaust Valves (FCV-25-18, FCV-25-19) SHUT 2.18 Six Contain=ent Radiation Sample Suction and Return Valves (FCV-26-2. 4, 6, FCV-26-1. 3, 5) SHL7 ' ~ 2.19 Primary Makeup Water Isol Valve 01V-15-l) SHUT
~
2.20 Two RCP Controlled Bleedof f Isol Valves (7-2505 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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Pag 212 of 14
. EMERGENCY OPERATING PROCEDURE 0120041, REV 9 STEAM GENERATOR TUBE LEAK / FAILURE :
TABLE 1 m 3.0 ' Containment Soray Actuation Signal ' 3.1 Two Containment Spray Pumps ON 3.2 Two Containment Spray Header inlet, Valves (FCV-0I&, FCV-07-1B) OPEN 3.3 Four NACH (Caustic) Admission Valves (FSE-07-1A, FSE-07-2A, FSE-07-13, FSE-07--23) OPEN 3.4 Verify Containment Spray Flow in FI-07-1A and FI-07-1B. 3.5 Verify NA0H (Caustic) Flow on Post Accident, Panel "A"
~
TFI-07-2, FR-07-2) i l i l! l W . "
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5 Pags 13 of 14 MERGENCT OPERATING PROCEDURE 0120041, REV 9 STEAM GENERATOR TUBE LEAK / FAILURE i TABLE 1 m 4.0 Recirculation Actuation Signal OFF 4.1 Two LPSI Pu=cs 4.2 Two Safety Injection Miniflow Recire. Valves (V-3659, SEUT V-3660) Two Containment Sumo Outlet Valves (MV-07-2A, MV-07-23) OPD 4.3 Two RL'r Outlet Valves (MV-07-1A, MV-07-13) SHUT
- 4.4 4.5 Verify HPSI flow to core continues af ter RAS on FI-3321, FI-3341, FI-3311. FI-3331.
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Pigs 14 of14' EMERGENCY OPERATING FROCEDURE 0120041 REV 9 STEAM GENERATOR TUBE LEAK / FAILURE TABLE I 5.0 Main Steam Isolation Signal m 5.1 Two Main Steam Isolation Valves (RCV-08-1A, HCV-08-1B) SHUT 5.2 Two Main Steam Isolation Bypass Valves (MV-08-1A, MV-08-1B) SHUT 5.3 Two Main Feedwater Pump Discharge Valves (MV-09-1, MV-09-2) SHUT
.. 5.4 Two Main Feedwater Block Valves (MV-09-7, MV-09-8) SHUT i
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. . Pao l of 20 FLOICDA PCWER & LIGHT CCMPATI ST. LUCIE UlTIT NO.1 EMERGENCY PROCEDURE 0120042 L. gryISICL13 -
1,0 Titlet USE 02 W l dis desument it not Imily lAformatfort with a controlled document. 3..o Aporovalt _
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7? - Revision 12 Rpri byFacilpyReviewGroup D Fc. /0 197 9 . Approved by (l/ A2m 2/ 7-?LHf'$anager /Ja c it 19 % / Revision 13 4tefiewed by Fa'cility Review Group h. 44 1990 Approved by @/>#/ h Plant Manger A L, . z. 9 19 r e --
.- - Revision 18 reviewed by FRG . Meo M w L. 1981.
Approved by A'2 /////L/./h Plant Manager - //cg. ~ / 2. ' - lo81. .I -- ^ ~
--.-.'. . . . . ...-...L..--..-.....___... ....w-3.0 Purcose and Discussion:
3.1 Purpose
This procedure provides instructions to be followed in the event that laalcage from the Reactor Coolant System is in excess of operable charging pump capacity.,
- 3. 2. A loss'of coolant accident is defined as any mechanie where the loss. of coolant from the Reactor Coolant System exceeds the capacity of the operable charging pumps. When conditions in checReactor Coolant System degrade to the point that a L4mied"3 Safety System Setting is approached the Reactor Protective System vill initiate a reactor trip, maled g the reactor suberitical. This will stop the production of power in the core. Cooling of the core however, =ust continue to remove the considerable decay heat that rammina. the Safety I::",eetE System automatically provides a flow of subcooled water to the core for decay heat removal. Failure to keep the core covered v411 result in overheating of the fuel, failure of the cladding,. and a release of gross amounts of fission products to the contai= ment at=osphere.
The spectrum of breaks which would cause a TCCA is from apprnrdmately a .2 inch diameter break up to a double-ended hoe leg _ rupture. For an example: Analysis show that the flow from an u= restricted .3 inch diameter break is approximately 180 gpm at 2250 psia. A =ajor concern for these smm!1 breaks is that the flow through the break =ay not be sufficient for decay heat removal. In those circumstances it is imoerative that a secondary heat sink be available. This in turn dictates the use of the Anvd 14ary Feedvater System as the main feed-vater system is disabled due to an SIAS. a
Ptg2 2 of 20 DfERGENCY PROCEDURE 0120042, REV. 18 LOSS OF REACTOR COOLANT 3.0 Purpose and Discussion (Cont'd) 3.2 (Cont'd) Operator actions should be directed toward ensuring proper un' I 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 for=ation, 4.0 Symotems/ 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 may cause indications which are contrary to true conditions. All available indications shculd be used to aid in diagnosing the event sinoe the accident may cause irregularities in a particular instrument reading. Critical parameters must be verified when one or more confirmatory indications are available. With the Subcooling Margin Monitor (SMM) operating normally, use the nomograph on'RTG3 104 in conjunction with the SMM 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 thermoccuples to determine the margin to saturation. Subcooling margin can also be determined by subtracting het 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 generator is receiving auxiliary feedvater. The diagnostic chart on Page 20 may be of some value in analyzing 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 Conta1==ent Isolation Actuation signal. e 4 h
Pago 3 of 20 l DERGUTCT PROCEDURE 0120042, REV. 18 LOSS OF REACTOR COOLANT i 4.0 Svmptoms/ Precautions: 4.4 Any one or more of the following indications or alarms may be present: ,
.mI 4.4.1 Decreasing pressurizer pressure.
4.4.2 Increasing cont =4= ant pressure and temperature. 4.4.3 Rising water level in the rer,ctor cavity sump. 4.4.4 High coutm4 =ent radiation. 4.4.5 Decreasing or increasing pressurizar level, 4.4.6 Quench tank high level. 4.4.7 Quench. tank high temperature. 4.4.8 Quench tank high pressure. 4.4.9 Tavg decreasing or at saturation temperature for RCS pressure. RE7 16 4.4.10. Safety or relief valve (s) opert alarm H-11. f CAUTION:. Some instruments (valve position, temperatures 7~ ~?rarlevaL-indication,-etevHspecified -- ~ for use in this procedura have not been de-
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- ign d h long ters posc"LOCreenditibifs
,. . . inside the.conta4=arte Therefore, the- f I
gustor-should-bersspecially'arerrtfrat tne potential exists for erroneous indication / l
---- after- >15- minutes have els.psed following a I LOCA event.
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. . Pcga 4 of 20 EMERGINCY PROCEDURE 0120042, REV. 18 ;
LOSS OF REACTOR C00IANT *
5.0 Instructions
5.1 Imediate Automatic Actions mml 5.1.1 Reactor trip / turbine trip 5.1.2 Safety injection actuation signal 5.1.3 Contaiment isolation actuation signal 5.1.4 Contaim ent spray actuation signal 3.2 Imediate Operator Action 5.2.1 Carry out immediate operator actions for reactor trip per OP 0030130. 5.2.2 Af ter 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 i operating reactor coolant pumps. 5.2.3 Ensure safety injection and contaiment isolation actuation signals have occured or initiate manually. Ensure HPSI flow to the, core when pressure decreases below the pump's-shut-off head (s1250 psia). 5.2.4 Establish and maintain steam generator levels at 65% with auxiliary feedwater system. CAUTION: Do not exceed 750F/hr cooldown rate. 5.2.5 If conditions permit, attempt to locate and isolate the source of the leak. Possible leak locations include, but are not limited to the PORV's, the letdown line, and sample lines. 5.3 Subsequent Actions
^ Observe all available indications to determine conditions within
~
i the RCS. Use'SMM display, RCS hot leg temperature, RCS cold leg tempera-ture, incore thermocouple temperature, and RCS pressure to determine if the RCS is subcooled or saturated. An increase in temperature above the saturation temperature for the existing pressure is an indication of voiding in the RCS. If this occurs the operator m2st ensure thac the RCP's are turned off, the SIS is providing makeup to the RCS, and that the steam generators are removir4 heat from 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.
. . Pga 5 of 20 EMERGENCY PROCEDURE 0120042, REV. 18 LOSS OF REACTOR COOLANT 5.0 Instructions (cont.) 5.3 (cont.) , 5.3.1 Refer to Table I to ensure the proper operation of engineered safety fescures as time and conditions permit. 5.3.2 Ensure that containment spray is actuated if containment pressure exceeds 10 psig, and check the following: 2 containment spray pumps ON 2 spray header inlet valves OPEN L 4 NaOH admissica valves OPEN NaOH flow indication in control s30 gpm roor. on post accident panel 5.3.3 When cour=4nment pressure decreases to less than 10 psig, stop 1A and 13 containment spray pumps, close FCV 07-1A and FCV 07-13, reset CSAS channels A and 3, and raturn containment spray pumps and FCV switches to the " auto" position. ; 5.3.4 Within one (1) hour, but without exception no later than one (1) hour stop RCS/3AMT boration via the charging pumps. 5.3.5 Continue to ensure proper operation of the safety injection system by checking flow rates and S.I.T. levels. After any SIAS, operate the SIS until RCS hot and cold leg temperatures are at least 500 F below saturation temperature for the RCS pressure and a pressurizer level
'I is indicated, unless the cause of the SIAS has been verified to be an inadvertent actuation. If 500F subcooling cannot be maintained after the system has been stopped, the high pressure injection system must be started.
CAUTION: .Mi n4 = = pressure - temperature operating restrictions take precedence over requirements for o1,. nation of the high pressure injection or charging system to achieve 50 subcooling dur+ng operation of the shutdown cooling system. ,
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Pago 6 cf 20 l EMERGENCY PROCEDURE 0120042, REV. 18-LOSS OF REACTOR COOLANT 5.0 Instructions (cont.) 5.3 (cont.) I mmu 5.3.6 Imnlement the Emergency Plan as necessary in accordance with EP 3100021E, " Duties of Emergency Coordinator". 5.3.7 Immediately prior to the receipt of the Recirculation Actuation Signal restore power to V3659 and 73660. 5.3.8 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. ,. 5.3.8A If steam dump to condenser is available, close the Atmospheric Steam Dumps, and begin dumping steam to condenser. 5.3.83 If. offsite power is lost, steam dump to atmosphere must be used for cooldown. 5.3.8C Continue auxiliary feedwater flow to the steam generators during cooldown. . 5.3.8D Do not exceed the 75 F/ hour cooldown rate. 5.3.8E If the RCS pressure remains greater (after stabilization) than the shutoff head of the LPSI pumps, stop both pumps. CAUTION: Feedwater is normally provided to both steam generators. Isolation of a single steam generator per OP 0120041 (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 vill also reduce the amount of radioactivity released. For small breaks in the RCS where steam generators are important for heat removal one steam generator must be used for this purpose even if primary to secondary leaks are detected. P .
Pago 7 of 50 1 l e e EMERGENCY PROCEDURE 0120042, REV. 18 LCSS OP REACTOR COOLANT . 5.0 Instructions'(cent.) 5.3 (cont.) , 5.3.9 When the RYf level reaches 6 f t., ensure that at least one (1) containment spray pump is runnino. Open the necessary valve (s) as indicated by pump conditions to provide cooled water from the shutdown cooling heat exchanger (s) to the HPSI pump (s) during recirculation. MV-3662 S.D.C. to 13 and 1C HPSI pumps MV-3663 S.D.C. to 1A HPSI pump This is the preferred line-up for long term cooling. 5.3.10 Ensure that Recirculation Actuation (RAS) occurs when the RRr level decreases to 3 ft. indicated - (4 ft. from the bottom of the tank) and check the following: 2 LPSI pumps TRIP 2 Miniflow recire valves SHUT 2 Containment sump outlet valves OPEN CAUTION: . Ensure HPSI flow to the core continues after RAS. Do not allow the HPSI pumps
- to operate " dead-headed". HPSI shutoff head (no flow) 1250 psig.
5.3.11 Ensure V3659 and V3660 are closed, then de-energize the valves using key operated switches on RIG 3106. 5.3.12 If all HPSI pumps and charging pumps are operating and the HPSI pumps are delivering less than 75 gr per pump, turn off the charging pumps one at a time and then HPSI pumps one at a time until only one HPSI pump remains operating. This will ensure that minimum flow require-ments will be met by the flow through the pump to the RCS for the smallest break size that results in a SIAS. 5.3.13 Monitor R.A.B. radiation levels and sump levels after 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. 5.3.14 As soon as possible, but without exception, within ten (10) hours, hot leg injection shall be initiated to the core in conjunction with the existing cold leg injection being sustained by the HPSI pumps per Appendix A.
Pcan 8 of 20 7 EMERGENCY PROCEDURE 0120042, RE7. 13 LOSS OF REACTOR COOLANT 5.0 Instructions (cont.) 5.3 (cont.) n== 3.3.15 If the pressure and inventory control with the SIS cannot be established after eight hours and RCS pressure is less than 300 peig, continue the hot and cold leg injection. NOTE: It may be necessary te fill the pressurizer solid to regain pressure control and to achieve 5007 subcooling. If this is the case the HPSI discharge valves will have to be carefully throttled during the cooldown to reduce system pressure. 5.3.16 If pressure and inventory control with the SIS are established after eight hours and RCS pressure is greater than 30^ psig, conduct cae of the following activities. The activities are listed 'n order of decreasing preference. 5.3.16A 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 subcooling and reduce RCS pressure to <268 psia for shutdown cooling by reducing the flow delivered by the high pre'ssure injection and charging pumps.- While reducing pressure and after shutdown cooling is initiated, maintain RCS pressure with the charging pumps and/or the BPSI pumps to continue to mahtain at least 500 subcooling, or CAITfION: -If there is a high radioactivity level in the reactor coolant system, circulation of this fluid in SDC may result in high area radio-activity readings in the amH14ary building. The activity level of the RCS should be determined prior to initiating SDC flow. 5.3.163 Continue to remove decay heat using auxiliary feedwater and steam dumps if adequate condensate is available and (A) cannot be implemented, or 5.3.16C 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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Pago 9 of 20 EMERGENCY PROCEDURE 0120042, RE7. 18 LOSS OF REACTOR COCLuiT 5.0 Instructions (cont.) 5.3 (cont.) , 5.3.17 Place both Hydrogen Recembiners in serrice per Appendix 3. 5.3.18 If contmi-ent hydrogen concentration cannot be :naintained
.below 3.5%.as indicated on the cont =4==nt hydregen sample system by tao (2) hydrogen reccabiners, then place the contaizunent hydrogen purge system into operation per Appendix 3.
6.0
References:
6.1 FSAR Chapters 4, 6, Appendix 6C, 7, 8, 9, 15. 7.0 Records Required: 7.1 Normal Log Entries dilha e
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Pagn 10 of 20 EMERGENCY PROCEDURE 0120042, REV 18 LOSS OF REACTOR COOLANT APPENDLX A HOT LEG INJECTION
- 1. Prerequisite , ,.
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 at manual operating stations.
b) Ensure a min 4= = flow path to avoid dead-heading the HPSI, containment spray, and LPSI pumps. c) Containment spray pump flow shall not exceed 1500 GPM. d) LPSI pump flow shall not exceed 3500 GPM.
- 3. Primary method of hot leg injection using LPSI pumps via hot leg suction line.
a) Ensure RCS/ containment AP less than 150 psid. b) Select operable LPSI pump and use applicable valve lineup A LPSI operable 3 LPSI operable
. c) Shut V3207 and 3432 3206 and 3444 d) Open V3400 V3484 r e) Shut HCV 3615, 3625 HCV 3615, 3625 l 3635, 3645 3635, 3645 f) Open V3651 and 3652 V3481 and 3480 g) Start LPSI 1A LPSI 13 h) Monitor flow FT3306 & 3332 FT3306 & 3322 i) Maintain minimum flow of 250 gpm NOTE: If power is lost to one set of SDC hot leg suction valves, notify electrical department to install jumpers.
a
Pago 11 of 20 7 EMERGENCY PROCEDURE 0120042, REV 18. ; LOSS OF REACTOR COOLANT APPENDIX A (cont) 5
- 4. Alternate Method: Hot leg injection using HPSI pumps via pressurizer auxiliary spray.
a) Stop charging pumps and shut V-2336, 2337, 2339. b) Open V-2340 CVCS to HPSI Auxiliary header I connect. c) Shut ISE-02-01 and I-SE-02-02, 131 and 1A2 loop chargine isolation valves. d) Shut PCV-1100E and F, pressurizer spray valves. i ) e) Unlock and open I-SE-02-03 and I-SE-02-04 auxiliary spray valves. f) One HPSI pump (B or C) must remain available to recirculate water from containment sump to HPSI header. 4
- 1) To use A HPSI pump for hot leg in-jection, shut valves HCV 3617, 3627, -
3637 and 3647 and maintain minimum l . flow of 200 gpm through auxiliary i spray by monitoring charging flow indicator FT 2212.
- 2) To use C HPSI pump for hot let in-
- jection (A pump not available), unlock and shut MV3653 and open MV3655. Shut l HCV 3617, 3627, 3637 and 3647 and maintain flow of 200 gpm through auxiliary spray by monitoring chartrin; i flow indicator FT 2212.
l S. Secondary Alternate Method: Hot leg injection l using CS pump via hot leg scetion line l l a) Condition, RCS/ containment AP <150 paid. b) With 1 B containe.ent spray pump running; I open or check to be open V-3457. c) Place HIC-3306 Keysvitch in the Auto i position. t
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Pego 12 of 20 ! EMERGENCI PROCEDURE 0120042, RE7 18 LCSS OF REACTOR COCIANT APPENDII.A (cont) i
. 5. (cont) d) With the keysvitch a Auto, take ==an=1 control of HIC-3306, and close FC7-3306.
NOTE: The 13 contairnment spray pump is still supplying cooled water to the 3 HPSI pump, and is now aligned to the LPSI Header, except for the opening of HCV-3657. e) Opert 7-3400 f) Open V-3651 and V-3652, ('3' LPSI pump suction valves from 'B' Hot Leg). i g) Close HC7-3615, HC7-3625, HC7-3635, HC7-3645, h) Slowly open HC7-3657, until flow shows on PT-3306. Adjust HC7-3657 to maintain a min 4== of 250 gpm flow on FT-3306 a6d PT-3332 (Loop 131 LPSI flow transmitter) .
- 1) Adjust HC7-3616, HC7-3626, HC7-3636 and HC7-3646 until their respective flow transmitters read <150 gym.
j) Check. the running amps on the 'B' HPSI and 'B' courainment spray pump to be below red line. k) HC7-3657 can now be opened more to increase flow to the '3' Hot Leg. CAUTION: Do not exceed 1500 gym total flow on the '3' courninment
, spray pump.
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Pcg3 13 of ' DfERGENCT PROCEDURE 0120042, RE7 18 LCSS OF REACTOR COOLANT APPENDII B PLACING H, RECCMBINER AND CCNTAISMENT~E,PLM IN SER7 ICE ,
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'.L- Place rec:xabiners in service as follows:
lA 13
- 1. Close breakers #41251 in 4807 MCC 1A5 (lA) and #42103 in 4807 MCC 136 (13) .
- 2. See 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 411"m hated.
4 Set the Power Out Switch on the control . p-1 to the "CN" position. The red light on the switch will 4114 af n=ce
- 5. Gradually tdra the Power Adjust potent-
. iometer to 70 KW'as indicated on the Power Out Wattmeter. ,
CAUTION: Ihere is a lag in the meter reading, so turn the potent-iometer know slowly. Do not exceed 75 G.
- 6. Periodically check the temperature of the three thermocouples using the temperature channel selector switch.
And, when the temperature reaches 1250 7, adjust the power adjust potentiometer to maintain temperature between 1250 P and.1400 P. CAUTION: Do not let the temperature exceed 1400 7 as indicated by the thermocouple readout. O P 8
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,- Pags 14 of 20 EMERGENC[ PROCEDURE 0120042, REV 18 LOSS OF REACTOR COOLANT APPENDIX B (cont)
- 2. Place containment H2 purge in service as follows:
- 1. Verify closed V-25-15 and 16 filter bypass valves.
- 2. Unlock and open V-25-14 and 13 suction isolation 0alves.
- 3. Open FCV-25-9 hydrogen, purge suction flow control valve. .j , . .
4 Opes.r-25-17 hydrogen purge
- discharge to vent stack.
,r
- 5. Star HVE 7A or 7B. ,
- 6. Unlock and open V-25-11'an F v;25-12 makeup air for hydrogen purge. ;
- 7. Modulate FCV-25-10 open as needrei.co maintain char-coal absorber temperature below' alarm point.
CAUTION:' Ensure that either EVE 10A or HVE 10B>
.is running. ,
- 8. Periodically. check the stack 4 radiation monitoring system for increasing gaseous and particulate levels.
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Paga 15 of 20 EMERGENCY PROCEDURE 0120042, REV 18
. LOSS OF REACTOR COOLANT TABLE 1
, 2.0 Containment Isolation Actuation Siknal 2.1 Two Shield Building Vent Fans (HVE-6A, HVE-6B) 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 Samnle Isolation Valves (V-5200, V-5203) SHUT 2.5 Four Pressuriner Sample Valves (V-5201, V-5202,. V-5204, V-5205) SMUT 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, 25-4, 25-2) SHUT 2.8 Two Containment Purge Exhaust Fans (HVE-8A, EVE-8B) 0FF 2.9 One Nitrogen to Containment Supp1v 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-07-113) SHUT 2.12 Four Steam Geterator Slowdown Isolation Valves (FCV-23-3,
. FCV-23-5, FCV-23-4, FCV-23-6) SHUT 2.13 Two Steam Generator Blowdown Sample Isolation Valves (FCV'-23-7 and 9) SHUT 2.14 Two Reactor Drain Tank Discharge , Isolation Valves (V-6301, 7-6302) SHUT 2.15 Four Control Roon 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-25-25) cmtr 2.17 Two Control Room Toilet Air Exhaust Valves (FCV-25-18, FCV-25-19) SHUT
**c. 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 Water Isol Valve (MV-15-1) SHUT 2.20 Two RCP Controlled Bleedoff Isol Valves (V-2305 and ISE-01-1) SHUT
- NOTE: Only one shield building vent fan is required, the other 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 RTG3, 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)
- c. FCV26-1, FCV26-3, FCV26-5: Close valves using RTGF switch, close manual valves at Eonitor cabinet, ensure no f1w indication on =enitor.' '
,* PKg216 of 20 EMERGENCY PROCEDURE 0120042, REV 14 P
. LOSS OF REACTOR COOLANT J
'w TABLE 1
. s
.s '3.0 Containment Soray Actuation Signal l
~ : ,
'3.1 Two Containment Spray Puw.s ON 3.2 3eo Containment Spray Header Inlet Valves (FCV-0J-1A, I .
FCV-07-13) OPEN l s 3.3 Four NA0H (Caustic) Admission Valves (FSE-07-1A, FSE-07-2A, FSE-07-1B, FSE-07-23) OPEN l 3.4 Verify Containment Spray Flow in FI-07-1A and FI-07-13. 3.51 Verify NA0H (Caustic) Flow on Post Accident Panel "A"
'(FI-07-2, FR-07-2) s a, l . .
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- Pags17 of 20 EMERGENCY PROCEDURE 0120042, REV '18
. LOSS OF REACTOR C00LM '
mams TABLE 1 4.0 ' Recirculation Actuation Signal OFF 4.1 Two LPSI Pu=os 4.2 Two Saf ety Injection Miniflow Recire. Valves (V-3659, . SHUT V-3660) OPEN 4.3 Two Containment Sumo outlet Valves (MV-07-2A. MV-07-23) SHUT 4.4 Two RWf Outlet Valves (MV-07-1A. MV-07-1B) 4.5 V.erify HPSI flow to core continues af ter RAS on FI-3321, FI-3341, FI-3311, FI-3331. e-e 4 4 i I e e A 4
. i, . Paga 18 of 20 EMERGENCY PROCEDURE 0120042, REV 18 LOSS OF REACTOR C00LAh"f
- TABLE I S.0 Main Steam Isolation Signal 5.1 Two Main Steam Isolation Valves (HCV-08-1A, HCV-08-13) SHUT m
5.2 Two Main Steam Isolation Bypass Valves (MV-08-1A, . MV-08-1B) SHUT 5.3 Two Main Feedwater Pump Discharge Valves (MV-09-1, SHUT MV-09-2)
- 5.4 Two Main Feedwater Block Valves (MV-09-7, MV-09-8) SEUT 9
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Pago 19 of 20 M "EINCY PROCEDURE 0120042, REV 18 LOSS OF REACTOR COOLANT t TABLE I 1.0 Safetv Injection Actuation Signal Emu - 1.1 Two HPSI Pumps on 1.2 Two LPSI Pumps CN 1.3 Four AUX HPSI Discharge Valres (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 _.
, l..a Che d. proper operation of the Safety Injection System by the following means.
1.5.1 Check HPSI flow rates on: 7I-3311, 3321, 3331, 3341.
- 1. 5. 2. Check LPSI flev races on': FI-3312, 3322, 3332, 3342. .
1.5.3 Check decreasing Safety Injection Tank Levels on: LIA-3311, 3321, 3331, 3341. 1.I' Two CCW Pumos ON
- 1. 3 Two CG Valves frem SDC EX's (HCV 14-3A,
, HCV 14-33). OPEN
~ ~
1.% Four ConMment Cooling Fans ON 1.;J.0 Four CCW "N-Header" Isolation, Valves (HCV-14-dA, ~ 14-9, 14-83. 14-10).- SHUT ~~
~
1.Cr Four SIT Check Valve Leakofi Valves (V-3618, . 3628, 3638, 3648). SHUT
~
1 12'; Two R. A.3. Main Sucolv Fans (HVS-4A, 43) ON
~
- 1. 133 Two ECCS Area. Exhaust Fans (HVE 9A.'9B) ON*
g 1.14/ Eight Aux Bldg Dampers (D-5A, 6A, 9A, 12A, 53, 63, . 9B, 123) SHUT 1.15 W Four Aux 31dg/ECCS Pump Hoon Dampers (D-13,14, 15, 16) OPE.T _ l.16. Four Reactor Coolant Pump CCW 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 1.13' Two Feedwater Block Valves (MV-09-7; MV-09-8) SHUT L L7 Two Charging Pumps ON
~'
l 3f? Two 3oric Acid Makaue Pumps ON 1.22 Two Letdown Isolation Valves (V-2515: V-2516) SHUT l.22 VCT Cutlen Valve (V-2501) SHUT 1.23 Two Gravity Feed Valves (V-2508: 7-2509) OPEN
~
~}'~~ 1.7.A Emergency Bora:.e Valve 01V-251<4 )
1.25 Two Bam Pume Recire Valves (V-2510, V-2511) OPEN SHUT
~ ~ ~
1.29 Blender Outlet Valve to VCT (V-2512) SHUT
' ~ ~ ~ ~~ ~
1.27 Load Control Valve (MV-2525) SHUT _, [ 1. "'T Borie Acid' Header Discharge Valve (MV-2161) 1
'_4 Two R:c Cavity Sump- Isol Valves (LCV 07-LIA;.
SHUT _ ECT 07-113)- SHUT' __ I.20- Two Intake Cooling Water Pumes CN 1.3:D Two ICW to TCW Ex Isol Valves (MV-21-2: MV-21-3) SHUT _ l.32. ' A' ICW Lube WIR Supply to CW Pu=ps (?L7-21-3A) ,. _ _. Sm _ l 1.3'h '3' ICW Lube 7rR Sunelv to CN Pumos (FLV-21-1Bi s* HUT '
*NO 2: Only one ICCSL area exhaust fan is required, the other fan should be shutdown and_ kept in standby. ,
. 3
/R18
Paga 20 cf 20 EMERSENCY PROCEDURE 0120042, REV 18
- LOSS OF REACTOR COOLANT -
. DIAGN0STIC CHART 41 __
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