ML20028A198
| ML20028A198 | |
| Person / Time | |
|---|---|
| Site: | Saint Lucie  |
| Issue date: | 10/27/1982 |
| From: | FLORIDA POWER & LIGHT CO. |
| To: | |
| Shared Package | |
| ML17213A710 | List: |
| References | |
| PROC-821027-02, NUDOCS 8211160566 | |
| Download: ML20028A198 (203) | |
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2 Ptg"2 1 of 6 FLORIDA POWER & LIGHT COMPANY 0% ]' ST. LUCIE UNIT #1 - EMERGENCY OPERATING PROCEDURE NO. 070nnem 1 b Ecnp gi} % .)..,),,5J= REVISION 12 TUd - I '*"Whd. UCI "' ent.
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1.0 Title
verify in{ormation with a contro e Loss of Feedwater or Steam Generator Level
2.0 Aoproval
Reviewed by the Facility ?eview Group 8'? ^} 4 /1 19 7 5~ Approved by 0 . N M f, /;;, r Plant Minager J;;) / /1 19 7 (~ Revision 12 Reviewed Yacility Review Group' $G # P 3 /19 F2. . Approved by kf # ph Plant Manager de / . 2- r- 19 h 3.0 Purpose and ois , :en: 3.1 This pr .< provides instructions to be followed in the event of losc n: L .dwater flow and/or loss of steam generator level. 3.2 Lo.% .:enerator level results in a reduction in capability of he ec. . .y system to re=ove the heat generated in the reactor core. Lot: steam generator level results from the inability to suppi, fee 6 *r in an amount equal to the existing steam demand. Excessive rce a demand, i.e., above feedwater system capability is considered in Etirgency 0.P. 0810040, Main Steam Line Break. 3.3 The loss of all taetra s cr to the steam generator and the subsequent heatup of the i' wetor Co nant System will result in saturation conditions at he5 tempm sture and pressure in the Resctor Coolant System. This would cause. s less of reactc,r coolant mass through the PORV's and code t.afeti's nd void formations throughout the system. A maximum ettert taould be directed toward the initiation of feedwater flow to the steam generators. Without feedwater, the steam generators could boil dry within approximately 13 minutes. 3.4 The inability to supply feedwater in the required quantity could result from one or a combination of the following: 3.4.1 Pipebreakinthecondensate/feedwatersystem. 3.4.2 Flowpath blockage due to valve closure or strainer stoppage. 3.4.3 Loss of pumping capacity due to pump trip, loss of AC power, or pump cavitation. 3.4.4 Los's of C' Auxiliary Feedwater pump remote operating capability. 3.5 The following protective functions are provided to prevent loss of heat sink..
Pags 2 of 6 EMERGENCY OPERATING PAOCEDURE NO. 0700040, REV 12 LOSS OF FEEDWATER GE STEAM GENERATOR LEVEL 3.0 Purpose (cont) 3.5 (cont) 3.5.1 Reactor trip: *== 3.5.1.1 Steam generator low-low level at 39%. 3.5.2 Turbine Runback: 3.5.2.1 Loss of both heater drain pumps if turbine power is 3;92%. 3.5.2.2 Loss of feedwater pump if turbine power is 2;60%. 3.5.3 Aux Feed Pump Auto-start at 34% steam generator level. 3.6 The action taken for loss of steam generator level is basically the same regardless of cause. That is, to trip the reactor, there-by removing the heat source, and restoring steam generator level with the auxiliary feedwater pump.s. This approach is due to the self-sufficient nature of the auxiliary feed system. It, in no way, depends on the normal feedwater sy' stem. The auxiliary feed system has the capability to bring the unit to hot shutdown and ramain there for a period in excess of 20 hours, regardless of any single failure in the normal feed system. Three auxiliary feed pumps are available. Two motor driven pumps, either of which can supply either steam generator and one steam driven pump which can supply either steam generator. The auxiliary feedwater system ties into each steam generator feed line downstream of the steam generator feed inlet check valve. Capability exists to feed either steam generator by any auxiliary feed pump. A break in the feed line between the feed line check valve and the steam generator would result in the loss of that steam generator as a heat sink. Corrective action would be to isolate feed flow to that steam generator and continue maintaining level in the unaffected steam generator. Residual heat can be adequately dissipated in this manner. The leak must be isolated in any incident involving a break even though the break does not i==ediately affect the auxiliary feedwater system. The isolation of a leak is necessary to conserve the water availacle in the condensate storage tank. The leak is isolated by stopping the steam generator feed pumps and condensate pumps. A leak dowtstreas of a steam generator feed line check valve would also require stopping auxiliary feed flow to that steam generator.
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1 Pags 3 of 6 EMERGENCY OPERATING PROCEDURE NO. 0700040, REV 12 LOSS OF FEEDWATER OR STEAM GENERATOR LEVEL 3.0 Purpose (cont) 3.7 The Aux feed pumps will auto start approximately 3 minutes L,,j following either S/G level dropping below 34% (2/4 logic). Flow is automatically initiated to both steam generators and cannot be terminated for 30 seconds. Bypass switches are
, provided on RTGB 102 which will prevent pump starts and valve stroke and would be utilized' if normal feedwater flow remains or becomes available and is desired.
4.0 Symptoms
4.1 Low-low steam generator level. 4.2 Low feed pump suction or discharge pressure. 4.3 Stean generator feed pump trip. 4.4 Condensate pump trip. 4.5 Heater drain pump crip. 4.6 Increasing Tavg. l l l l l 4 l A
Page 4 of 6 EMERGENCY ( ?ERATING PROCEDURE NO. 0700040, REV. 12 . LOSS OF 2!!LWATER OR STEAM GENERATOR LEVEL {
" '?.' 1 I
5.0 Instructions : l 5.1 Immediate Automati Actions (some or all of the following may f occur). g '] L 5.1.1 Reactor trip. 5.1.2 Turbine trip. 5.1.3 Transfer from Auxiliary transformer to startup transformer of auxiliary power. 5.1.4- Generator OCB's open. 5.1.5 Steam dump to condenser actuation. R12 5.1.6 Steam generator relief activation. 5.1.7 With a turbine trip, the main feed reg valves will close and the 15% bypass valves will open to = 5% flow position. 5.1.8 Aux Feed Pump auto start sequence at 34% indicated level. 5.2 Inmediate Operator Action. , 5.2.1 With reactor trip. 5.2.1.1 Carry out immediate operator actions for reactor trip per OP 0030130. 5.2.1.2 If one feed pump is lost, feed steam generators with remaining feedwater train. 5.2.1.3 If both feed pumps are lost, immediately initiate auxiliary feed to the steam generators. Stop
. both heater drain pumps and leave one condensate
! pump running to cool down the secondary systems. When establishing auxiliary feed flow to the steam generators, use steam generator levels as.well as , header flow rates to ensure each steam generator i is receiving auxiliary feedwater. 5.2.1.4 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.
I
- 4
Prgs 5 of 6 EMERGENCY OPERATING PROCEDURE No. 0700040, REV._12 / LOSS OF FEEDWATER OR STEAM GENERATOR LEVEL W
5.0 Instructions
(Cont'd) 1 5.2 Immediate Operator Action (Cont'd)
- 2) Limit feedwater flow race to 150 gpm per b steam generator until condinuous feedwater flow to the SG has been maintained for five minutes.
5.2.1.5 If a major rupture occurs in the condensate-feedwater system immediately trip both condensate pumps, both heater drain pumps, and both feed pumps to minimize damage to secondary components. Immediately initiate auxiliary feed flow to the steam generators. (Isolate rupture as quickly as possible). 5.2.1.6 Refer to applicable Subsequent Actions. 5.2.2 Immediate Operator Action (Reactor does not trip). 5.2.2.1 If loss of a feed pump results in a turbine runback, check that: 5.2.2.1.1 The load reduction is consistent with the capacity of the operating feed pump. 5.2.2.1.2 Steam generator levels can be
. maintained using one feed pump.
5.2.2.1.3 Reactor powe.r is matched with turbine power (Tavg = Tref) . 5.2.2.2 Refer to applicable Subsequent Actions. 5.3 Subsequent Actions 5.3.1 Subsequent Actions (with reactor trip) 5.3.1.1 Implement the Emergency Plan as necessary in accordance with EPIP 3100021E, " Duties of the Emergency Coordinator". 5.3.1.2 Monitor auxiliary feedwater flow to each steam generator. If either stean generator cannot be maintained above 38% with auxiliary feedflow and its pressure is relatively low compared to the other steam generator, secure auxiliary feed flow to t'his steam generator. 5.3.1.3 If all main feedwater flew is lost, coordinate the dumping of steam and the addition of auxiliary Ril
Pags 6 of 6 EMERGENCY OPERATING PROCEDURE No. 0700040, REV.12 LOSS OF FEEDWATER OR STEAM GENERATOR LEVEL ,j
~
1 / h' 5.0 Instructions (Cont'd) ' '2< 5.3 Subsequent Actions (Cont'd) 5.3.1 Subsequent Actions (with reactor trip) - Cont'd 5.3.1.3 (Cont'd) feedwater to restore steam generator level to approximately 65% and Tavg to approximately 532 F. NOTE: Use caution to avoid excessive cooldown on addition of auxiliary feedwater. 5.3.2 Subsequent Actions (without reactor trip) 5.3.2.1 After insuring the plant is in a stable condition, determine and correct the cause of the loss of feedwater. 6.0
References:
6.1 FSAR, Section 15.2.8, and Section 10.5.3. . 6.2 Combustion Engineering Emergency Procedure, F-EP-9. 7.0 Records, h ports and Notifications: 7.1 Log Book entries. O
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FLORIDA POWER & LIGHT COMPANY ) ! ST. LUCIE UNIT NO.1 # d EMERGENCY OPERATING PROCEDURE NUMBER 1-0030143 ,N . REVISION 1 g,, . w
1.0 TITLE
TOTAL LOSS.0F AC POWER
2.0 APPROVAL
' Reviewed by Facility Review Group August 4 1982 Approved by C. M. Wethy Plant Manager August 4 19 Revision 1 Reviewed by FRG (9 -c D D Ic 1951 Approved by )/[/bcti os 'blantManager C T f .d [ 19 I )._.-
u' ' 3.0 PURPOSE AND DISCUSSION: 3.1 See Appendix A.
4.0 SYMPTOMS
4.1 Loss of power to 1Al,1B1 6.9KV Bus . 4.2 Loss of power to lA2, lA3,1B2, IB3 and 1AB 4.16KV Bus.
5.0 INSTRUCTIONS
5.1 Automatic Actions 5.1.1 Reactor Trip. 5.1.2 Turbine Trip / Generator Lockout. 5.1.3 Auxiliary Feedwater Auto Actuation. 5.1.4 PORV's Operate.
~
F0l1 l0FCDU!1 TION ONLY This document is not controlled. Before uw, verify information with a controlled document. t *
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Pegs 2 of 9 ST. LUCIE UNIT NO.1 . EMERGENCY OPERATING PROCEDURE NUMBER l-0030143, REVISION 1 ,,g TOTAL LOSS OF AC POWER y - 0"9 i
.1 d
5.0 INSTRUCTIONS
( Cont .) h [- 5.2 Immediate Operator Actions d?
; j
)
5.2.1 Insure all CEA's on bottom, and reactor trip breakers open. -- 5.2.2 Insure Auxiliary Feedwater Pump 1C is restoring Steam Generator level. If S/G level has dropped to <42%, then take control of Aux Feed and reduce to less than 150 GPM. /R1 5.2.3 Close both of the main steam isolation valves HCV-08-1A and HCV-08-1B . /R1 5.2.4 Close both letdown isolation valves V-2515 and V-2516. /R1 l l t e e O
h Ptgs 3 of 9 ST. LUCIE UNIT NO. 1 . EMERGENCY OPERATING PROCEDURE NUMBER 1-0030143, REVISION 1 TOTAL LOSS OF AC POWER I
5.0 INSTRUCTIONS
(Cont .) I 5.3 Subsequent Actions , 5.3.1 Insure generator OCB's and field breaker open. 1 5.3.2 Open 30102 (S.U. Trans former to 1A1 6.9KV bus) . Open 30202 (S.U. Transformer to 1B1 6.9KV bus) . Open 20102 (S.U. Transformer to 1A2 4.16KV bus) . Open 20302 (S.U. Transformer to 132 4.16KV bus). 5.3.3 Insure D/G breakers open (1A-20211 and IB-20'al). 5.3.4 Insure 1AB 4.16KV bus feeders are open:
- 20208, 20505 (IA3 4.16KV to 1AB 4.16KV bus).
l 20409, 20504 (133 4.16KV to IAB 4.16KV bus). 5.3.5 Open 40103 (IA2 4.16KV feed to 1A1 L.C.-Hi side) . Open 20110 (IA2 4.16KV feed to 1A1 L.C.-Lo side) . Open 40203 (IA3 4.16KV feed to 1A2 L.C.-Hi side) . Open 20210 (1A3 4.16KV feed to 1A2 L.C.-Lo side) . 5.3.6 Open 40403 (132 4.16KV feed to 181 L.C.-Hi side) . Open 20310 (1B2 4.16KV feed to IB1 L.C.-Lo side) . Open 40503. (183 4.16KV feed to 182 L.C.-Hi side) . - Open 20402 (133 4.16KV feed to 152 L.C.-Lo side) . 5.3.7 Insure 1AB 480V Load Center Feeders are open: 40204, 40702 (IA2 480V L.C. to 1AB). 40706, 40504 (1B2 480V L.C. to 1AB) . 5.3.8 Insure the main steam isolation bypass valves both indicate closed or dispatch an operator to locally take control and close the valves. /R1 NOTE: The handwheels on these valves turn counterclockwise direction to close, opposite of most valve handwheels
- in the plant. /R1 5.3.9 Open 1A and 13 Atmospheric Dump Valves to reduce. Steam l Generator pressure below safety lift pressure.
- 1. If instrument air pressure has decayed, local operation is necessary. Additional instrument air control capacity might be gained by opening cross-connect from service air system. /R1
- 2. Maintain communication with local operator.
J
Pzga 4 of 9 ST. LUCIE UNIT NO.1 . ""i EMERGENCY OPERATING PROCEDURE NUMBER 1-0030143, REVISION 1 ;f 0 TOTAL LOSS OF AC POWER ha f f 4 a f I
5.0 INSTRUCTIONS
(Cont.) g >j 5.3 (Cont .) k! 5.3.10 Close FCV 23-3, 4, 5 and 6 (1A and 13 S/G Blowdown i! Isola tions) . 5.3.11 Close FCV-23-7 and FCV-23-9 (1A and 1B S/G Blowdown Sample Isolations) . 5.3.12 Close A0V-5200, 5201, 5202, 5203, 5204 and 5205 (RCS Sample Isolations) . 5.3.13 Implement the Emergency Plan as necessary in accordance with EP 3100021E, " Duties of the Emergency Coordinator." 5.3.14 Minimize atmospheric steam dump use thereby insuring minimum RCS heat loss; however,
- 1. Maintain S/G pressure less than 5/G safety setpoint.
- 2. With decreasing RCS pressure, maintain hot leg temperature (Th) at least 200F below the saturation temperature corresponding to the RCS pressure.
5.3.15 Verify by the following indications that natural circulation flow has been established within approximately 15 minutes af ter RCP's were stopped.
- 1. Loop Delta T less than normal full power Delta T
(<460F).
- 2. Cold leg (Tc) constant or , decreasing.
- 3. Hot leg (Th) stable (i.e., not steadily increasing).
5.3.16 If RCS pressure decreases to 1700 psia, verify receipt of block permissive annunciator R-6 and block SIAS. 5.3.17 Notify system dispatcher of plant conditions and request most urgent priority in restoring off-site power. 5.3.18 If IC Auxiliary Feedwater Pump is stopped or flow is lost, and Steam Generator level is less than 42%, then:
- 1. Reinitiate auxiliary feed flow as soon as possible; however, do not exceed a flow race of 150 GPM per affected Steam Generator.
- 2. Limit feed flow rate to 150 GPM per affected Steam Generator until continuous feed flow to the af fected Steam Generator has been maintained for five minutes.
Pago 5 of 9 ST. LUCIE UNIT NO.1 , - i EMERGENCY OPERATING PROCEDURE NUMBER 1-0030143, REVISION 1 / j TOTAL LOSS OF AC POWER j {1 b $
5.0 INSTRUCTIONS
( Cont . ) i; { 3 3 5.3 (Co nt.) g j 5.3.19 Use all available resources to restore one emergency diesel -- generator to operable status.
- 1. (Insert techniques later) 5.3.20 The following restoration sequence assumes "A" train power supply is restored first.
- 1. Scrip all vital and non-vital load center breakers in preparation for a systematic power restoration.
- 2. Energize 1A3 4.16KV bus by either:
- a. Starting 1A D/G and closing D/G breaker. Adjust and maintain voltage and frequency at 4.16KV/60 RERTZ.
or
- b. Close 20102 (S.U. Transformer to 1A2 4.16KV bus) .
Close 20109 (IA2 4.16KV to 1A3 4.16KV bus). Insert sync plug and close 20209 (1A2 4.16KV to 1A3 4.16KV bus).
- 3. Energize 1A2 480V Load Center as follows:
- a. Close 40203 (1A3 4.16KV feed to 1A2 L.C.-H1 side) .
- b. Close 20210 (IA3 4.16KV feed to 1A2 L.C.-Lo side) .
- 4. Energize 1A3 480V Load Center by closing 40204 and 40702 (IA2 480V L.C. feed to IAB L.C.) .
- 5. Energize 1A5, lA6,1A7 and 1A8 480V MCC's as follows:
- a. Close 40214 (1A2 480V L.C. feed to 1A5 MCC).
- b. Close 40218 (1A2 480V L.C. feed to 1A6 MCC) .
- c. Close 40219 (IA2 480V L.C. feed to 1A7 MCC) .
- d. Close 40215 (1A2 480V L.C. feed to 1A8 MCC) .
- e. Open 41270 (IAS MCC supply to la containment instrunent air compressor) . /R1
Ptgs 6 of 9 ST. LUCIE UNIT N0; 1 EMERGENCY OPERATING PROCEDURE NUMBER l-0030143, REVISION 1 ,/g ;; TOTAL LOSS OF AC POWER i !
"3 I
5.0 INSTRUCTIONS
( Cont .) i j: g 3 d 5.3 ( Cont.) M i-5 3 E 5.3.20 (Cont.) ====
- 6. Energize non-essential sections of 1A5, lA6 and 1A8 MCC's as follows:
- a. Close 41230 (MCC LAS non-essential breaker) .
- b. Close 41325 (MCC 1A6 non-essential breaker). .
- c. Close 41513 (MCC 1A8 non-essential breaker) .
- 7. Insure 1A battery charger is "0N LINE" supplying the 1A DC bus by observing 1A DC bus voltage on RTGB 101 to be greater than 120V DC.
- 8. Align and start emergency cooling water to the instrument air compressor. Start the 1A instrument air compressor and observe restoration of instrument air pressure.
- 9. Start the LA charging pump to reestablish pressurizer level. When the CCW system has been restored per step 15, then lA KPSI pump can also be started to adgment refilling of the pressurizer. /R1
- a. Evaluate RCS temperature, pressure, and level instrumentation to determine if a bubble exists other than in the Pressurizer.
- b. If evaluation confirms, then continue charging to increase RCS pressure.
- c. When greater than 200F subcooled, operate Charging l and/or EPSI pumps to maintain Pressurizer level greater than 30% level, i
- 10. Insure closed 20204 (Pressurizer heater transformer 1A l 4.16KV feed).
l l 11. When pressurizer level indicates greater than 30%, energize pressurizer heaters B-1, B-2, B-3, and P-1. S e
. y _ _ , _. ._ -
Page 7 of 9 '" i ST. LUCIE UNIT NO.1 * ' EMERGENCY OPERATING FROCEDURE NLHBER 1-0030143, REVISION 1 TOTAL LOSS OF AC POWER ,
5.0 INSTRUCTIONS
( Cont .) 1 5.3 (Cont.) - 1 5.3.20 ( Cont .)
- 12. Establish ICW sealwater using of fsite power. If power was restored via 1A emergency D/G, proceed to step 13; o therwise : /R1
- a. Energize 1A1480V Load Center by closing 20110 (lA2 4.16KV feed to 1A1 480V L.C.) .
- b. Start LA Domestic Water Pump to supply water for Intake Cooling Water Pump start. Go to step 14.
- 13. Establish ICW sealwater using power from the diesel generato r. Energize 1A1480V Load Center as follows: /R1
- a. Insure 1A1480V loadcenter is fully stripped of loads. /R1
- b. Insert sync plug, close 20109, and hold control switch closed while closing 20209.
- c. Close 20209 and release 20109 hand switch.
- d. Close 20110 (1A2 4.16KV feed to 1A1480V load center).
- e. While loading secondary plant equipment, insure
. diesel loading remains less than 3500 KW.
- f. Start lA Domestic Water Pump to supply water for Intake Cooling Water Pump start.
- 14. Reestablish "A" train Intake Cooling Water System as follows:
- a. Establish seal water,
- b. Throttle LA I.C.W. pump dishcarge valve.
- c. Start 1A I.C.W. pump; pressurize and vent "A" I.C.W. header.
- d. Af ter venting, open 1A I.C.W. pump discharge valve.
Prgo 8 of 9 ST. LUCIE UNIT NO.1 . EMERGENCY OPERATING PROCEDURE NUMBER l-0030143,' REVISION 1 TOTAL LOSS OF AC POWER { 1 l I ?
5.0 INSTRUCTIONS
( Cont .) i l 5.3 (Cont .) f 5.3.20 ( Cont .) u==d
- 15. Reestablish "A" train Component Cooling Water System as follows:
- a. Isolate CCW to RCP's by closing RCV-14-1, 2, 6 and 7 (to prevent thermal shocking RCP seals)
- b. Throttle LA CCW pump discharge valve.
- c. Insure surge tank at normal level.
- d. Start LA CCW pump; pressurize and slowly open IA CCW pump discharge valve.
- 16. Reestablish CVCS letdown to maintain Pressurizer level at normal operating level. /R1
- 17. Commence boration to Cold Shutdown boron concentration. ./R1
- 18. Start one set of cavity and support cooling fans. /R1
- 19. Proceed to E0P 0120040, " Natural Circulation /Cooldown,"
step 5.3.9, and perform in conjunction with the balance of this procedure.
- 20. Restore balance of secondary plant in accordance with EOP 0030140, " Blackout Operation."
e e l
Pigs 9 of 9 ST. LUCIE UNIT NO.1 EMERGENCY 0FERATING PROCEDURE NUMBER l-00'30143, REVISION 1 TOTAL LOSS OF AC POWER [ 4 g h=q , t 4 I' i APPENDIX A }
, DISCUSSION I
.l i
The " Total Loss of AC Power" event consists of a loss of of f-site power in conjunction with failure of the Emergency Diesel Generators to provide emergency power. This results in a loss of all AC electrical power except that provided by inverters powered from the vital DC busses. The termination of AC power causes a loss of forced reactor coolant flow, main feedwa ter flow, steam flow to the turbine and pressurizer pressure control. The reactor trips on either low reactor coolant flow, high reactor coolant system (RCS) pressure or low steam generator level depending on initial conditions. The " Total Loss of AC Power" event also causes a loss of all reactor coolant system makeup capability which includes charging and safety injection flow. Inventory losses through leakage, reactor coolant pump controlled bleedoff, and primary relief valve releases are the major contributors to the degradation of pressure and level control during the event. The other contributor to coolant system shrinkage and pressure reduction is system heat loss, primarily through the pressurizer walls. Core heat removal is accomplished through natural circulation. Reacto r coolant system heat removal is accomplished using atmospheric dump valves and the steam driven auxiliary feedwater pump. O D O
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FLORIDA POWER & LIGHT COMPANY ST. LUCIE PLANT UNIT NO. 1 f 0FF-NORMAL OPERATING PROCEDURE NO. 1-1110032 i ! REVISION NO. 1 - . _ . . . _ _ , _ . - , V
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1.0 Title
This decu.-.c..} i: nof c:n:re'}ed. $afog use. 1 M Off-Normal Operation of the Liquid Waste I Y9dh* &IT'id%dh i a confrohd do39tnenf. 2.0 Review and Approval: ..
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Reviewed by Plant, Nuclear Safety Committee . - V 19 Approved by W ,e - - Plant Manager -
.. 19
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19 d-Revision No. 1 Reviewed by PNSC 6 e r / r.- Approved by S E /1 2./_ Y Plant Manager fu/. 2 3 - T 19A 3.0 Furpose and Discussion: y n ' 3.1 Purpose This precedure provides instruction in the off-normal operations of the Liquid Weste ?rocess Monitor. 3.2 Discussion - t The purpose of the Liquid Waste Monitor is to continuously monitor and _ record the radioactivity that is being discharged in the liquid waste being released to the circulating water canal.1 Prior to each discharge a representative sample of the liquid waste'to be discharged _; is taken ar.d analyzed. Based on this qualysis, the monitor setpoints are determined and set.
4.0 Symptoms
~
4.1 Visual and audible alarms on RMS cabinet "E" ' 4.2 Flashing Alert or High red alarm LED lights on the ratemeter. 4.3 A flashing Low Race (Fail) red alarm LED light on the ratementer. s - , 4.4 Increasing activity as noted on the recorder trace._.
5.0 Instructions
5.1 I::nediate Automatic Action: . 5.1.1 FCV.6627X, liquid waste flow control valve closes upon actuation of a High,' Lov Fig, or Monitor Fail alarms. ( ,
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OFF-NORMAL OPERATING PROCEDURESNO. 1-1110032, REVISION 1 , OFF-NORMAL OPERATION ON THE LIQUI 2 WASTE PROCESS MONITOR - I ST. LUCIE PLANT UNIT fl I
5.0 Instructions
(cont) . 5.2 Innediate Operator Action im 5.2.1 Ensure FCV-6627X, liquid waste flow control valve is closed. 5.3 Subsequent Operator Action 5.3I1 Notify Chemistry Department on termination of release. 3.3.2 Upon Evaluation of problem, a new analysis of waste monitor tanks contents is necessary, complete requirements of OP# 0510022, Controlled Liquid Release to the Circulatory Water Discharge to terminate release. 4 5.3.3 Upon Chemistry Department revaluation, the release can be restarted, using the same release permit with new setpoints entered into the radwaste monitor and the release permit reviewed by chemistry department and
\ the Nuclear Plant Supervisor. -
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{ OFF-NORMAL OPERATING PROCEDURZ NO. 1-1110032 REVISION 1 ;
,' 0FF-NORMAL OPERATION OF THE L %dID WASTE PROCESS MONITOR ST. LUCIE PLAY" UNIT #1 , ,
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References:
! 6.1 FSAR Section 11.4.2.3 i' . 6.2 PSL Technical Specifications ~ i >
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FLORIDA POWER & LIGHT COMPANY [ ST. LUCIE PLANI UNIT 2 - E-EMERGENCY OPERATING PROCEDURE NO. 2-0030140 ! REVISION O l
- 1. TITLE BLACKOUT OPERATION
- 2. PREPARED BY N.[l/N /O-/81982
- 3. SUBCOMMITTEE REVIEW Id]M/dh N b for FPL /O-/7 1972
- 4. REVIF'FD BY FRG ON .c .A G' 1971.-
- 5. APPROVED BY d / / l'd , ,, 4 _ w _-
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Edant Manager k 7 A 619Il 6 6- REVISION REVIEWED BY FRG ON 19
- 7. APPROVED BY Plant Manager 19 l
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Page 1 of 13 FLORIDA P0k'ER & LIGHT COMPANY ./ ,
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ST. LUCIE UNIT 2 N
! .1 EMERGENCY OPERATING PROCEDURE NO. 2-0030140 J j REVISION 0 d
j
1.0 TITLE
BLACKOUT OPERATION
2.0 APPROVAL
Reviewed by Facility Review Group a , e- #0 19 f .L. Approved by 1./-/ M n , 4 f.w/ D ant Manager e- 7- 7 f 19 T ), j i - Revision Reviewed by FRG 19 Approved by Plant Manager 19 3.0 PURPOSE OR DISCUSSION: 3.1 This procedure provides the action to be taken in the event-of a , complete loss of off-site electrical power concurrent with a Turbine trip. 3.2 Discussion - See Appendix A. t
4.0 SYMPTOMS
4.1 Alarms associated with the loss of operating plant components. 4.2 Loss of normal Control Room lightir.g and DC lighting energized. 4.3 Reactor and Turbine trip. 4.4 Emergency Diesel Generators start. 4.5 Reactor Coolant Pump trip and Main Feedwater Pump tri,,. 7p3 g a . -- n - - - ~ -- - - y p r - or [ 1
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r . Psgo 2 of 13 ST. LUCIE UNIT 2 . EMERGENCY OPERATING PROCEDURE NO. 2-0030140, REVISION O BLACK 0UT OPERATION
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5.0 INSTRUCTIONS
(_j, 5.1 Immediate Automatic Action: 5.1.1 Reactor and Turbine trip; Generator lockout. 5.1.2 Generator breakers open. < 5 . 5.1.3 Incoming feeder breakers open to 4160V and 6900V buses. 5.1.4 Tie breakers between normal 4160V buses (2A2 and 2B2) and the emergency 4160V buses (2A3 and 2B3) open. 5.1.5 Ties between essential and non-essential sections of emergency 480V MCCs open. 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. Pressurizer heater transformers A and B CEDM MG Sets 2A and 2B Fuel Handling 480V MCC 2A8, 2B8 Reactor cavity sump puap 2A Containment building elevator Electrical equipment room hoist 120/208 Power Panel 121 transformer Lighting panel transformers 110, 112, 114, 117, 125, 126 Incoming feeder from 2A2 and 2B2 4160V buses RCP oil lift pumps (B pumps only - A pumps running) Pressurizer relief isol valves (1403 and 1405) CVCS heat tracing transformer 2A and 2B 480V Lighting panel 2A, 2B and 2C Waste management heat tracing transformers 2A and 2B Air condiMoner HVA-4, ACC-4 Power panel 120 Lighting panels 113, 116, 109, 115, 130 Refueling equipment Refueling water to charging pumps (V-2504) Boric Acid batching tank heaters Fire siren
P:33 3 of 13 ST.. LUCIE UNIT 2 - EMERGENCY OPERATING PROCEDURE No. 2-0030140, REVISION.O BLACKOUT OPERATION
/*
5.0 INSTRUCTIONS
( Cont . ) l [I h 5.1 Immediate Automatic Action: ( Co nt .) 5.1.7 All loads on emergency buses are tripped except the following: I . Boric Acid Makeup Pumps Charging Pumps Emergency lighting , Class I power panels RCP cil lif t pumps ( A pumps only - B pumps of f) Diesel f uel oil transfer pump 5.1.8 Diesal generators 2A and 23 start and energize 4160V energency buses 2A3, 233, and 2AB and loads listed in step 5.1.7. 5.1.9 Subsequent loads are started at three second intervals. (See Table 1, Emergency Diesel Generator Loading Sequence.) 5.1.10 Auxiliary Feedwater auto start initiates when the first Steam Generator level decreases to 39%. - 5.2 Immediate Operator Action: 5.2.1 Trip Turbine and reactor manually. 5.2.2 Check all CEAs are f ully inserted and reactor trip breakers are open. 5.2.3 Check turbine valves are closed. 5.2.4 Check generator fie ! and 24CKV OCBs are open. 5.2.5 Place reheater ontrol system in manual, close TCVs. 5.2.6 Check that Diesel Generators have started and are feeding only emergency buses. 5.2.7 Open Startup transformer breakers. 5.2.8 Reduce T ave to reference setpoint by manual operation of the steam dump valves to atmosphere. 5.2.9 Isolate Steam Generator blowdown. O
Pcgo 4 of 13 ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE NO. 2-003'0140, REVISION.O BLACKOUT OPERATION
5.0 INSTRUCTIONS
(Cont.) j 5.2 Immediate Operator Action: (Co nt .) j/ 5.2.10 Verify the Steam driven AFW pump has started and has established flow to SCs. If AFW pumps have started due to -q the Luto start feature, the motor driven pumps may be secured, if desired. 5.2.11 If any of the automatic actions listed in 5.2.2 through 5.2.10 do not occur automatically, then manually initiate that action. 5.3 Subsequent Action: 5.3.1 Implement the Emergency Plan as necessary in accordance with EPIP 3100021E, "Duples of the Emergency Coordinator." 5.3.2 Verify 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
~49 F. ( AT for f ull power) .
0
- 1. If the above conditions are not established:
A. Check RCO , temperature and pressure to ensure, that the RCS is subcooled. B. Ensure AFW flow to the Steam Cenerators has been initiated and the steam dumps to atmosphere are in operation. C. Refer to EOP 2-0120043, "Inadequa te Core Cooling."
- 2. Return at least one RCP in each loop to operation as soon as of f-site power is availabla.
5.3.3 Start equipment in Table 1 if required. 6
t I 4 ST.' LUCIE UNIT 2 - EMERGENCY OPERATING PROCEDURE NO. 2-0030140, REVIS ION'O SMCKOITf OPERATION ,
,8 g ,
5.0 ESTRUCTIONS
( Cont . ) i n .2 [- Subsequent Action: ( Co nt.) 5.') [ 5.3.4 If one Diesel fails to start, attempt a manual start. [ - L W
- 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.
- 2. If no alarms are present on the local alarm panel, an inspection of the overspeed trip lever should be made to 1 insure it has not tripped.
- 3. If the overspeed trip levers are latched, the i
normal / isolate switches on the local control panel should be placed in the ISOMTE position and a local start attempt should be made., i
- 4. Refer to OP 2-2200020 and OP 2-2200050.
i 5.3.5 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).
i , 5.3.6 Check MSR warm-up valves (MV08-5, MV08-7, MV08-9, and .j MV08-11) to be closed or close manually. 5.3.7 Send an operator to align and start emergency cooling water I to the Instrument Air Compressor, then reset Control Room handswitch and manually start the Instrument Air Compressor. CAUTION: Do not overload the Diesel Generators when starting additional equipment (3685KW maximum continuous rating). 5.3.8 When Diesel Generator power is available, energize equipment 1 as may be required for plant safety and to achieve an orderly shutdown vi:hin the Diesel Generator load limitations as follows:
- 1. Verify one set of cavity and support cooling fans
- operating. If not, start one set.
- 2. Lock out automatic starting equipment that is not in service.
- 3. Manually open all breakars on any non-vital bus or motor control center that is to be re-energized.
- 4. Reset lockout relays for each required bus to allow clo' sing of feeder breakers.
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Pego 6 of 13 ST. LUCIE UNIT 2 EMERGENCY OPERATINC PROCEDURE No. 2-003'0140, REVISION. O BLACKOUT OPERATION
'1 9 Y
5.0 INSTRUCTIONS
( Cont . ) Sm J 5.3 Subsequent Action: ( Co nt.) / 5.3.9 Energize 4160V buses 2A2, 2B2, 480V load centers 2A1, 231 and 480 MCCs 2A1, 231, and 2C as follows: . h ACTION LOCATION
- 1. Strip non-vital 4.16KV buses 2A2 2B2
( All should be opened automatically)
- 2. Insert syne plug, close 4.16KV 2A2-20109 2B2-20309 non-vital breaker and. hold control switch closed while closing 4.16KV vital breaker. ZA3-20209 233-20411
- 3. Strip non-vital load center 2A1 231
- 4. Close 4.16KV feed breaker to 2A2-20110 2B2-20310 non-vital load centers
- 5. Strip 480V MCC 2A1 2B1 2C
- 6. Close 480V Load Center feed 2Al-40115 , 2B1-40411 breaker to MCC 2A1 and 2B1
- 7. Close 480V Load Center feed 2Al-40119 231-40410 breaker to MCC 2C 5.3.10 At MCC 2C, close breakers for turning gear, bearing oil pump, air side seal oil pump and hydrogen seal oil pump.
5.3.11 Place a Turbine Cooling Watsr" Pump in operation. 5.3.12 Align Turbine Cooling Water to the Instrument Air Compressor back to normal alignment. 5.3.13 Place turbine drain valve switch in the OPEN posit Lon. 5.3.14 Start bearing oil pump before turbine bearing oil pressure reaches 12 psig decreasing. Pump starts automati: ally at 12 psig decreasing turbine bearing oil pressu G. NOTE: If bearing oil pump fails to start, the emergency DC oil pump will start at 10 psig decreasing bearing oil press tre. Operator should start pump before 10 psig is reached. Stop the DC oil pump if it is running in addition to the bearing oil pump.
l Pigo 7 of 13 ST. LUCIE UNIT 2 . EMERGENCY OPERATING PROCEDURE NO. 2-0030140, REVISION- 0 BLACKOUT OPERATION ,## I <= 4 8 3 11 .
5.0 INSTRUCTIONS
( Cont .) j j 5.3 Subsequent Action: ( Co nt.) 5.3.15 Remove the following components from service: ' p .5 Steam jet air ejectors Priming ejector Auxiliary priming ejector Auxiliary steam to RAB Gland seal system 5.3.16 Start CEDM cooling fans 2A and 2B. 5.3.17 Start reactor support cooling fans 2A and 23. CAUTION: Consider equipment starting requirements. Alternate operation of equipment may be required to avoid overloading the Diesel Generators (3685KW maximum continuous rating). 5.3.18 tianually close breakers for pressurizer heater buses on 4160V buses 2A3 and 2B3. 5.3.19 Check that the bearing oil lif t pump starts automatically when turbine speed decreases to approximately 600 rpm. 5.3.20 start turbine lube oil vapor extractor and generator oil vapor extractor. 5.3.21 Check that the turning gear engages and starts automatically when turbine speed decreases to zero rpm, or manually engage it. 5.3.22 Reduce the ficw of cooling water to maintain the temperature of the oil leaving the turbine lube oil and the air side and hydrogen side oil coolers between 95 - 1000F. 5.3.23 Isolate cooling water supply to the generator hydrogen coolers. 5.3.24 If additional Condensate Storage Tank water is required, have Unit 1 personnel place the Water Treatment Plant in se rvice . 5.3.25 Place the spent fuel pool cooling pump in operation as necessary. NOTE: With spent fuel elements from 3-1/3 cores present.
- the spent fuel pool can safely withstand five hours without cooling bef ace reaching the boiling point.
i Pago 3 of 13 ST. LUCIE UNIT 2 - EMERGENCY OPERATING PROCEDURE NO. 2-0030140, REVISION O f ,s, BLACK 0tTr OPERATION # f 5.0 I h INSTRUCTIONS: (Cont.)
*/
5.3 Subsequent Action: ( Cont.) 5.3.26 Periodically check fuel oil levels in the Diesel Generator day tanks to confirm proper operation of the fuel oil -- transfer system and to ensure uninterrupted Diesel Generator operation. 5.3.27 Sample and analyze the reactor coolant to determine if fuel element clad failure has occurred. 5.3.28 Determine expected duration of power outage. If unable to do so or if outage is to be prolonged, borate RCS to Cold Shutdown concentration. 5.3.29 If the outage will exceed four hours and the RWT is available, proceed to Cold Shutdown conditions utilizing natural circulation, atmospheric steam dump and feedwater addition. Re fer to E0P 2-0120040, " Natural Circulation /Cooldown." Place shutdown cooling in service when appropriate temperatures and pressures are reached. NOTE: Do not begin plant cooldown until Cold Shutdown boron concentration is verified. 5.3.30 If Pressurizer cooldown cannot be accomplished in a timely manner from the addition of cooler liquid (auxiliary spray) from the Charging Pump via che Pressurizer spray line, proceed with the alternate positive meant of depressurization as follows:
- 1. Place the switches for the Power Operated Relief Valves (V-1474 and V-1475) in the OVERRIDE position.
- 2. Initiate a high Pressurizer pressure trip signal en two
, RPS channel trip units.
- 3. Place the switch for either Power Operated Relief Valve (V-1474 or V-1475) in the NORMAL RANGE position and vent the Pressurizer to the Quench Tank. Return the switch to OVERRIDE to close valve.
- 4. Control the rate of cooldown and depressurization by selective operation of the Power Operated Relief Valves in this mode until cooldown via the auxiliary spray valves can be initiated.
t 5.3.31 When normal AC power is available:
- 1. Restore bus sections to their normal supplies, i 2. Place the Diesel Generator system in standby lineup as per OP 2-2200020.
- 3. Restore all plant systems to normal. -
.Prgo 9 of 13 ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE No. 2-003D140, REVISION O BLACKOUT OPERATION
6.0 REFERENCES
6.1 FSAR, Section 15 6.2 FSAR, Section 8 6.3 Of f-Normal OP 2-0030130, " Shutdown Resulting From Reactor / Turbine Trip." 6.4 OP 2-0210020, " Charging and Le tdown." 6.5 OP 2-0330020, " Turbine Cooling . Water Operation." 6.6 Off-Normal OP 2-0250031, " Boron Concentration control, Of f-Normal." 6.7 Of f-No rmal OP 2-1010040, " Loss of Instrument Air." 6.8 OP 2-1540020, " Water Plant Startup and Shutdown." 6.9 OP 2-2200020, " Emergency Diesels - Standby Lineup." 6.10 OP 2-0700022, " Auxiliary Feedwater System Operation." 7.0 RECORDS / NOTIFICATIONS: 7.1 Normal log entries. , 7.2 AP 0010134, " Component Cycles and Transients." 9
Page 10 of 13 g ST. LUCIE UNIT 2 I EMERCENCY OPERATING PROCEDURE 2-0030140, REVISION 0 BLACKOlff OPERATION TABIR 1 DIESEL CENERATOR LOADING SEQUENCE RIN HNG linD (IM) Per Nostnal IIrA Diesel loai or Siutdown With (Recirculation) min Steam Line Autoutic Startirg Gnwrator Reneplate StartirE T1sirg loss of Off- With loss of Off- BrexA With loss of Iron Equipment (4) Qtantity IIP KVA Segw nee Site Ibwr (Ill0P) Site Ibwr (Ill0P) Of fsite Ibwr (Ill0P) I ltigh Pressire Sifety Inj. heap 1 400 2422.0 0 Sm. - 373 373 2 mtor Operatal Valves tot 57 585 0 Sec. 40 8 (1) 80 3 linergesicy 1.ightiru lot - - 0 Sec. 70 70 70 4 lbwer Panels lot - - 0 Sec. 30 30 30 5 Diesel Oil Transfer naaps 1 3 21.5 0 Sec. 3 3 3 6 RCP 011 Lift Rsaps 4 10 66.85 0 Sec. 19 ' 19 19 7 Gitaterruptible Ibwr Supply 1 - - 0 Sec. 20 20 20 8 IIVAC heapers lot - - 0 Sec. 4 4 4 9 liVAC Valves Int - - 0 Sm. 3 3 3 10 , Elec. Fautp. Rxna Exluust, 2-ilVE-11 1 50 244.7 0 Sec. 47.5 47.5 47.5 11 Elec. F4uip. Roon Exlaist, 2-RV-3 1 5 34.22 0 Sec. 5 5 5 12 liittery it,as Roof Ventilator, 2-RV-1 1 0.75 8.5 0 Sec. .75 .75 .75 13 low Presstre Safety Inj. Rsap 1 400 2183.3 3 Sec. - - 361 14 Contalment Fan Omlers 2 125/83 &8.4 3 Sec. 160 160 160 15 Elec. F4uip. Room Supply 1 100 584,12 3 Sec. 95 95 95 16 Compment Coolism wter asup 1 450 2491'.2 6 Sec. 400 400 400 17 Shield Bulldire hiaust 1 60 340.6 6 Sec. - 57 57 j 18 Shield Ikilldlig Ibaters tot - - 6 Sec. - 31.5 31.5 i I
Page 11 of 13 . ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE 2-0030140, REVISION O B_LACKOITT OPERATION . TABLE 1 DIESEL CENERATOR LOADING SEQUENCE (Continued) IDHitC IIMD (IGl) 1 Per Naninal IHA Diesel loal or Shutdom With (Recirculation) Kain Steam Line Autoutic Startirg Cemrator Romeplate Startian Thalig Inss of Off- With loss of Off- Break With Inss of Iton Eqtdpaent (4) Qantity IIP KVA Sequeire Site ther (IDOP) Site ther (IDOP) Offsite ther (IDDP) 19 Intake Gmllig Eter haap 1 600 3709.0 9 Sec. 527 527 527 20 0)ntairement Spray hsap 1 500 2892.6 12 Sec. - 450 450 21 Ilyilrazine heap 1 3 21.5 12 Sec. I 1 1 22 Auxiliary Feolwater asap 1 350 1951.4 15 Sec. 297 297 297 (2) 23 lbric Acid Ibat Trace Int Int - 18 Sec. 5 5 5 (3). 24 Q>ntrol Roon Air Gmlitionhg 2 60 - 18 Sec. 57 57 57 25 Gmtrol Roon Haer. Filter Fan 1 10 62.0 18 Sec. 9.5 9.5 9.5 26 RAB kpply Fan 1 150 900.1 18 Sec. 142.5 142.5 142.5 . 27 E1]CS Area Exinust Fan 1 60 358 18 Sec. 57 57 57 28 thetor Civity Supply Fan 1 20 124.15 18 Sec. 19 - - 29 Reactor Supports On11rg 1 40 234.76 18 Sec. 33 - - 30 Intake kildhg On111g Fan 1 7.5 44.0 18 Sec. 7.13 7.13 7.13 31 mttery Ourger 1 3 - - 73.5 73.5 73.5 32 O urgLg henps 2 125 1656.8 M a nt loal 237.5 237.5 - 33 kric Acid Mikeup hup (5) 2 25 148.2 Knn1 loal 47.5 47.5 - 34 low Pressure Lfety Inj. hanp 1 400 2183.3 K a nt Loal 309 - -
Page 12 of 13 ST. LUCIE UNIT 2 # EMERGENCY OPERATING PROCEDURE 2-0030140, REVISION O BLACK 0lJr OPERATION e; TABLE 1 DIESEL CENERATOR LOADING SEQUENCE (Continued) RitNIPC IIRD (107) 9 Per Nominal III1 Q,.. -ad Diesel Inal or Surdom With (Recirculation) Main Steae Line Automatic Starting Gmerator Meneplate Starting Theirg loss of Off- With loss of Off- Break With Insa of Itos Equipment (4) Qantity llP KVA Seq (erre Site Ihr (IDOP) Site Ihr (IDDP) Offsite Ihr (II1F) 35 Instrument Air Campress)r. I 60 340.6 M a ul loal 57 - - 36 Re1 Ibol Ox211ng asap 1 40 234.76 Mnni loal 3'8 38 - 37 Ilyttrogen Recombiner 1 - - Knial loal - 75 - 38 Prestrimr thaters 1 - - M n ni loal 150 - - after 2 tours 100P Tbtal 3317.0IGi 3298.00 IGi 3335.53 IGi N)tes: (1) Acttutal on RAS ' (2) Startal if operathe grior to IIxP (3) Apgraxhmite IGi requirol for toegerattre mainterare ' (4) Itons 32 to 37 inclistve are anni loals (5) Exh Baric A:Id Hikeup Punps are loalal onto Diesel Cerwnitor A l l
~
?cga 13 of 13 ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE NO. 2-0030140, REVISIOR 0 ^
BLACK 0tTr OPERATION
~
[,37. APPENDIX A d! - f j DISCUSSION ,
- 1. A loss of power to the 4160V buses results in a loss of power to all 480V Load Centers 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 6900V buses supplying the Reactor Coolant Pumps and will be accompanied by a Turbine trip and Generator lockout.
- 2. Steam dump to atmosphere must be used to remove reactor dacay heat.
Initially, Steam Generator safety valves may actuate to augment the steam flow and to help control Steam Generator pressure immediately af ter the trip.
- 3. On-site power will be supplied by the Emergency Diesel Generators.
- 4. A rapid reduction in Steam Generator water levels will occur due to the reduction of the Steam Generator void fraction on the secondary side and also because steam flow will continue af ter normal feedwater flow stops.
Auxiliary feedwater flow will automatically initiate af ter the first Steam Generator level reaches 39% (2/4 logic) .
- 5. Core decay heat removal is accomplished by natural circulation iti the reactor coolant loops.
- 6. Core damage is not expected as a result of a loss of power condition as the Steam Generators are maintained as a heat sink and pressurizer pressure and inventory control are available.
- 7. If operating under blackout conditions and an Engineered Safety Features Actuation signal occurs, any non-emergency loads that are running will be automatically tripped and the required emergency loads will be automatically started.
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e Os ; FL0e.IDA POWER & LIGHT CCH2ANY ; ST. LUCIE PLANT UNIT NO. 2 '* 4 EMERGENCY OPERATING FROCEDURE 2-0030141 g ,.. REVISION NO. 0
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- 1. TITLE: CONTROL ROOM INACCESSIBILITY -
- 2. PREPARED BY: L. Rich, M. Perry 10-7 1982
- 3. SUBCOMMITTEE REVIEW BY: B. PEARCE, D. SAGER For FP&L /O S 19 8 4- REVIEWED BY FRG ON: ti'-_ ? .2S 19 S
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- 5. APPROVED BY . ], />,/'h / <.A.% r /3DLANT MANAGER C',T f. ~
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- 6. REVISION REVIEWED BY FRG ON: 19 _
- 7. APPROVED BY PLANT MANAGER 19-4 j
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o FLOR 2DA POWER & LIGHT COMPANY ST. LUCIE UNIT NO. 2 - EMERGENCY OPERATING PROCEDURE 2-003014L / % REVISION O f
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1.0 TITLE
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CONTROL ROOM INACCESSIBILITY
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2.0 APPROVAL
Reviewed by Facility Review Group 'T '("
-)4 19Eck Approved by 1 /J-/4 . , m- M ant Manager P- /R. 19{ -
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Rev. Reviewed by FRG 19__ Approved by Plant Manager 19__ r 3.0 PURPOSE & DISCUSSION: 3.1 This procedure provides instructions for placing the plant in a safe condition when operations cannot safely be conducted from the Control Room. 3.2 The reactor and turbine are manually tripped prior to leaving the Control Room, if possible, or locally from the Reactor Trip Switchgear and the Turbine f ront standard. 3.3 A heat sink is provided by automatic steam dump to the Condenser and/or to atmosphere. 3.4 Level is maintained in the Steam Generators by manual control of auxiliary feedwater valves with flow furniched by the Auxiliary Feedwater Pumps. 3.5 Pressurizer level and pressure are maintained by manual control of Pressurizer heaters, auxiliary spray valves, and letdown valves, and are monitored at the Remote Shutdown Pane'. 3.6 Isolation switches located in the Reactor Auxiliary Building Electrical Equipment Room, Turbine Building Switchgear Room, Diesel Generator Rooms, and Reactor Auxiliary Building are manually selected tc the ISOLATE position to prevent inadvertant operation of vital equipment due to possible electrical malfunction in the unattended Control Room. 3.7 A copy of this procedure will be posted at each manned operating station required for plant shutdown from outside the Control Room. N
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l l Pega 2 of 36 ST. LUCIE UNIT NO. 2 . EMERGENCY OPERATING PROCEDURE NUMBER 2-0030141, REVISION O CONTROL ROOM INACCESSIBILITY
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3.0 PURPOSE & DISCUSSION: (continued) I'Q(9 ; e 1 3.8 A listing of isolation switches will be posted on each of the J' j following panels, MCCs, and distribution buses. j/r
- 1. Load Centers 2A, 25, 2AB . n I l 2. Isolation Switch Panels 2A, 2B, 2AB
- 3. MCC 2AS, 2A6, 2BS, 2B6
- 4. 4160V Buses 2A3, 2B3, 2AB 5 4160V Buses 2A2, 2B2
- 6. 6900V Buses 2Al, 2B1
- 7. Diesel Generator 2A and 2B Control Panels 3.9 The Nuclear Plant Supervisor will utilize additional personnel as availabla to assist in reouired subsequent actions.
4.0 SYMPTOMS
4.1 Conditions exist such that the Control Room becomes uninhabitable and nust be evacuated. 5.0 INSTRUCTION 5: ! 5.1 Immediate Actions: 5.1.1 Manually trip the reactor and Turbine prior to leaving the Control Room, if possible. 5.1.2 Announce evacuation of the Control Room over the P.A. system. 5.1.3 Implement the Emergency Plan, as necessary, in accordance
- with EPIP 3100021Z, " Duties of the Emergency Coordinator".
5.1.4 Obtain the Remote Shutdown Room Keybox Master Key from the Control Room Key Locker: Key Number (LATER). 5.1.5 Evacuate all' personnel from the Control Room. 5.2 Subsequent Actions: 5.2.1 Man and take control of stations as follows:
- 1. Reactor Control Operator "A" - Remote Shutdown Panel.
A. Establish communications on the Sound Power Phone System. B. Monitor available plant parameters on the Remote Shutdown Panel. C. Start motor or steam-driven Auxiliary Feedwater Pumps and feed the Steam Generators as required.
, _ - _ . _ . _ . _ , , _ , _ - _ . _ , , , . . _, . . . , . _ _ ~ . . _ ~ , _ 4,_ . . , .._, - - _.__ _ _ , _ . . - . . - . _ _ . - . - , . -
Psgn 3 of 36 ST. LUCI2 UNIT NO. 2 EMERGENCY OPERATING PROCEDURE NUMBER 2-0030141, REVISION O CONTROL ROOM INACCESSIBILITY
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5.0 INSTRUCTIONS
(continued 5.2 (continued) 4,,6 ' Ol 5.2.1 (continued) [ f
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D. Control Pressurizer pressure and level by manual _ control of Pressurizer heaters, auxiliary spray valves, and letdown valves. NOTE: Only the "P" Letdown level and pressure valves are controllable from the Remote Shutdown Panel.
- 2. Nuclear Plant Supervisor - Electrical Equipment Room, Reactor Auxiliary Building - 43' Elev.
A. Open or check open Reactor Trip Breakers TCB-1 through 8. i
- 3. Place isolation switches in the ISOLATE position on the following switchgear in the order listed: (See Appendix A).
480V Load Center 2A3 480V Load Center 233 , 480V Load Center 2A2 4160V SWGR 2A3 480V MCC 2A5 480V MCC 2A6 480V Load Center 232 4160V SWCR 233
- 480V MCC 2B6
,' 480V MCC 2B5 i 480V MCC 2A3 Isolation Panel 2A3 Isolation Panel 2A Isolation Panel 23 ' Communications Isolation Panel C. Assist Reactor Control Opdrator "A" in monitorin3 unit parameters from the Remote Shutdown Panel.
- 3. Reactor Control Oper:itor "B" - Turbine Operating Level.
A. Locally trip or verify tripped Unic No. 2 Turbine. B. Verify Turbine Stop Valves and Control Valves are shut; if not, initiate Turbine trip from Turbine front standard. C. . Proceed to Turbine Building Switchgear Room and establish commanications on the Sound Powered Phone circuit.
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Pega 4 of 36 ST. LUCIE UNIT NO. 2 EMERGENCY OPERATING PROCEDURE NUMBER 2-0030141, REVISION O CONTROL ROOM INACCESSIBILITY .e 3
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5.0 INSTRUCTIONS
(continued) - 5.2 (continued) 5.2.1 (continued) d g } D. Place isolation switches in the ISOLATE position for bus feeder breakers as follows (see Appendix A): 4160V SWGR 2A2 4160V SWGR 2B2 , 6900V SWGR 2Al 6900V SWGR 2B1 E. Stop 2A and 2B Main Feedwater Pumps, 2A and 2B Heater. Drain Pumps, and one Condensate Pump by opening their respective breakers. CAUTION: Ensure that one Condensate Pump resains in service.
- 4. Nuclear Operator - Reactor Auxiliary Building.
A. Place isolate switches in ISOLATE / LOCAL position on the following switchgear (see Appendix A): 4160V SWGR 2AB 480V Load Center 2AB B. Proceed to the Diesel Generator Building and place isolation switches on 2A and 2B Diesel Control Panels in ISOLATE position (see Appendix A). C. Open or check open isolation valves for Lecdown pressure and level control valves (V-2110P and V-220lP). Isolate V-2110Q and V-2201Q. D. Proceed to the Charging Pump area and establish communications on the Sound Powered Phone circuit. 5.2.2 Maintain Pressurizer level at approximately 33% indicated level. 5.2.3 Maintain Pressurizer pressure at approximately 2100 psia. 5.2.4 Maintain Reactor Coolant System temperature at or below 532*F (2A cold leg temperature) by use of atmosphere steam dump and/or selective shutdown of Reactor Coolant Pumps. NOTE: Stop Reactor Coolant Pumps as required by opening the Reactor Coolant Pump breakers in the Turbine Building Switchgear Room. 5,2.5 Maintain Steam Generator levels at the approximately 65% indicated level by operation of the Auxiliary Feedwater Pumps and discharge valves to the Steam Generators. ,
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Pegs 5 of 36 ST. LUCIE UNIT NO. 2 . EMERGENCY OPERATING PROCEDURE NUMBER 2-0030141, REVISION O , CONTROL ROOM INACCESSIBILITY ' I,M g5
5.0 INSTRUCTIONS
(continued) [,,j
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5.2 (continued) / . jr / 5.2.6 Isolate Steam Generator blowdown by manually closing 4f isolation valves at the Closed Blowdown Heat Exchangers. .T E- . 5.2.7 When Turbine speed decreases to "0" RPM, verify that the l Turning Gear Oil Pump and the turning gear are in operation. ; 5.2.8 Periodically check the habitability of the Control Room and when conditions permit, reoccupy the Control Room. Return isolation switches to NORMAL for switches and controls that l are operational and maintain the Unit at Hot Standby until a complete evaluation has been made. 5.2.9 If Control Room r.ccessibility is not possible, place the i unit in a Cold Shutdown condition as follows: i
- 1. Commence boration to Cold Shutdown conditions by manual valve lineup. Borate to 1900 ppa as shown below.
NOTE: This concentration will ensure >5% Shutdown Margin at 201*F at any time in core life, assuming the most rea,etive CEA stuck full out. Use both the local boron flow seters vs. time and BAM Tank level change to determine how many gallons of boron have been added. Do not interpolate values shown, always round critical boron concentration DOWN to next lower value on tabla. NOTE: If plant curves are available, they may be used to l determine shutdown boron concentration ) requirements instead of this Table. l t Bcron Conc. Number of Gallons BAM Tank Prior to Control of Baron needed level change Room Inaccessibility to reach 1900 ppa (1 BAM Tank) i 50 PPM 7223 Gal 75% j 100 PPM 7039 Gal 73% 200 PPM 6668 Gal 70% I 300 PPM ' 6295 Gal 66% 400 PPM 5919 Gal 62%
- 500 PPM l 5442 Gal 57% -
600 PPM 5162 Gal 54% 700 PPM l 4779 Gal 50% 800 PPM 4395 Gal 46% 900 P PM 4008 Gal 42% 1000 PPM 3618 Gal 33% 1100 P.PM 3226 Gal 34% 1200 PPM 2832 Gal 30% 1300 PPM 2435 Gal 25% 1400 PPM 2036 Gal 21% 1500 PPM ! 1634 Gal 17% ,
t Pego 6 of 36 ST. LUCIE UNIT NO. 2 . EMERGENCY OPERATING PROCEDURE NUMBER 2-0030141, REVISION 0 CONTROL ROOM INACCESSIBILITY
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5.0 INSTRUCTIONS
(continued) 5.2 (continued) Q}j #
)
t 5.2.9 (continued) [
- 2. Ensure Steam Generator level is being maintained at g~I i
approximately 65% by the Auxiliary Feedwater Pumps.
- 3. Stop at least one Reactor Coolant Pump prior to reaching '
500*F by tripping its breaker at the 2Al or 231 switchgear. Additional RCPs may be stopped as desired
, to control cooldown rate. After pump coastdown, stop the lift pumps by opening the associated breakers in the electrical switchgear room. Re-close lift pump breakers afcar one minute elapses.
i
- 4. Place all Pressurizer heater switches at the Remote Shutdown Panel to 0FF. Heaters may be ener3 1zed to control RCS pressure as needed.
- 5. The highest RCS cold leg temperature (highest one with RCP running) shall be plotted every 30 minutes. The copy of the graph (Figure 1) shall be kept with this procedure. The RCS temperature and pressure shall be determined to be within the limits of Figure 3.4-2b at least once per 30 minutes during cooldown.
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NOTE: Cooldown of the RCS shall be limited to f 75 F in any one hour period.
- 6. The Pressurizar water phase temperature shall be plotted every 30 minutes using the Saturated Temperature v,
~
Pressure curve of this procedure (Figure 2). If possible, maximize letdown and minimize char 31ng when using auxiliary spray to minimize thermal stress on spray nozzle. l NOTE: Cooldown of the Pressurizer shall be limited l co i 190*F in any one hour period. l 7. When the quanity of boron calculated in Step 5.2.9.1 has been added, cooldown may proceed. Verify by chemistry sample (if possible) that desired boron concentration has been obtained. Commence taking data on cooldown l curve. Have the "B" Reactor Control Operator break Condenser vacuum by manually opening vacuum breaker MOVs. CAUTION: MSIS will occur at about 475'F, and sealing
. steam will be lost. Condenser vacuum must be i broken prior to 475*F to prevent seal damage.
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Pags 7 of 36 ST. LUCIE UNIT NO. 2 EMERGENCY OPERATING PROCEDURE NUMBER 2-0030141, REVISION O CONTROL ROOM INACCESSIBILITY
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5.0 INSTRUCTIONS
(conticued) bav$l I j 5.2 (continued) + # l 5.2.9 (continued) ,
- 8. While locally monitoring and controlling VCT level, '
f slowly open the atmospheric steam dumps and establish the desired cooldown rate.
- NOTE
- A makeup blend ratio to the VCT of about 9:1 is sufficient to maintain 1900 PPM boron in the RCS.
l . NOTE: A temperature differential of approximately
, 100'F between the RCS and Pressurizer should be maintained during cooldown. _Cooldown of the
- Pressurizer must be accomplished by use of auxiliary spary and heater control.
- 9. At 1750 psia, isolate and bypass the following transmitters:
- 1) Charging header flow: close valve marked "HIGH SIDE", open valve marked " BYPASS", and close valve marked " LOW SIDE".
l i 2) Charging header pressure: close its isolation valve.
- 10. When the SIAS anber permissive lights cons on (1700 psia), block SIAS by turning the key operated switch on
, the Remote Shutdown Fanel for both A and B channels.
> 11. Commence venting all .four SITS from remota valve stations in the Pipe and Electrical Penetration Rooms. (Valves 3733, 3734, 3735, 3736, 3737, 3738, 3739 and 3740), i
- 12. Maintain at least two Reactor Coolant Pumps operating.
If possible, two RCPS in the same loop should be lef t running. i 13. Periodically adjust the steam dump controllers and auxiliary spray control to maintain the desired ccoldown
- and de pressurization rate. Verify that the Steam l Generators are being maintained at approximately 65%
level.
- 14. With RCS pressure < 1700 psia, but prior to commencing SDC operations, rack out 2A and 2B Containment Spray Pump breakers (2-20203 and 2-20407).
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Psgs 8 of 36 ST. LUCIE UNIT NO. 2 EMERGENCY OPERATING PROCEDURE NUMBER 2-0030141, REVISION O CONTROL ROOM INACCESSIBILITY _ ,,,,. I (~s i:=m$ '
5.0 INSTRUCTIONS
(cont.) , r 5.2 (continued)
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5.2.9 (continued) -
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- 15. When RCS temperature is < 500*F and RCS pressure is <
1500 psia, preform the following: A. Close 2-V-07145 and 2-V-07130 (Containment spray pump disch valves) B. Close the following containment spray header' manual isolation valves. 2-V-07161 (A hdr FCV upstream isol) 2-V-07164 (B hdr FCV upstream isol) 2-V-07162 (A hde FCV downstream isol) 2-V-07165 (B hde FCV downstreats isol)
- 16. When RCS pressure is < 275 psia, rack in the breakers for and then close the SIT discharge valves by placing the local control switch in the CLOSE position.
MV-3614: Bkr 2-41219
- MV-3624: Bkr 2-41311 MV-3634: Bkr 2-42117 MV-3644: Bkr 2-42048
- 17. Rack out the SIT discharge valve breakers.
CAUTION: Prior to lowering RCS pressure below (LATER) psia, two RCPs in the same loop must be operating.
- 18. Lower RCS termperature to 300*F and RCS pressure to 260 psia.
- 19. Remove the trip and close fuses on one 11 PSI Pump.
Ensure that the other liPSI Pump remains operable. CAUTION: With SDC in service, an increase in RCS pressure > 350 psia will result in rapid RCS inventory loss due to lif ting of relief valves in Hot Leg suction lines (Total capacity 4,600 gpm). NOTE: Minimum pressure for RCP operation is (LATER), so it is necessary to proceed quickly to Shutdown CoolinS. O
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.'. 4 Pcgs 9 of 30 ST. LUCIE UNIT NO. 2 EMERGENCY OPERATING PROCEDURE NUMBER 2-0030141, REVISION 0 %}
CONTROL ROOM INACCESSIBILITY [%
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5.0 INSTRUCTIONS
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S.2 (continued) '~
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(continued) . -s - s
- 20. Stop the operating RCPs prior to lowering pressure to x (LATER) by tripping the breakers on 2Al and 2BL switchgear. After pump coastdown, stop the oil lift , ' g pumps by opening the breaker for eadh pump for 1 minute, then re-closing the breaker. ,
- 21. Reduce RCS pressure to < 350 psia, then open'the
following valves from their local controllers: A. Hot Leg Suction Valves:, V-3651, V-3652, v-3665, ' V-3480, V-3481, V-3664. - [ , ( NOTE: V-3664andV-3665localcontrollersardsiA' Pipe Penetration Room, all others are in the Cable, Spreading Room. , NOTE: V-3545 (Hot Leg Suction Cross-Tie) is nocM11y closed. It may be used to provide flow during off-normal conditions. B. CCW from SDC Heat Exchangers: HCV-14-3A and - HCV-14-3B by (LATER). 'Y P C. SDC Heat Exchanger Discharge Valves: MV-3456 and MV-3457. , D. LPSI Header Isolation valves: MV-3615, MV-3625, MV-3635 and MV-3645. l i
- 22. Close the folicwing valves: \
A. RWT recirculation stop valves: V-3459, V-3463; and ' V-3597. ~- $- B. Minificw header stop valves: V-3659, V-366], V-3459 and V-3496. I
- 23. Have the Nuclear Operator establish communications on the Sound Power Phone System in the 2A LPSI Pump Room.
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Pcgs 10 of 36 l
! ST. LUCIE UNIT NO. 2
'. t EMERGENCY OPERATING PROCEDURE NUMBER 2-0030141, REVISION O .
l; % \,- CONTROL ROOM INACCESSI3ILITY
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- 4 5.0 INSTRUCTIONSt
+
(cont.)
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, 5.I (contin N) .3
- 5.2.9 -(ccatinued) f/ !
.24'. ' Establish SDC as follows: b 3
. !' ,y l -s - C .' A. In(grekeysforMV-3306andMV-3657(controllers
'* . located .n A LPSI Room) and place switches to s~
MODULATE position. " ,, g %., , s ) 2 ','# ' B. Using key switches at local controlle'?s, open MV-i 3517 and MV-3456. ' s ,- .
"' ;; ,' C. GiveMV-3506a3secondopensiknal,thenallow
],. s 7 switch to return to NORMAL. i' s \ , D. Start the 2A LPSI Pump, then open MV-3306 to obtain
. 3000 spe flow as indicated on FI-3306 at the Remote Shts:down Panel.
E. While observing SDC outlet temperature and flow on
% the Remote Shutdown Panelg alternately open MV-3657 and close MV-3306 to achie've desired cooldown rate 2 anA wintain 3000 spe. , ,
_ s 25.[At200*FRCStemperature,removethetripandclose s 4 fuse,s on the remaining EPSI Pump. Open the breaker for one Charging Pump so that no more than two Charging
. Pumps are operable. ,
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- 26. ' Stabilize RCS temperature at approximately 100 F0 and RCS li pressure at approximately 250 pr a. Control pressure by
'N ' ( use of Pressuriser heaters and auxiliary spray. Do not take the Pressurizer solid until Control Room access has s been re-established.
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ST. LUCIE UNIT NO. 2 EMERGENCY OPERATING PROCEDURE NUMBER 2-0030141 REVISION O CONTROL ROOM INACCESSIBILITY
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's APPENDIX "A" (continued) % / jl ~
ISOLATION SWITCHES ?
/ 2 li a? ,/
e 480V Load Center 2A3 - Pressurizer Heater Bus, Auxiliary Building Electrical Equipment Room
- 1. Heater Bank P-1
- 2. Heater Bank B-1
- 3. Heater Bank B-2
- 4. Heater Bank B-3 I
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Paga 12 of 36 ST. LUCIE UNIT NO. 2 EMERGENCY OPERATING PROCEDURE NUMBER 2-0030141, REVISION O CONTROL ROOM INACCESSIBILITY I I f APPENDIX "A" (continued) [,y )y ISOLATION SWITCHES , 480V Load Center 2B3 - Pressurizar Heater Bus, Auxiliary Building - Electrical Equipment Room
- 1. Heater Bank P-2
- 2. Heater Bank B-4 e
- 3. Haater Bank B-5
- 4. Heater Bank B-6 4
e e e e b e G 0
I Pade 13 of 36 ST. LUCIE UNIT NO. 2 EMERGENCY OPERATING PROCEDURE NUMBER 2-0030141, REVISION O CONTROL ROOM INACCESSIBILITY A ( \ I #3 5
/ Ji 1 APPENDIX "A" (continued) N==d 8
}
ISOLATION SWITCHES / / l // . 3 480V Load Center 2A2 - Auxiliity Building Electrical Equipment Room
- 1. SS Transformer 2A2
- 2. Bus Tie to 480V L.C. 2AB
. 3. Containment Fan Cooler 2-HVS-1A
- 4. Containment Fan Cooler 2-HVS-13
- 5. lA Charging Pump G
Pegs 14 of 36 ST. LUCIE UNIT NO. 2 EMERGENCY OPERATING PROCEDURE NUMBER 2-0030141, REVISION O _- CONTROL ROOM INACCESSIBILITY .,4 -=%g,
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APPENDIX "A" (continued) ,jr / ISOLATION SWITCHES Y' /' l J sm-va d - 4160V SWGR 2A3 - Auxiliary Building Electrical Equipment Room
- 1. 2A EPSI Pump
- 2. 2A LPSI Pump
- 3. 2A Containment Spray Pump
- 4. Pressurizer Heater Transformer 2A3
- 5. 2A Component Cooling Water Pump
- 6. 2A Intake Cooling Water Pump
- 7. CEDM Cooling Fan 2HVE-21A
- 8. Feed to 4160V Bus 2AB
- 9. Feed from 4160V Bus 2A2
- 10. Feed to 480V SS Transformer 2A2
- 11. Feed from 1A Emergency Diesel Generator
- 12. 2A Auxiliary Feedwater Pump l
Pega 15 of 36 ST. LUCIE UNIT NO. 2 EMERGENCY OPERATING PROCEDURE NUMBER 2-0030141, REVISION O CONTROL ROOM INACCESSIBILITY
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- s aj 3 APPENDIX "A" (continued) S =m! ; .?
-l 0 ISOLATION SWITCHES f ,[
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480V MCC 2A5 - Auxiliary BuildinE Electrical Equipment Room
^i
- 1. Makeup Bypass to Char 31ng Pumps (V-2514)
- 2. 2A AFW Pump Discharge to 2A Steam Generator (MV-09-9)-
- 3. 2B Steam Generator to 2C AFW Pump Turbine (MV-08-12)
- 4. CCW to Containment Fan Cooler 2HVS-1A (!!V-14-9) .
- 5. CCW to Containment Fan Cooler 2HV5-1A (MV-14-10)
- 6. CCW to Containnsnt Fan Cooler 2HV5-13 (!iV-14-11)
- 7. CCW to Containment Fan Cooler 2HVS-13 (MV-14-12) e e
1
- - - ,,, m , , . - - - - --
Pcgt 16 of 36 ST. LUCIE UNIT NO. 2 EMERGENCY 0"PERATING PROCEDURE NUMBER 2-0030141, REVISION O CONTROL ROOM INACCESSIBILITY f* 5 i APPENDIX "A" (continued) r h 1md[ cfj ISOLATION SWITCHES , [- _ _ . 480V MCC 2A6 - Auxiliary Building Electrical Equipment Room
- 1. 2A Boric Acid Makeup Pump
- 2. 2B Boric Acid Makeup Pump
- 3. 2HVA-3A - Control Room Outdoor Air Conditioner
- 4. 2HVE-6A - Shield Building Exhaust Fan
- 5. 2HVE-13A - Control Room Booster Fan
- 6. Containment Spray Isolation Valve (MV-07-161)
- 7. 2A LPSI Pump Suction valve (V-3432)
I l -l
Pega 17 of 36 ST. LUCIE UNIT NO. 2 EMERGENCY OPERATING PROCEDURE. NUMBER 2-0030141, REVISION 0 CONTROL ROOM INACCESSIBILITY f,~ ~%, [ s r% i APPENDIX "A" (continued) 6ei-? j ISOLATION SWITCHES
/ jf
,h ,.
480V Load Center 2B2 - Auxilia,ry Building Electrical Equipment Room
- 1. SS Transformer 2B2
- 2. Bus Tie to 480V L.C. ZAB
- 3. Containment Fan Cooler 2HVS-lC
- 4. Contaimment Fan Cooler 2HVS-lD
- 5. 2B Charging Pump O
Pago 18 of 36 ST. LUCIE UNIT NO. 2 EMERGENCY OPERATING PROCEDURE NUMBER 2-0030141, REVISION O CONTROL ROOM INACCESSIBILITY pg,
.?
) [) '
ca.nni APPENDIX 'A" (continued) ,,/
/p r ISOLATION SWITCHES JN #
J~ f M 1 4160V SWGR 2B3 - Auxiliary Building Electrical Equipment Room
- 1. Feed from 23 Emergency Diesel Generator
- 2. Feed to 480V SS Transformer 2B2
- 3. Pressurizer Heater Transformer 2B3
- 4. CEDM Cooling Fan 2HVE-218
- 5. 2B Component Cooling Water Pump
- 6. 2B HPSI Pump
- 7. 2B LPSI Pump
- 8. 2B Containment Spray Pump
- 9. Feed to 4160V Bus 2AB
- 10. Feed from 4160V Bus -2B2
- 11. 2B Intake Cooling Water Pump
- 12. 2B Auxiliary Feedwater Pump i
i l i 1 0
Pegs 19 of 36 ST. LUCIE UNIT NO. 2 EMERGENCY OPERATlXO PROCEDURE NUMBER 2-0030141, REVISION O CONTROL ROOM INACCESSIBILITY
.. es
? %
i i") i APPENDIX "A" (continued) .g..J j l ISOLATION SWITCHES 4'
#Z 480V MCC 2B6 - Auxiliary Building Electrical Equipment Room #
- 1. 2HVE-6B - Shield Building Exhaust Fan
- 2. 2HVA-3B - Control Room Air Conditioner
- 3. 2HVE-13B - Control Room Booster Fan
- 4. Containment Spray Isolation Valve (MV-07-164)
- 5. 2B LPSI Pump Suction Valve (V-3444)
.i l l l
Pags 20 of 36 ST. LUCIE UNI'C NO. 2 . EMERGENCY OPERATING PROCEDURE .V,MBER 2-0030141, REVISION O CONTROL ROOM INACCESSIBILITY y = " %g fl 3
'd i
.l APPENDIX 'A" (continued) gf ISO MTION SNITCHES .[
_y 5_ _= 480V MCC 2B5 - Auxiliary Building Electrical Equipment Room
- 1. Boric Acid Gravity Feed Valve (V-2508)
- 2. Boric Acfd Gravity Feed Valve (V-2509)
~
- 3. 2B AFW Pump Dischar3e to 2B Steam Generator (MV-09-10)
- 4. 2A Steam Cenerator to 2C AFW Pump Turbine (MV-08-13)
- 5. CCW to Containment Fan Cooler 2HV5-1C (MV-14-13)
- 6. CCW to Containment Fan Cooler 2HVS-lD (MV-14-14)
- 7. CCW to Containment Fan Cooler 2HV5-1D (MV-14-15)
- 8. CCW to Containment Fan Cooler 2HV5-ID (MV-14-16) 1 0
,~ - --
~
rega 21 of 36 ST. LUCIE UNIT NO. 2 . EMERGENCY OPERATING PROCEDURE NUEEER 2-0030141, REVISION 0 , CONTROL ROOM INACCESSIBILITY
?>:r 11
/
APPENDIX "A" (continued)
,, l i)
ISOLATION SWITCHES s[/ # 480V MCC 2AB - Auxiliary Building Electrical Equipment Room l/ 1 --!
- 1. 2KVA-3C- Control Room Air Conditioner, Indoor Unit
- 2. CCW Discharge Valve - A Edr. (NV-14-1)
- 3. CCW Discharge Valva - 3 Hdr. (MV-14-2)
- 4. CCW Discharge Valve - A Hdr. (MV-14-3)
- 5. CCW Discharge Valve - B Edr. (XV-14-4)
W e
Pega 22 of 36 ST. LUCIE UNIT NO. 2 EMERGENCY OPERATING PROCEDURE NUMBER 2-0030141, REVISION 0 CONTROL ROOM INACCESSIBILITY f"% r
? f% ?S APPENDIX "A" (continued) fj j J #
ISOLATION SWITCHES f / U / '.Y
; bT Isolation Panel 2AB - Auxiliary Building Electrical Equipment Room d - - -
- 1. 2C Auxiliary Feed Pinap Stop Valvs (MV-08-3)
D w O e
A Pega 23 of 36 ST. LUCIE UNIT NO. 2 . EMERGENCY OPERATING PROCEDURE NUMBER 2-0030141, REVISION 0 CONTROL ROOM INACCESSIBILITY
..eg
- k E\
-- 1, APPENDIX "A" (continued) ' "-* y, sf ISOLATION SWITCHES
;<j /'!
2 1
'm 1 Isolation Panel 2A - Auxiliary Building Electrical Equipment Room
- 1. SS-1-189 - Auxiliary Syray Valve (I-SE-02-3)
- 2. SS-1-157 - Letdown Containment Isolation Valve (V-2516)
- 3. SS-1-176 - Charging to Loop 2A2 (I-SE-02-02)
- 4. SS-194 - Charging Line Isolation Valve (V-2523)
- 5. 2A Steam Generator Atmospheric Steam Dump PIC-08-1A1 (2 switches)
- 6. 28 Steam Generator Atmospheric Steam Dump PIC-08-3Al
- 7. 2A Diesel Generator Watt / Volt Meter -
- 8. 2C AFW Pump Discharge to 2B Steam Generator (MV-09-12)
O 9 0
r Pegs 24 of 36 ST. LUCIE UNIT NO. 2 EMERGENCY OPERATING PROCEDURE NUMBER 2-0030141, REVISION O _Q0NTROL ROOM INACCESSIBILITY
, "~% ,
^
1 ) APPENDIX "A" (continued) b [ Af r
, ISOLATION SWITCHES
.>/
M4
; 3 Isolation Panel 2B - Auxiliary Building Electrical Equipment Room
- 1. SS-2-189 - Auxiliary Spray Valve (I-SE-02-04)
- 2. SS-2-157 - Letdown stop Valve (V-2515) .
- 3. SS-2-176 - Charging to Loop 2B1 (I-SE-02-01)
- 4. SS-1-194 - Letdown Containment Isolation Valve (V-2522)
- 5. 23 Steam Generator Atmospheric Steam Dump PIC-08-1B1 (2 switches)
- 6. 28 Steam Generator Atmospheric Steam Dump PIC-08-3B1
- 7. 2B Diesel Generator Watt / Volt meter
- 8. 2C AFW Pump Discharge to 2A Steam Generator (XV-09-11) 4 e
O
Paga 25 of 36 ST. LUCIE UNIT NO. 2 EMERGENCY OPERATING PROCEDURE NUMBER 2-0030141, REVISION 0 i CONTROL ROOM INACCESSIBILITY
% 1 f q. . i APPENDIX "A" (continued) 3 j ISOLATION SWITCHES ,/
r Communications Isolation Panel - Auxiliary Bailding Communications Room
!a
~
1
~
- 1. Fire Alarm / Site Evacuation - Control Console, Isolation Switch
- 2. Control Room PA Isolation Switch
- 3. Code Call Isolation Switch k
e 9 0 0
, - - - - , , . - - . . , , - , . - , - - - . ~ . - . - - + . - - , . - , - - - , . , - -
n , , -,- ..-.-.-
Paga 26 of 36 ST. LUCIE UNIT NO. 2 . EMERGENCY OPERATING PROCEDURE NUMBER 2-0030141, REVISION O CONTROL' ROOK INACCESSIBILITY
.. w. .,
Ln i APPENDIX "A" (continued)~ 8) :t 3
^
j ISOLATION SWITCHES d i 4 L . ? 4160V SWGR 2A2 - Turbine Building Switchgear Room
- 1. Feed to 480V SS Transformer 2A1 2.
Feed to 4160V Bus 2A3
- 3. Feed from 2A4 SWGR I
^
l .i i f e i
,,,, . _ . . . , , , . . ~ . . . . , . o , ,- y. ... . - . . - -,, ,,._-._-,_..,.._s, -
Pega 27 of 36
. ST. LUCIE UNIT NO. 2 .
EMERGENCY OPERATING PROCEDURE NUMBER 2-0030141, REVISION O CONTROL ROOM INACCESSIBILITY l APPENDIX 'A" (continued) '9 ISOLATION SWITCHES . # V
$.?
f f 4 4160V SWGR 232 - Turbine Building Switchgear Room 'j 2
. r _ -->
- 1. Fced to SS Transformer 2B1
- 2. Feed to 4160V' Bus 2B3
- 3. Feed from 234 4160V Bus I
e O 4 v-,
l Pags 28 of 36 ST. LUCIE UNIT NO. 2 . EMERGENCY OPERATING PR0(4 DURE NUMBER 2-0030141, REVISION O ! CONTROL ROOM INACCESSIBILITY
,. P%-
') r s
N j APPENDIX "A" (continued)
" (' i
._ 9
,f C /
ISOLATION SWITCHES yf f k i *m
! E- !
6900V SWGR 2A1 - Turbine Building Switchgear Room
- l. Feed from Startup Transformer 2A i
i f 1 k 1 ) e _ . . . , . ~ , , . . . . . - , - . - . , , _ , - , . , - - e- ., --,--,._-m ,.
Paga 29 cf 36 ST. LUCIE UNIT NO. 2 EMERGENCY OPERATING PROCEDURE NUMBER 2-0030141, REVISION O CONTROL ROOM INACCESSIBILITY 3 i n APPENDIX "A (continued) l < ISOLATION SWITCHES 6900V SWGR 281 - Turbine Building Switchgear Room
- 1. Feed from Startup Transformer 2B 1
l e e 0
-.-y .- .c- ,- - -p9.. ---.- w
. s Pega 30 of 36 ST. LUCIE UNIT NO. 2 EMERGENCY OPERATING PROCEDURE NUMBER 2-0030141, REVISION 0 CONTROL ROOM INACCESSIBILITY " ' * "'%w s-i iR b Lej $ 1 APPENDIX "A" (continued) / /
ISOLATION SWITCHES d' e il Gm 1 -n.1 4160V SWGR 2AB - Auxiliary Building Ground Floor *
- 1. 2C Component Cooling Water Pump " Local" switch position
- 2. 2C Intake Cooling Water Pump " Local" switch position
- 3. Feed from 4160V Bus 2A3 .
- 4. Feed from 4160V Bus 233 l
.n . = , . - . -- - , . . . , . , - --., . - - ,
s
- a Pega M of 36 ST. LUCIE UNIT NO. 2 EMERGENCY OPERATING PROCEDURE NUMBER ?.-0030141, REVISION O CONTROL ROOM INACCESSIBILITY , e '"a, ,
r 5 [ 4 7M 1 j APPENDIX "A" (continued) Y
./
ISOLATION SWITCHES 4
/
5
=
-- _ _ a 480V Load Center 2AB - Auxiliary Building Ground Floor
- 1. Bus Tie to 460V L.C. 2A2
- 2. 2C Charging Pump
- 3. Bus Tie to 480V L.C. 2B2 O
e l l l 1
Pega 32 of 36 ST. LUCIE UNIT NO. 2 . EMERGENCY OPERATING PROCEDURE NUMBER 2-0030141, REVISION O CONTROL ROOM INACCESSIBILITY ,f " *g A ) l 1, 6 c APPENDIX "A" (continued)
~ 4' ISOLATION SWITCHES
/
'- M' _:
- 2A Diesel Generator Control Panel
- 1. - Voltage Control
- 2. Frequency Control
- 3. Start Circuit s
W G e 0
~ , e- - w,v,. ,-y,-. v--, ,n- ,. , , e,. -we -- - , - - - --.n. -, - . - -- - - --- - - . -
. I l
Pags 33 of 36 ST. LUCIE UNIT NO. 2 EMERGENCY OPERATING PROCEDURE NUMBER 2-0030141, REVISION O j CONTROL ROOM INACCESSIBILITY y-% 3 e4 . A 4'l k L: i i APPENDIX "A" (continued) g(I / ISOLATION SWITCHES jv i ,3 2B Diesel Generator Control Panel
- 1. Voltage Control
- 2. Frequency Control
- 3. Start Circuit 4
9 _ _ . . , _ - . . . . _ ,. . . _ , . _ . _ _ _ _ . _ -- ---~,
~
o .. Page 34 of 36 ' ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEWRE 2-0030141, REVISION O CONTROL ROOM INACCESSIBILITY - a
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Page 36 of 36 2 ST. I.UCIE UNIT 2 EMERGENCY OPERATING PROCEDURE 2-0030141,. REVISION O CONTROL ROOM INACCESSIBILITY
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Pcgs 1 of 12
~
OFF-NORMAL PROCEDURE 2-0030130 RE7 1 RT/TT
./ aury A 5 i'?. ;\
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.1
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I *- , f J! FLORIDA POWER AND LIGHT COMPANY ST. LUCIE PLANT UNIT 2 0FF-NORMAL OPERATING PROCEDURE NUMBER 2-0030130 REVISION 1 4 REACIOR TRIP / TURBINE TRIP OCTOBER 25, 1982 TOTAL NO. OF PAGES H 1 F0B IEFCO:]ni;0:100LV This document is not controtbd. Before use. t* I-{er--Mien with a controlled document.
- h. . . a ..... .u..--
_ _ , - _. , ,. , - - . .. , - . - - ~- ~ ' ,
- Prge 2 of 12 RT/TT FLORIDA POWER AND LIGHT COMPANY ST. LUCIE PLANT UNIT 2 0FF-NORMAL PROCEDURE NLHBER 2-0030130 ps REVISION 1 [
g s #% = 1.0 SCOPE 5 13 3 w: ) ; This procedure provides guidelines for an operator fallowing a reactor J /
/
trip. The circumstances which contributed to the trip may require the y use of another procedure concurrent with or following this procedure. Ib.n
~
2.0 SYMPTOMS 2.1 Indications and annunciator alarms associated with any of the following trips: SYMPTOM INDICATION / ALARM 2.1.1 Hi power 2.1.1 Indication J1002A/004A, B, C, D, JR009/010 RPS - Ch. 1 TRilll/1121 Alarms L-9, L-17 2.1.2 Ri rate of change / power 2.1.2 Indication JK1-001A, B, C, D, RPS - Ch. 2 2.1.3 Lo RC Flow 2.1.3 Indications PD1-1101A, B, C, D, RPS - Ch. 6 Alarms L-10, L-18 2.1.4 Lo S/G level 2.1.4 Indications LIC-9013 A, B, C, D, LIC-9023 A, B, C, D, L2-9011/9021 RPS - Ch. 7 Alarms L-3, L-11
Paga 3 of 12 0FF-NORMAL OPERATING PROCEDURE NLMBER 2-0030130 RT/TT-REVISION 1 f (#1 1 2.0 SYMPTOMS (Cont.) Ydi j f-
?
j.p? j/ 2.1 (Cont.) v # 2.1.5 to S/G Pressure 2.1.5 Indications # I FI-08-1A, 1B, PR-08-1, 2,
- 3 RPS - Ch. 8 PI-8013A, B, C, D, (RTG3 206)
PI-8023A, B, C, D, (RTG3 206) Alarms L-19, L-27 2.1.6 Local Power Density 2.1.6 Indications JR-012, J0-012-1 JI-005A, B, C, D. JI-006A, B, C, D. RPS - Ch. 3 Alarms L-22, L-30 2.1.7 Thermal margin / low pressure 2.1.7 Indications PIA-1102A, B, C, D, RPS - Ch. 4 . Alarms
.L-36, L-41 2.1.8 Hi Pressurizer Pressure 2.1.8 Indications PI-1102A, B, C, D, PR-1100 PIC-1100X/Y RPS - Ch. 5 Alarms L-20, L-28 2.1.9 Ri Containment Pressure 2.1.9 Indications PIS-07-2A, 2B, 2C, 2D.
PI-07-4A/5A PR-07-4B/5B Alarms L-5, L-13
Pega 4 of 12 0FF-NORMAL OPERATING PROCEDURE NUMBER 2-0030130 RT/TT REVISION 1 2.0 SYMPTOMS (Cont.)
. .r f"% :.
5 Ek. 5 2.1 (Cont.) 3 4 a
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./
2.1.10 Turbine trip 2.1.10 Indications 4'
#a WM-881 .# gf DtN-881 W-REC-881 RFS - Ch. 10 l7{ /
e 1 DEU - SYSTEM Alarms L-21, D-8 2.1.11 Low CCW Flow to RCP's 2.1.11 Indications (<636 GPM > 10 min.) FIA-1158, 1168, 1178, 1188 RPS - Ch. 11 FIS-14-1A, 1B Alarms L-6, L-14 2.1.12 Turbine overspeed 2.1.12 Indications RFS - Ch. 10 DEH - SYSTEM
!N-881 -
Alarms D-5, L-21 2.1.13 Condenser low vacuum 2.1.13 Indications RPS - Ch. 10 PI-10-7A, 7B Alarms D-3, L-21, D-13 2.1.14 Thrust bearing failure 2.1.14 Indications RPS - Ch. 10 TR-22-1 Alarms D-6, D-16 R1 i e
Pego 5 of 12 0FP-NORMAL OPERATING PROCEDURE NUMBER 2-0030130 RT/TT REVISION 1 2.0 SYMPTOMS (Cont.) 2.1 (Cont.) [ , j 2.1.15 Generator Lockout 2.1.15 Indications b-= l k RPS - Ch. 10 *g' r,
/
AM 881 AM 872 VM 872 f.I -
,Y 1 4 Alarms D-7 2.1.16 Exhaust Hood Righ Temp 2.1.16 Indications RPS - Ch. 10 TR-22-6 Alarms D-4, D-14 2.1.17 Turbine Bearing 011 Pressure 2.1.17 Indications RPS- Ch. 10 PI-22-25 Alarms D-2, D-12 ,
2.1.18 Auto-Stop 011 Pressure 2.1.18 Indications RPS - Ch. 10 PI-22-25, 26 Alarms D-7, D-17 2.1.19 Righ S/G Level 2.1.19 Indications LIC-9013 A, B, C, D LIC-9023 A, B, C, D LR-9011/9021 RPS - Ch. 12 (FUTURE) Alarms L-7, L-7, (FUTURE) G-1, G-9 2.1.20 DEH DC Bus Failure 2.1.20 Alarms D-19 R1
Pass 6 of 12 0FF-NORMAL OPERATING PROCEDURE NUMBER 2-0030130 AT/TT REVISION 1
/* ,..
-f 1 k
2.0 SYMPTOMS (Cont.) :.s.; ("f l1 aY , 2.1 (Cont.) , f, 7 f e7 2.1.21 Manual Trip 2.1.21 Indications f j ,',, All CEA's fully inserted! d ADS, DE3- SYSTEM W-REC-871 DMW-871 Core Mimic Digital Position Readout Alarms L-1, D-10 NOTE: In every case where a reactor trip occurs, the following alarms should also energize, K-1, -2, -3, -4, -5,
-9, -10, -12, -13, (RT3's)
If they do not,.this could be an indication of ATWS 2.2 Reactor Trip Breakers OPEN 2.2 Indications ' RPS Alarms IF1, -2, -3, -4, -5, -9, -10,
-12, -13 2.3 CEA's Insert 2.3 Indications ADS, Core Mimic, Digital Position Readout, and Backup 2.4 Generator NW Output Reduces to Zero 2.4 Indications
. DEH, W-REC-871 DMW-871, RPS - Ch. 10 Alarms .
D-21, D-8 2.5 After trip, the following Parameters: Reactor Power - Decrease Pressurizer Pressure - Decrease Pressurizer Level - Decrease RCS Temperature - Decrease Steam Generator Pressure - Increase Steam Generator Level - Decrease R1
Page 7 of 12 OFF-NORMAL OPERATING PROCEDURE NUMBER 2-0030130 RT/TT REVISION 1 3.0 AUTOMATIC ACTIONS # 4 cs 3.1 The turbine generator will trip with i"Ei l EITHER_ i A Turbine Trip Signal set j A Reactor Trip Signal 3.2 The reactor will trip with EITHER A Reactor Trip Signal S.E A Turbine Trip Signal and Power is > 15% 3.3 Plant electrical auxiliaries transfer from auxiliary to SU transformer. 3.4 S/G 1evel j( 39% narrow range (2 out of 4 channels) automatic initiation of auxiliary feedwater sys. 3.5 Atmospheric Dumps and/or SBCS actuate following a trip. 3.6 Turbine trip on Hi S/G level will also CLOSE 100% feedwater bypass valves. R1 O
Pags 8 of 12 0FF-NORMAI. OPERATING PROCEDURE NW3E2 2-0030130 RT/TT REVISION 1 4.0 IMMEDIATE OPERATOR ACTIONS Q a r 4.1' Manually depress both Reactor Trip . 5 Shlg P.B.'s on RTGB 201 or 204 and ensure bM Reactor Trip Bkrs. are open. g/ J NOTE: If the conditions for a Reactor Trip are #
/r/I
/
present, and the Reactor has not tripped, refer I ' J immediately to GP 2-0030132 (ATWAS) 4.2 Manually depress Turbine Trip P.B. on RTCB 201, ensure all G.V.'s and T.V.'s - Close. , 4.3 Ensure all CEA's are fully inserted. If more than one CEA is not fully inserted, initiate Emergency Boration per op #2-0250030. 4.4 Close reheater block valves (MV-08-4, 6, 8 and 10). 4.5 Ensure Gen. OCB's and Gen Field Bkr are open. . 4.6 Ensure that auxiliary power has tranferred to the Startup Transformers. OR D/G 2A and/or D/G 23 are running with their output Bkrs closed carrying only the emergency buses. Note: In the event of a complete loss of-offsite pwr, refer immediately to op #2-0030140, " Blackout Operation". e 4.7 Ensure main feedwater flow to S/G's through 15% valves, OR Ensure aux feedwater initiated. 4.8 Ensure that Tave is being maintained j at 532 F by SBCS or Atmos Dumps. R1 l
Prgs 9 of 12 0FF-NORMAL OPERATING PROCEDURE NUMBER 2-0030130 RT/1"' REVISION 1 (" 5.0 SUBSEQUENT ACTIONS *
- 1
- .ca' y }
CHECK ,f' j/
*i* f 5.1 Consult break diagnostic chart (Fig. 1) and determine /,/ j7 if another emergency procedure is required. If so, j -
immediately refer to that procedure; if not, proceed 2 4 to Step 5.2 5.2 Reverify (using check list) all immediate actions have occurred. 5.3 If trip was caused by High Pressurizer Pressure, verify the PORV's are CLOSED or isolate manually when pressure <2300 psia. CAUTION Do not overfeed the S/G's. This could cause Tavg to go below 532 0 F and thermal shock the S/G's. 5.4 Place the feedwater bypass valves in the " auto" position to maintain no load levels. - 5.5 If the emergency diesels are running, START both motor driven auxiliary fw. pumps and maintain S/G level 5.6 If both the S/G feed pumps and motor driven auxiliary FW pumps are inoperable, then START steam driven auxiliary,fw pump. CAUTION-Feed should be diverted from any S/G showing abnormally low steam pressure or high feed flow. 5.7 Ensure pressurizer level is being returned to setpoint by auto control of charging pumps and letdown control valves. If not, take manual control. 5.8 Ensure pressurizar pressure is being controlled automatically by the heaters and spray valves. If not, take manual control. R1
l l Pega 10 of 12 l 0FF-NORMAL OPERATING PROCEDURE NUMBER 2-0030130 RT/TT REVISION 1 ; 5.0 SUBSEQUENT ACTIONS (Cont.) i . fr CHECK ,, j l 3 5.9 If steam pressure cannot be maintained above 800 fj psig, CLOSE MSIV's or atmospheric dump valves, ,f ,
/
as appropriate, to avoid excessive cooldown and . l- jr depressurization of the RCS. . jf g,,, , 5.10 Verify shutdown margin. If it is below Tech - Specs, emergency borate 5.11 As the turbine slows down, ensure the bearing oil pumps START as follows or manually START, if required: 5.11.1 AC bearing oil pump and seal-oil backup pumps START together @ 11-12 psig 5.11.2 Emergency D.C. oil pump @ 10-11 psig 5.11.3 Bearing oil lift pump starts when turbine reaches'600 RPM __ 5.12 Ensure at 0 RPM the turning gear engages. 5.13 Place turbine drain selector to OPEN CADTION Do not isolate steam to gland seals as long as condenser vacuum is maintained. CHECK 5.14 Reduce bearing oil temperature to 900F - 100 0F. 5.15 la the event the condense'r is not available, evaluate condensate storage tank inventory. 5.16 If it is unsafe to maintain the plant in hot standby condition; bring the unit to cold shutdown per OP f2-0030127 5.17 If immediate recovery and return to power is planned, commence CEA block circuit check, if required (see OP #2-0030122 Para. 8.6, Reactor Startup). NOTE If RCP's have tripped, they may be restarted if it has been confirmed that a LOCA has not occurred, pump services CAN be restored and RCS pressure-temperature conditions permit restart. R1
i CFF-NOR>fAL OPERATING PROCEDURE NUMBER 2-0030130 Page 11 of 12 REV1SION 1 RT/TT FIGURE l BREAK DIAGNOSTIC CHART . -m-
., ,3 , ,
i.cd a ! 4 l} . i IF _ PRESSURIZER LEVEL CHANGING f
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AND I PRESSURIZER PRESSURE RAPIDLY DECREASING i
! AND STEAM GENERATOR PRESSURE o ,
ABNORMALLY LOW IN ONE' OR NORMAL OR RISING $ BOTH STEAM. GENERATORS _ U THEN
- FEEDWATER OR STEAM LINE BREAK LOCA
- [
ANDIF ANDIF CONTAINMENT PRESSURE' CONTAINMENT PRESSURE A A 4 o UP NORMAL UP NORMAL 9 AND CONTAINMENT THEN THEN M RADIATlCN NO MS/FW SREAK MS/FW BREAK INCREASING IN CTMT CUTSIDE OF TNEN TH'N E MS=EP2-C810040 CTMT LOCA 3/G TUEE FW=EP2-0700040 MS=EP2-0810040
,FW=EP2-0700 M O EP2-Cl2OO41 RUPTURE EP2-Ol2OO4i
- MAY DECREASE SLIGHTLY AFTER REACTOR TRIP
Paga 12 of 12 0FF-NORMAL OPERATING PROCEDURE NUMBE2 2-0030130 AT/TT REVISION 1 6.0 PURPOSE / DISCUSSION This procedure provides the entry to a sequence of events that will lead to the safe termination of any of the emergency events considered for our plant. The first few Lamediate actions verify that all has performed as it should. The operator verifies CEA's in, or if not, is referred to the ATWAS procedure. He then verifies off-site power and if it is not available, he is referred to the Blackout Procedure. He then scans a Diagnostic Chart and, if necessary, is directed to the appropriate emergency procedures. Each of these emergency procedures will provide specific instructions for the particular circumstances and verify adequate core cooling, or if not, refer to the operator to the inadequate core cooling procedure. If no emergency conditions exist, the operator continues to the subsequent actions, which guide him to a safe shutdown and preparation for return to power, if conditions warrant.
7.0 REFERENCES
7.1 St. Lucie Unic #1 Off-Normal Procedures e, 7.2 St. Lucie Unic #2 FSAR, Sect. 7 'a'*""5l , 7.3 CEN 128, C.E. NSSS trans.ents & accidents AM 8.0 RECORDS REQUIRED
' ~ ~ ~
, 8.1 Normal log entries and trip details l 8.2 Startup/ Shutdown log entry 8.3 Reactor trip log entry 8.4 Applicable los chart recorders 9.0 AP?ROVAL Reviewed by the Facility Review Group October 12, 1912 Approved by C. M. Wethy Plant Manager _ October 14, 1982, Rev. / Facility Review Group i f - ?) ; 1944 Approved byreviewedby/bt._m'f\PlantManager l /f
*/
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. ATWS EMERGENCY PROCEDURE 2-0030132 Rev 1 ATWS f*,g M
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FLORILA POWER & LIGHT COMPANY ST. LUCIE PLANT UNIT 2 EMERGENCY PROCEDURE NUMBER 2-0030132 REVISION 1 ANTICIPATED TRANSIENT WITHOUT SCRAM (ATWS) OCTOBER 25, 1982 J TOTAL NO. OF PAGES 5 i
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. ATUS FLORIDA POWER & LIGHT COMPANY ST. LUCIE PLANT UNIT 2 4^,
EMERGENCY PROCEDURE NUMBER 2-0030132 :7
}
(ATWS) REVISION 1 3
} s
.v 1.0 SCOPE f,//
I 5 This procedure provides instructions to be used in the event of an ATWS. The transients which produce most limiting ATWS consequences are covered by this procedure. 2.0 SYMPTOMS The following are symptoms related to the three transients; Loss of Feedwater (LOF), Loss of Offsite Power (LOOP), and stuck opan Relief
- Valve, which would cause a reactor trip. Any of these symptoms, not accompanied by insertion of all CEA's, as indicated by the ADS, Core Mimic, Digital Position Readout, Backup readout and core power indication are an indication of ATWS
TRIP SIGNAL GENERATED BY: STUCK SYMPTOM LOF LOOP OPEN PORY INDICATION / ALARM 2.1 High Przr Yes Yes No 2.1 Indications Pressure PI-lLO2A, PI-1102B, PI-1102C, PI-1102D PR-1100 PIC-1100X, PIC-1100Y RPS - Channel 5 2.1 Alarms L-20, L-28 2.2 TM/LP No No Yes 2.2 Indications i FIA-1102A, PIA-1102B, PIA-1102C, PIA-1102D
, RPS - Channel 4 2.2 Alarms L-36, L-41
Page 3 of 5 ATWS EMERGENCY PROCEDURE NUMBER 2-0030132', REVISION 1 (ATWS) s d**'* A $") (
2.0 SYMPTOMS
(Cont.) } TRIP SIGNAL GENERATED BY: . ,f SYNTTOM LOF LOOP STUCK OPEN PORV INDICATION / ALARM g 1 {'*- , l' 2.3 Low RCS Yes Yes No 2.3 Indications Plow PDI-1101A, PDI-11013, PDI-1101C, PDI-1101D RPS - Channel 6 2.3 Alarms L-10, L-18 2.4 Low S/G Yes No No 2.4 Indications Level LIC-9013A, LIC-90138, LIC-9013C, LIC-9013D LIC-9023A, LIC-9023B, LIC-9023C, LIC-9023D LR-90ll, LR-9021 RPS - Channel 7 2.4 Alarms L-3, L-11 3.0 AUTOKATIC ACTIONS: , Some of the following Automatic Actions will occur during the various transients with the absence of a reactor trip: NOTE: Any Automatic Actions that should occur and do not, must be manually initiated. AUTOMATIC ACTION INITIATING EVENT 3.1 Turbine Trip 3.1 If reactor trip SHOULD EAVE occurred 3.2 AFW Auto Start 3.2 39% narrow ranSe inst.'s (2 out of 4 channels) R1 3.3 PORY Actuation 3.3 RCS pressure @ 2375 PSIA R1 3.4 Main Steam Safety Valves Open 3.4 S/G pressure > 985 PSIG ,
,R1
- 3.5 SBCS Actuation 3.5 Turbine Trip or High S/G pressure 3.6 Generator OCB's Open 3.6 Turbine Trip 6
Pega 4 of 5
, ATWS EMERGENCY PROCEDURE NUMBER 2-0030132, REVISION 1 (AIWS)
O-3.0 AUTOMATIC ACTIONS: (Cont.) b m ,3 ; AUTOMATIC ACTTON_ INITIATING EVENT 3.7 SIAS and CIAS 3.7 RCS pressure 1600 PSIA if Containment pressure 5 PSIG f , 3.8 CSAS 3.8 ~ Containment pressure 10 PSIG 4.0 IMMEDIATE OPERATOR ACTIONS LOCATION 4.1 Verify required Auto Actions have occurred or manually initiate. 4.2 Trip Turbine 4.2 RTGB 201 4.3 Ensure AFW Flow 4.3 RTGB 202 4.4 Trip Reactor 4.4 RTGB 201 or 204 4.5 Emergency Borate 4.5 RTGB 205 AND IF CEA'S DON'T DROP 4.6 Open RTB's locally 4.6 Cable spreading, room 4.7 Stop both M-G sets at 4.7 RAB 19.5' Elev. the M-G s'ets or by opening (M-G sets) Breakers 2-40212 and 2-40511 RAB 43' Elev. L.C. 2A2/2B2 (Breakers to M-G sets) AND IF CEA'S DON'T DROP 4.8 Rc-energize CEA bus with either M-6 set. 4.9 Manually Insert CEA's 4.9 RTGB 204 AND 4.10 Emer3ency torate by opaning 4.10 RTGB 205 '* MV-2514 and starting BA pumps 2A and 2B 4.11 Stop M-G sets either at M-G 4.11 Locally in RAB set or at breaker 2-40212 and 2-40511 4.12 Return to 2-0030130, Reactor Trip / Turbine : rip,. Immediate Operator Actions to determine type of transient and further action required. R1 ~ 5.0 SUBSEQUENT ACTIONS: ,
Page 5 of 5
. ATWS EMERGENCY PROCEDURE NUMBER 2-0030132, REVISION 1 (ATWS) -
( , None , d 7f I //
6.0 DISCUSSION
This procedure starts and ends during a transient. For this reason, there is no subsequent action. The last immediate action is to refer to
./'L'I
{ _ _ , . the Reactor Trip / Turbine Trip procedure and from there determine the course of action to take.
7.0 REFERENCES
7.1 Memorandum from Frank Schroeder to Robert L. Tedesco, dated June 23, 1980 . 7.2 CE Emergency Procedure Guidelines, CEN-152 7.3 St. Lucie #L Off-Normal Operating Procedures 8.0 RECORDS REQUIRED: 8.1 Normal Log Entries
9.0 APPROVAL
Reviewed by the Fa.cility Review Group October 12, .1982 Approved by l l N ide t ..,- (N iant Manager M jc 19d O Rev. reviewed by Facility Review Group 19 _ Approved by Plant Manager 19 _
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FLORIDA POWER & LIGHT COMPANY g .. ST. LUCIE PLANT UNIT NO. I. / / ' c/ hts- OPGLATlHG PROCEOJtE 2-0:UC/g REVISION NO. g /
,j'#,/
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- 1. TITLE: 40/)/ (0$$ Of JC hCoJW
- 2. PREPARED BY: 0. du/wr/ /C-jd 19 82.
- 3. SUBCOMMITTEE REVIEW BY: [ 42d([ For FP&L /d-S(a 19 8k
- 4. RIVIEWED BY FRG ON: te.-c r J C 19 s 2-
- 5. APPROVED BY [M ,f i ( ,m ' P M MANAGER [h7 7 6 19 J A.
./
i
- 6. REVISION REVIEWED BY FRG ON: 19 1
- 7. APPROVED BY: PLANT MANAGER 19 i
i N. F , v i Q $ l ..i: C' ' ' _;, ..- .. .... ; q. oL1 pa -t~ *?0-;I This document 1: rei c:nt:a!l:d. 3c'ere ess, I verify int:rmatica wi;h a contre!!ad document.] i . I f i i t
Page 1 of 9 TLOP EMERGENCY PROCEUDRE 2-0030143 REV. O TLOP f 6 - J.5 t*
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+
+1 4
_ __m FLORIDA POWER & LIGHT COMPANY ST. LUCIE PLANT UNIT 2 EMERGENCY PROCEDURE NUMBER 2-0030143 REVISION O TOTAL LOSS OF AC POWER (TLOP) OCTOBER lj, 1982 i l TOTAL NO. OF PAGES 9 4 3 . This Jc ::m:n; i. :.c; e n' ' ': ? :- :e , i verify i,f mstica wi:h a . 2 a flaJ dsa.r-.. l-I i .j l 1 I
Pegs 2 of 9 FLORIDA POWER & LIGHT COMPANY TLOP ST. LUCIE UNIT NO. 2 EMERGENCY OPERATING PROCEDURE NUMBER 2-0030143 REVISION 0 / LT 1
1.0 SCOPE
This procedure is to be used in the event of a total loss of both offsite f 9
. AC power, and loss of both diesel generators. L _
1
2.0 SYMPTOMS
2.1 Loss of power to 2Al, 2B1 6.9 KV Bus. 2.2 Loss of power to 2A2, 2A3, 2B2, 2B3 and 2AB 4.16 KV Bus. 3.0 AUTOMATIC ACTIONS: ACTION INITIATING EVENT 3.1 Reactor Trip. 3.1 Low RCS Flow 3.2 Turbine Trip / Generator Lockout 3.2 Reactor Trip 3.3 Auxiliary Feedwater Auto Actuation. 3.3 Low S/G Level 0 39% 3.4 PORV's Operate. 3.4 Hi Pressurizar Press
; O 2375 PSIA .
i a e S
i . Page 3 of 9 TLOP ST. LUCIE UNIT NO. 2 EMERGENCY OPERATING PROCEDURE NUMBER 2-0030143, REVISION O TOTAL LOSS OF AC POWER [fMg 4 J~ 4.0 DetEDIATE OPERATOR ACTIONS: 'bf; $ '
/
4.1 Insure all CEA's on bottom, and reactor trip breakers open. AI~ w l ! 4.2 Insure 2C Auxiliary Feedwater Pump is restoring Steam Generator level. 4.3 Close both of the main scsam isolation valves, HCV-08-LA and HCV-08-13. 4.4 Close letdown isolation valves V-2515, V-2516 and V-2522.
Page 4 of 9 TLOP ST. LUCIE UNIT NO. 2 EMERGENCY OPERATING PROCEDURE NUMBER 2-0030143, REVISION O j" g%, TOTAL LOSS OF AC POWER 0 5.0 SUBSEQUENT ACTIONS: yj1% h A e 5.1 Insure generator OCB's and field breaker open. d j/ 5.2 Open 2-30102 (S.U. Transformer to 2A1 6.9 KV bus). g,,,, Open 2-30202 (S.U. Transformer to 2B1 6.9 KV bus). g Open 2-20102 (S.U. Transformer to 2A2 4.16 KV bus). --ma Open 2-20302 (S.U. Transformer to 2B2 4.16 KV bus). 5.3 Insure D/G breakers open (2A-2-20211 and 23-2-20401). 5.4 Insure 2AB 4.16KV bus feeders are opan: 2-20208, 2-20505 (2A3 4.16KV to 2AB 4.16 KV bus). 2-20409, 2-20504 (233 4.16KV to 2AB 4.16 KV bus). 5.5 Open 2-40103 (2A2 4.16KV feed to 2Al L.C. - Ei side). Open 2-20110 (2A2 4.16KV feed to 2Al L.C. - Lo side). Open 2-40203 (2A3 4.16KV feed to 2A2 L.C. - Hi side). Open 2-20210 (2A3 4.16KV feed to 2A2 L.C. - Lo side). 5.6 Open 2-40403 (2B2 4.16KV feed to 2B1 L.C. - Hi side). Open 2-20310 (2B2 4.16KV feed to 2B1 L.C. - Lo side). Open 2-40503 (233 4.16KV feed to 2B2 L.C. - Hi side). Open 2-20402 (2B3 4.16KV_ feed to 2B2 L.C. - Lo side). . 5.7 Insure 2AB 480V Load Center Feeders are open: 2-40204, 2-40702 (2A2 480V L.C. to 2AB). 2-40706, 2-40504 (2B2 480V L.C. to 2AB). 5.8 Insure the main steam isolation bypass valves both indicate closed or dispatch an operator to locally take control and close the valves. NOTE: The handwheels on these valves turn counterclockwise direction to close, opposite of most valve handwheels in the plant. 5.9 Open 2A and 2B Atmospheric Dump Valves to reduce Steam Generator pressure below safety lift pressure. AC power to controllers will be lost, so DC operation of the valves will become necessary as below:
- 1. Take desired ADV auco/ man switch to MANUAL.
- 2. Modulate the dump valve open or closed with direct DC power with' the open/close control switch.
b
Page 5 of 9 TLOP ST. LUCIE UNIT NO. 2 EMERGENCY OPERATIN
G. PROCEDURE
NUMBER 2-0030143, REVISION O TOTAL LOSS OF AC POWER _ ,y,,
,1 .
5.0 SUBSEQUENT ACTIONS: (Cont.) ;1 qg , b i 5.10 Close FCV-23-3, 5, 4 and 6 (2A and 2B S/G Blowdowu Isolations). """") ,. ,-I 5.11 Close FCV-23-7 and FCV-23-9 (ZA and 2B S/G Blowdown Sample / Isolations). 5.12 Close A0V-5200, 5201, 5203, 5204 and 5205 (RCS Simple Isolations). _e,l 5.13 Implement the Emergency Plan as necessary in accordance with EP 3100021E, " Duties of the Emergency Coordinator." 5.14 Minimize atmospheric steam dump use thereby insuring mininum RCS heat loss; however,
- 1. Main S/G pressure less than S/G safety setpoint.
, 2. With decreasing RCS pressure, maintain hot leg temperature (Th) at least 200 F below the saturation temperature corresponding to the RCS pressure. 5.15 Verify by the following indications that natural circulation flow has been established within approximately 15 minutes after RCP's were stopped.
- 1. Loop Delta T less than normal full power Delta T (< 46 DF).
- 2. Cold leg (Tc) constant or decreasing.
- 3. Hoc leg (Th) stable (i.e., not steadily increasing).
5.16 If RCS pressure decreases to 1700 psia, verify receipt of block permissive annunciator R-6 and block SIAS. 5.17 Notify system dispatcher of plant conditions and request most urgent priority in restoring off-site power. 5.18 If 2C Auxiliary Feedwater Pump is stopped or flow is lost, then:
- 1. Reinitiate auxiliary feed flow as soon as possible; however, do not exceed a flow race of 150 GPM per af fected Steam Generator.
- 2. Limit feed flow rate to 150 GPM per affected Steam Generator until continuous feed flow to the affected Steam Generator has been maintained for five minuces.
Page 6 o2 9 TLOP ST. LUCIE UNIT NO. 2 EMERGENCY OPERATING PROCEDURE NUMBER 2-0030143, REVISE 0N O TOTAL LOSS OF AC POWER g 5.0 SUBSEQUENT ACTIONS: (Cont.) 5.19 Use all available resources to restore one emergency diesel f / generator to operable status. /
- 1. (Insert techniques later) 4 ,
5.20 The following restoration sequence assumes "A" train power supply i .
-I:
is restored first.
- 1. Strip all vital and non-vital load center breakers in preparation for a systematic power restoration.
- 2. Energize 2A3 4.16KV bus by either:
- a. Starting 2A D/G and closing D/G breaker. Adjust and maintain voltage and frequency at 4.16KV/60 HERTZ.
or
- b. Close 2-20102 (S.U. Transformer to 2A2 4.16KV bus).
Close 2-20109 (2A2 4.16KV to 2A3 4.16KV bus). Insert sync plug and close 20209 (2A2 4.16KV to 2A3 4.16KV bus).
~
- 3. Energize 2A2 and 2A5 480V load centers:
- a. Close 2-40203 (2A3 4.16KV feed to 2A2 L.C. - Ei side).
- b. Close 2-20210 (2A3 4.16KV feed to 2A2 L.C. - Lo side).
- c. Close- (2A5 4.16KV feed to 2A5 L.C. - Lo side).
- 4. Energize 2AB 480V Load Center by closing 2-40204 and 2-40702 I
(2A2 480V L.C. feed to 2AB L.C.) l l 5. Energize 2A5, 2A6, 2A7 and 2A8 480V MCC's as follows: l
- a. Close 2-40214 (2A2 480V L.C. feed to 2A5 MCC).
I I b. Close 2-40219 (2.'2 480V L.C. feed to 2A6 MCC).
- c. Close 2-40219 (2A2 480V L.C. feed to 2A7 MCC).
- d. Close 2-40215 (2A2 480V L.C. feed to 2A8 MCC).'
Page 7 of 9 TLOP ST. LUCIE UNIT NO. 2 EMERGENCY OPERATING PROCEDURE NUMBER 2-0030143, REVISION O TOTAL LOSS OF AC POWER 5.0 SUBSEQUENT ACTIONS: (Cont.) em ( 5.20 (Cont.) 1 ,l
- 6. Energize non-essential sections of 2AS, 2A6 and 2A8 MCC's as Jf follows: ,
- a. Close 2-41230 (MCC 2A5 non-essential breaker). A
- b. Close 2-41325 (MCC 2A6 non-essential breaker).
- c. Close 2-41513 (MCC 2A8 non-essential breaker).
- 7. Insure 2A battery charger is "0N LINE" supplying the 2A DC bus by observing 2A DC bus voltage on RTGB-201 to be greater than 120V DC.
- 8. Align and start emergency cooling water to the instrument air compressor. Start the 2A instrument air compressor and observe restoration of instrument air pressure.
- 9. Start the 2A charging pump to reestablish pressurizer level.
When the CCW system has been restored per step 15, then 2A HPSI pump can also be started to augment refilling of the pressurizer. ,
- a. Evaluate RCS temperature, pressure, and level instrumentation to determine if a bubble exists other than in the Pressurizer.
- b. If evaluation confirms, then conticue charging to increase RCS pressure.
- c. When greater than 200 F subcooled, operate Charging and/or HPSI pumps to maintain Pressurizer level greater than 30%
level.
- 10. Insure closed 2-20204 (Pressurizer heater transformer 2A 4.16V feed).
- 11. When pressurizer level indicates greater than 30%, energize pressurizer heaters B-1, B-2, B-3 and P-1.
- 12. Ensure ICW seal water from Unit 1 Domestic Water System is available.
i e e
.,., . _ , _.y - _ - _ . - - - .
_.m.._ 7__
Pegs 8 of 9 TLOP ST. LUCIE UNIT NO. 2 EMERGENCY OPERATING PROCEDURE NUMBER 2-0030143, REVISION 0 TOTAL LOSS OF AC POWER e 5.0 SUBSEQUENT ACTIONS: (Cont.) S 5.20 (Cont.) LJg b
- 13. Reestablish "A" train Intake Cooling Water System as follows: ,
- a. Establish seal water. <[
- b. Throttle 2A ICW pump discharge valve. -I
- c. Start 2A ICW pump; pressurize and vent "A" ICW header.
- d. After* venting, open 2A ICW pump discharge valve.
- 14. Reestablish "A" train Component Cooling Water System as follows:
- a. Isolate CCW to RCP's by closing RCV-14-1, 2, 6 and 7 ~
(to prevent thermal shocking RCP seals)
- b. Throttle 2A CCW pump discharge valve.
- c. Insure surge tank at normal level.
- d. Start 2A CCW pump; pressurize and slowly open 2A CCW pump, discharge valve.
- 15. Reestablish CVCS letdown to maintain Pressurizer level ~at-normal cperating level.
- 16. Commence boration to Cold Shutdown boron concentration.
- 17. Start one set of cavity and support cooling fans.
- 18. Proceed to E0P 2-0120040, " Natural Circulation /Cooldown",
step 5.3.9, and lerform in conjunction with the balance of this procedure.
- 19. Restore balance of secondary plant in accordance with E0P 2-0030140, " Blackout Operation".
s S ~ i.
\+
- Pegs 9 of 9
. TLOP ST. LUCIE UNIT NO. 2 EMERGENCY OPERATING PROCEDURE NUMBER 2-0030143, REVISION O TOTAL LOSS OF AC POWER .g
6.0 DISCUSSION
- i A r.
b
; ,ii 3 The " Total Loss of AC Power" event consists of a loss of off-site power in conjunction with failure of the Emergency Diesel Generators to provide .
energency power. This results in a loss of all AC electrical power ;f' except that provided by inverters powered from the vital DC busses. The y g,,, termination of AC poner causes a loss of forced reactor coolant flow, 3 a main feedwater flow, steam flow to the turbine and prassurizer pressure 6------ d control. The reactor trips on either low reactor coolant flow, high reactor coolant system (RCS) pressure or low steam generator level depending on initial conditions. The " Total Loss of AC power" event also causes a loss of all reactor coolant system makeup capability which includes charging and safety injection flow. Inventory losses through leakage, reactor coolant pump controlled bleedoff, and primary relief valve releases are the major contributors to the degradation of pressure and level ecutrol during the event. The other contributor to coolant system shrinkage and pressure reduction is system heat loss, primarily through the pressurizer walls. Core heat removal is accomplished through natural circulation. Reactor coolant system heat removal is accomplished using atmospheric dump valves and the steam driven auxiliary feedwater pump.
7.0 REFERENCES
7.1 CE Emergency Procedure Guidelines, CEN-152 7.2 St. Lucie #1 Off-Normal Operating Procedures 8.0 RECORDS REQUIRED: 8.1 Normal Log Entries
9.0 APPROVAL
Reviewed by the Facility Review Group bD ' 1981 Approved by _ /1 /M.1,v+E7 v i Plant Manager i f-- t .s. 195 Rev. Reviewed by Facility Review Group 19__ Approved by Plant Manager 19__
"L A S T P A G E" EP 2-0030143 REV. O TOTAL NO. OF PAGES 9 .e v Ww , m mm
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p e".e . FLORIDA POWER & LIGHT COMPANY l[ .g 'j ST. LUCIE PLANT UNIT NO. 2 '
- t. { .
EMERGENCY OPERATING PROCEDURE 2-0120040 '" d # REVISION NO. 0
.9 f
;f :ln- y i
4
- 1. TITLE: NATURAL CIRCULATION /COOLDOWN
- 2. PREPARED BY: H. Johnson 10/22 19H
- 3. SUBCCMMITTEE REVIEW BY: D. A. Sager For FP&L 10/25 19g
- 4. REVIEWED BY FRG ON: ..
r .e J 19 4
- 5. APPROVED BY: ) /./~ [h , , t -NPlant Manager ' ' - t O '- 19 O -
/
4
- 6. REVISION REVIEWED BY FRG ON: 19 _
- 7. APPROVED BY: Plant Manager 19 _
4
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~ FLORIDA POWER & LIGHT COMPANY Page 1 of 22 ST. LUCIE PLANT UNIT 2 EMERGENCY OPERATING PROCEDURE 2-0120040 REVISI N O
. rs,
1.0 TITLE
j NATURAL CIRCULATION /COOLDOWN #
2.0 APPROVAL
Reviewed by Facil4c Review Group [~~CN j[ 19 ) ) Approved by %/ d /, e r r j (Plant Manager t' r )( 192 l~ v Revision _ Reviewed by FRG 19 _ Approved by Plant Manager 19 _ 3.0 PURPOSE AND DISCUSSION: 3.1 Purpose
- 1. This procedure provides instructions to the operator in the event of a total loss of Reactor Coolant Pump (RCP) flow to the reactor core.
- 2. This procedure also provides guidance to the operator in the event that the plant must be cooled down using natural circulation flow.
3.2 Precautions - See Appendix A. . . . _ , .
.,....m. ,, .c e.- .
3.3 Discussion - See Appendix B. ,,,
; L:,.,, ,1 ' .1 e . a -
- i Thi: 1 u r - : ". M .E M '
4.0 SYMPTOMS
veri'y IMar : e' 2. a F * --
' - ~ ~ ~ ~ ~ ~ ~ ~ ~
4.1 Loss of off-site power. 4.2 Loss of or low voltage on 6.9 KV busses as indicated by:
- 1. 6.9 KV switchgear 2Al, 2B1 differential current trip.
- 2. 6.9 KV switchgear 2Al, 2B1 UNDERVOLTAGE alarm.
4.3 RCP OVERLOAD alarm. 44 REACTOR COOLANT LOW FLOW channel pre-trip alarm. 4.5 REACTOR COOLANT LOW FLOW CHANNEL trip. . 4.6 Loss of Component Cooling Water (CCW) flow to RCPs for greater than 10 minutes, requiring manual trip of all four pumps. 4.7 Valid SIAS-CIS caused by low RCS pressure, requiring all RCPs to be tripped af ter all control Element Assemblies have been inserted for 5 seconds.
. Page 2 of 22 ST. LUCIE UNIT 2 EMERGENCY OPE'1ATING PROCEDURE NUMBER 2-0120040, REVISION O NATURAL CIRCULATION /COOLDOWN
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l em
5.0 INSTRUCTIONS
[ 5.1 Automatic Action - *
- 1. Reactor coolant low flow reactor trip (Setpoint: 95% of full RCS flow).
f s_ 6 5.2 lamediate Operator Action 5.2.1 Carry out immediate operator actions for reactor trip in accordance with Off-Normal OP# 2-0030130. 5.3 Subsequent Actions 5.3.1 Implement the Emergency Plan as necessary in accordance with EPIP 3100021E, " Duties of the Emergency Coordinator". 5.3.2 Establish and maintain hot let temperature (T h ) at least 20 F below the saturation temperature corresponding to RCS pressure (refer to Figure 1) by doing the following:
- 1. Operate pressurizer heaters or auxiliary spray to increase or maintain pressurizer pressure, and to provide subcooling margin.
- 2. Increase turbine bypass or atmospheric steam dump flow to reduce or maintain RCS temperature and prevent lifting secondary safeties.
5.3.3 Verify that the pressurizar level control system is functioning to maintain pressurizer level. If necessary, manually operate charging and . letdown to restore and maintain normal pressurizer level. If operable charging pumps cannot restore RCS inventory and pressurizer level, observe RCS and containment parameters for indications of a LOCA. 5.3.4 Restore and maintain steam generator levels at approximately 65%. When feeding the steam generators ase caution to avoid excessively cooling the RCS, CAUTION: Do not exceed a cooldown rate of 750 F/hr.
. Page 3 of 22 ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE NUMBER 2-0120040, REVISION O NATURAL CIRCULATION /COOLDOWN
5.0 INSTRUCTIONS
(Cont.) [ h,,
/ #9 5.3 (Cont.) Q ' :l.
5.3.5 Verify the following indications that natural circulation j flow has been established within approximately 15 minutes - after_RCPs were tripped: 9,gf.7__
- l. Loop AT (Th - T e) les s than no rmal f ull power AT ( <46 0F) . d NOTE: The effective core AT with only one steam generator in operation.is determined at Th-Tc core where Te core = 2x (Tc operating loop) + Te non-operating loop 3
- 2. Cold leg temperatures (Tc) constant or decreasing.
- 3. Hot leg temperatures (Th) stable (i.e., not steadily increasing).
- 4. No abnormal differences between Th RTD's and core thermocouples.
5.3.6 Confirm boron concentration in the RCS by sampling from as many different points as possible. 5.3.7 Maintain the plant in a stabilized condition based upon auxiliary plant system availability (e.g., condensate inventory). 5.3.8 If one or more RCP's are restored to an operable condition within 10 sinutes, start an RCP in each loop if the following criteria are satisfied:
- 1. At least one steam generator is removing heat from the RCS.
I 2. Pressurizer level. and pressure are responding normally to the Pressurizer Level and Control System. 1 ! 3. The RCS is at least 20 0F subcooled (refer to Figure 1).
- 4. The yellow PERMISSIVE light on the asso;iated pump control switch is lit. -
l
- 5. No indication of voids in RCS are present.
l
- I I
i l l
,n. -
e
. Page 4 of 22 ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE NUMBER 2-0120040, REVISION O NATURAL CIRCULATION /COOLDOWN
5.0 INSTRUCTIONS
(Cont.) 5.3 (Cont.) 5.3.9 If all four RCPs can be returned to operable status within 10 minutes, power operation may be resumed under the direction of the Nuclear Plant Supervisor. If RCS cooldown is required under these conditions, the cooldown should be accomplished # using forced circulation. jf % 5.3.10 If required to conduct a plant cooldown to shutdown cooling (SDC) conditions using natural circulation, proceed as ko follows:
- 1. Establish as stable plant conditions as circumstances ,
permit. f,
- 2. Commence boration to maintain required SDH during cooldown.
- 3. Commence an RCS cooldown by utilizing one of the following methods:
- a. If the Condenser is available, use the Steam Dump Bypass System and Main or Auxiliary Feedwater.
- b. If the Condenser is not available, use the atmospheric dump valves and Main or Auxiliary Feedwater.
- 4. Continuously verify natural circulation flow throughout the c,ooldown process. -
- 5. Observe all available indications to determine conditions within the RCS.
- a. Use the Subcooled Margin Monitor (SMM) Th, Tc, and RCS pressure to verify that the RCS is subcooled.
- b. Figure 1 or the nomograph on RTGB-203 should be used for comparison with the SMM; subcooled margin can also'lue determined by subtracing Th from pressurizer temperature (TE-1101).
- c. Incore thermocouples, recorded on the DDPS, can also be used for indication of Th.
- 6. Establish and maintain a RCS cooldown race of 500 F/hr (See Figure 2). The highest RCS cold leg temperature shall be plotted every 30 minutes on a copy of Figure
- 4.
- The RCS temperature and pressure shall be determined to be within the limits of Technical Specification Figure 3.4-23 at least once per 30 minutes during cooldown.
l I
- Page 5 of 22 '
ST. LUCIE UNIT 2 l EMERGENCY OPERATING PROCEDURE NUMBER 2-0120040, REVISION O NATURAL CIRCULATION /COOLDOWN 5.0 INSTRUCTIONS; (Cont.) 5.3 (Cont.) 5.3.10 (Cont.) g,-===
- 7. The pressurizer water phase shall be recorded on Figure j")
5 and plotted every 30 minutes on Figure 4. f ', This e-me j temperature shall also be compared with the lowest spray of ,' water temperature to ensure that differential /- ',7 temperature does not exceed 350 0 F. /
- 8. Maintain RC3 pressure above and to the right of curve j- y values shown on Figure 3.
- 9. During the cooldown, maintain a mininum of 200 F subcooling by the following methods (listed in order of preference):
- a. Manual control of pressurizer heaters and auxiliary spray.
NOTE: Use only one charging pump.
- b. Operating. charging or HPSI pumps. -
- 10. During the cooldown, maintain pressurizar level by the following methods (listed in order of preference):
- a. Control charging and letdown.
- b. Operating HPSI pumps.
- 11. Monitor the available condensate inventory and replenish the CST as required.
CAUTION: CONDENSATE STORAGE TANK VOLUME SH/J.L BE MAINTAINED PER TECHNICAL SPECIFICATIONS 3.7.1.3.
- 12. During RCS cooldown and depressurization, perform the evolutions specified in Appendix C.
i
. Page 6 of 22 ST. LUCIE UNIT 1 EMERCENCY OPERATING PROCEDURE NUMBER 2-0120040, REVISION O NATURAL CIRCULATION /COOLDOWN
5.0 INSTRUCTIONS
(Cont.) 5.3 (Cont.)
^%
i f% 5.3.10 (Cont.) ,, g j y
.J
- 13. During RCS depressurization monitor for void formation yf in the reactor vessel upper head region. Indications of possible void formation include:
j? F
- a. RCS temperature = Tsat for the corresponding RCS _,f pressure.
- b. A pressurizer level increase significantly greater than expected while operating auxiliary spray.
- c. A pressurizer level decrease while operating charging.
- d. If the Pressurizer Level Control System is in automatic, an unanticapted letdown flow greater than charging flow.
- 14. If voiding in the RCS is indicated, perform the following:
- a. Isolate letdown by closing V-2515 and V-2516 (Letdown Containment Isolation). ,
- b. Stop the RCS depressurization.
- c. Stop the RCS cooldown.
- d. If possible, review and select one RCP in each loop for restarting.
- e. Repressurize the RCS to eliminate the void by operating pressurizer heaters or EPSI and charging pumps.
NOTE: If the HPSI or charging pumps are utilized to charge the RCS solid, the pumps should be stopped after solid RCS conditions are indicated.
- f. If required to continue the cooldown with the known presence of a steam void in the reactor vessel head, proceed using the Fill and Drain Method (Appendix D).
g .' When conditions permit, re-initiate letdown and resume depressurization to SDC initiation pressure.
l l Page 7 of 22 ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE NUMBER 2-0120040, REVISION O NATURAL CIRCULATION /COOLDOWN
5.0 INSTRUCTIONS
(Cont.) 5.3 (Cont.) 5.3.10 (Cont.)
- 15. If off-site power has been lost, and it becomes necessary to augment the cooldown rate refer to Appendix E.
- 16. When RCS temperature reaches 3250 F, maintain the RCS at this tempe,rature for an additional 20.4 hours (See Figure 2). .
, g.
- 17. Upon completion of the required " soak" period, initiate ! $,
SDC in accordance with Appendix F. f I l l = i I _..,.-..--_n. . - . . .. . ._y -_. v --.y-..
Page 8 of 22 ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE NUMBER 2-0120040, REVISION O NATURAL CIRCULATION /COOLDOWN Figure 1 SATURATION \ re( so.:j/
/
,[ 4 3000 2800 2000 SUPERCOOLED REGION / / /
2400 I I / / / 2200 0 2000 50 F SUSCOOLIP(G 9 '
~
E 1800 0 20 F SU3 COOLING
. 1600
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0 wl 300 350 400 450 500 550 600 650 700 RCS TEMPERATURE, HT , F l i e
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ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE NUMBER 2-0120040, REVISION 0 . NATURAL CIRCULATION /COOLDOWN
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Page 13 of 22 ST. LUCIE UNIT 2 e. EMERGENCY OPERATING PROCEDURE NUhBER 2-0120040, REVISION O NATURAL CIRCULATION /COOLDOWN D
)
FIGURE 5 , DATE I TIME COLUMN 1 COLUMN 2 COLUMN 3
- DIFFERENLf:,
PRESSURIZER LOWEST SPRAY PRESSURIZER COLUMN 1 every TEMP LINE TEMP PRESS MINUS 30 :ainutes TI-1101 TIA 1103/1104 PI 1107/1108 COLUMN 2 t i
*LDi1TED TO < 350' AND > 500 Operator Shift RCS TEMP AND PRESSURE ,
SHALL BE WITHIN LIMITS OF FIGURE 3.4-2b FOR EACH Operator Shift 30 MINUTE PERIOD. Operator Shift ,
S Page 14 of 22 ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE NUMBER 2-0120040, REVISION O NATURAL CIRCULATION /COOLDOWN i-APPENDIX A w b
)
PRECAUTIONS f
- 1. Natural circulation flow cannot be verified until the RCP's have stopped coasting down after being tripped.
- 2. Due to increased loop transit times, verification of plant responses to a plant change cannot be accomplished until approximately 10 to 15 ,
minutes following the action.
- 3. After a cold shutdown boron concentration-is attained in the RCS, makeup water added to the RCS during the cooldown should be at least the same boron concentration as in the RCS to prevent any dilution of-RCS boron concentration.
- 4. Once pressurizar cooldown has begun, pressurizer level indication decalibration will occur (indication on the normal petssurizer level i indication will begin to deviate from the true pressurizer level).
The temperature compensation correction curve posted on the RTGB should be used to determine true pressurizer water level. Cold calibrated pressurizer level indication is also available for lower pressurizer temperatures.
- 5. Minimize the use of pressurizer auxiliary spray whenever the .
1 temperature differential between the spray water and the pressurizer
, is greater than 200 F. Any auxiliary spray cycle which results in a ;
spray line temperature change of 650*F to 120*F in < 1.5 seconds shall be recorded in accordance with AP 0010134.
- 6. If pressurizer spray is not available, boron concentration'in the pressurizer may be lower than the RCS loop boron concentration. RCS i boron concentration should be inersased to avcid being diluted,below minimum requirements by a possible pressurizer outsurge.
- 7. If either the HPSI or LPSI pumps are utilized to collapse any steam voids in the RCS by charging the syJtem solid, the pump (s) should be stopped after solid conditions are indicated. This will minimize the i potential for any inadvertant flowpath from the RCS back to the
- Refueling Water Tank.
- 8. If the RCS is solid, closely monitor any makeup or draining and any system heatup or cooldown to avoid any unfavorable rapid pressure l excursions.
i
- 9. During all phases of the cooldown, monitor RCS temperature to avoid exceeding a cooldown rate > 100'F/hr.
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F8ge 15 of 22 ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE NUMBER 2-0120040, REVISION O NATURAL CIRCULATION /COOLDOWN
/ r APPENDIX A (Cont.)
) u PRECAUTIONS .
f[ ,
- 10. If cooling down by natural circulation with an isolated steam 7 generator, an inverted AT (i.e., Te > Th) may be observed in the 8 idle loop. This is due to a small amount of reverse heat transfer in 3- l the isolated steam generator and will have no effect on natural circulation flow in the intact steam generator.
- 11. All available indications should be used to aid in diagnosing the event since it may cause irregularities in a particular instrument reading. Critical parameters a2st be verified when one or :nore confirmatory indications are available.
- 12. When establishing auxiliary feedwater flow to the Steam Generators, use Steam Generator levels as well as header flowrates to ensure each Steam Generator is receiving auxiliary feedwater.
- 13. Condensate inventory should be monitared periodically to ensure that an adequate supply is available. Makeup to the Condensate Str.. age Tank should be started as soon as practical. If CST level decreases to tainimum required by Technical Specif. cations, the plant should be immediately cooled down utilizing the lill and Drain Method (Appendix D).
I I ( i e 0
- , - - - + , - - - - . - - . - - ---
1 1 Psge 16 of 22 l ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE NUMBER 2-0120040, REVISION O NATURAL CIRCULATION /COOLDOWN i APPENDIX B DISCUSSION i Reactor Coolant Pump forced circulation ,and heat transfer to the Steam Generators is the preferred mode of operation for decay heat removal whenever plant temperatures and pressures are above the Shutdown Cooling , System entry conditions. The natural circulation capability at the St. Lucie Plant provides an emergency means for core cooling using the steam generators, if the RCPs are unavailable. Natural circulation is governed by decay heat, component elevations, [ primary to secondary heat transfer, loop flow resistance, and voiding. j Component elevations at St. Lucia Plant are such that satisfactory natural circulation decay heat removal is obtained by density differences between the bottom of the core and the top of the steam generator tube sheet. An addit,ional contribution to natural circulation flowrate is the density difference obtained as the coolant passes through the Steam Gecerator U-tubes, but this is not required for satisfactory natural circulation. Natural circulation is assured even if the U-tubes are partially uncovered on the Steam Generator secondary side. Because of the temperature distribution in the Steam Generator U-tubes, there is no degradation in primary to secondary heat transfer as long as the secondary level covers at least 1/3 of the tube. height. By ensuring that the loop AT is less than the full power AT, the power-to-flow ra*io is assured to lua less , than 1.0 during natural circulation.
- Satisfactory natural circulation heat removal can be obtained with either one or two Steam Generators. Unequal auxiliary feedwater to the Steam Generators will not lead to unsatisfactory natural circulation as long as 4
all the decay heat is being removed throught the Steam Generators. Assurance that the RCS is being maintained in a subcooled condition can be obtained as follows. With the Subcooling Margin Monitor (SMM) operating mormally, the nomograph on RTGB 204 is used in conjunction with the SMM to 4 eliminate dependence on a single instrument. With the SMM inoperable, reference to the nomograph utilizing control room indication such as hot leg temperature, pressurizar pressure, and incore thermocouples will determine the margin to saturation. Subcooling margin can also be determined by subtracting hot leg temperature from pressurizar temperature (TE-1101). During normal plant operation under conditions of forced circulation flow, there is only a small flow of coolant in the reactor vessel head area. During periods of natural circulation, there is little, if any, effective
. flow. If the RCS is cooled down using natural circulation, it is possible . ! to generate a steam void in the reactor vessel head when saturation conditions develop. These conditions can be produced by the temperature sustained by the retained metal heat and decreased RCS pressure during cooldown. .
I
- - .- -- , , - - - - . - - , . - . - . - - - - - - -- L
Y Page 17 of 22 ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE NUMBER 2-0120040, REVISION 0 NATURAL CIRCULATION /C00LDOWN APPENDIX B (Cont.) , .D) i gm DISCUSSION LJs . Analyses have demonstrated that the upper reactor head region fluid can be ,p cooled to Shutdown Cooling System (SDC) entry conditions without void # formation using a hot les temperature cooldown rate of 500F/hr in approximately 14.2 hours. In order to provide additional conservatism, f
- I this procedure directs that a cooldown race of about 500 F/hr to 325 F be utilized, followed by a soak of 325 F for 20.4 hours for a total cooldown time of approximately 25.7 hours from cooldown initiation. (See Figure 1).
The condensate supply required for this cooldown is 270,500 gallons. - Makeup water can be supplied from the Water Treatment Plant and the two 500,000 gallon City Water Storage Tanks, or Treated Water Storage Tank. Pumping capability from all sources can be supplied from the diesel generators. An alternative to the above cooldown procedure is the fill and drain method (See Appendix D). This method may be employed should an extremely low probability event occur which could cause a loss of condensate makeup capacity or require a rapid RCS de pressurization. race. It provides for cooling of the upper reactor vessel head region by using auxiliary spray to the pressurizer to lower RCS pressure and create a void in the upper head. Voiding in the upper head flushes hot upper head fluid into. the cooler RCS where it mixes with RCS watar. The water flushed oat of the upper head will cause a surge of water from the RCS into the pressurizer. The process is halted by stopping the spray. The insurge compresses the pressurizer steam space, raising the pressure, thus stopping the insurge and halting flashing in the upper head. Charging to the RCS will then force fluid into the upper head due to the elevation - difference between the reactor vessel upper head and the pressurizer. Mixing of colder loop water with the hot upper head cools the upper head and causes an outsurge from the pressurizer. The process is continued until the upper head is solid. The cycle is then repeated until RCS temperature and pressure have been reduced to SDC entry conditions. The above procedure has been analyzed and performed sucessfully twice at St. Lucie and is considered a safe, alternative method of natural circulation cooldown. 9
. Page 13 of 22 ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE NUMBER 2-0120040, REVISION O NATURAL CIRCULATION /COOLDOWN APPENDIX C RCS COOLDOWN/DE-PRESSURIZATION CHECK 0FF LIST
- 1. At RCS pressure of 1750 pais, isolate and bypass the following l transmitters:
1.1 FT-2212 (Charging Header Flow Transmitter) NOTE: Close the valve on the transtaittec marked HIGH SIDE, open the valve marked BYPASS, and close the valve marked LOW SIDE. [ %, 1.2 PT-2212 (Charging header Pressure ,, Transmitter) f NOTE: Close its isolation valve.
- 2. At RCS pressure of 1700 psia, the SIAS Channel 3 LOCK PERMISSIVE g annunciator will come on. Block Channels A and B of SIAS by turning the key-interlocked switches to the BLOCK position.
NOTE: If the channels have been blocked, the two annunciators SIAS ACTUATION CHANNEL A BLOCKED and SIAS ACTUATION. CHANNEL B BLOCKED will come on.
- 3. At Steam Cenerator pressure of 685 psig, the MSIS ACTUATION CHANNEL A BLOCK PERMISSIVE and MSIS ACTUATION CHANNEL B BLOCK PERMISSIVE annunciators will come on. Block the MSIS channels by turning the key-interlocked switches to the BLOCK position.
NOTE: If the channels have been blocked, the two annunciators MSIS ACTUATION CHANNEL A BLOCKED and MSIS ACTUATION CHANNEL BE BLOCKED will come on. t 4. Prior to reaching RCS pressure of 1100 psia, unisolate and place i in operation the standby pressurizer level control and letdown pressure control valves. l
Page 19 of 22 ST.'LUCIE UNIT 2 . EMERGENCY OPERATING PROCEDURE NUMBER 2-0120040, REVISION O j NATURAL CIRCULATION /COOLDOW'i l 1 APPENDIX C (Cont.) RCS COOLDOWN/DE-PRESSURIZATION CHECK 0FF LIST l
- 5. 0 When RCS temperature is < 500 F and RCS pressure is < 1500 psia, perform the following: ,
5.1 Close the Containment Spray (CS) pump discharge valves: V-07145 V-07130
#"" \
5.2 Close and tag the manual valves in the CS header: ;;/ 9 V-07162 (A Rdr) V-07165 (B Edr) ' 5.3 Close containment spray motor operated valves MV-07-3 (A Hdr) i HV-07-4 (B Hdr) k
- 6. When RCS cold leg temperature reaches 280*F, annunciator SELECT LTOP OPERATION will come on.
6.1 Close MOV-1476 and MOV-1477 (PORV Isolation)' 6.2 Select LTOP on control switches for PORV-1402 and PORV-1404, and ensure that neither PORV opens. 6.3 Open MOV-1476 and MOV-1477 (PORY Isolation).
- 7. When RCS temperature reaches 3250 F and RCS pressure reaches 260 psia, perform the following:
7.1 Remove the trip and close fuses on one HPSI pump, and tag with ' caution tags. NOTE: Ensure the remaining HPSI pump is operable. 7.2 Remove the trip and close fuses on the 2A and 2B CS Pumps, and tag with caution tags.
- 8. When RCS temperature reaches 200 0 F, perform the following:
8.1 Remove the trip and close fuses on the remaining HPSI pump and tag with caution tags. 8.2 Tag out one charging pump such that no more than two charging pumps are available for dilution below 200 0F. O
. Page 20 of 22 ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE NUMBER 2-0120040, REVISION O NATURAL CIRCULATION /COOLDOWN APPENDIX D RCS FILL AND DRAIN HETHOD OF COOLING b=$a REACTOR VESSEL HEAD REGION NOTE: This method of RCS cooldown should only be esployed in the event that rapid de pressurization of the RCS is required, or Condensate l Storage Tank level decreases below mininum required by Tech Specs. -
CAUTION: DURING THIS EVOLUTION, PRESSURIZER LEVEL IS NOT A VALID INDICATOR OF RCS INVENTORY DURING TRANSIENT CONDITIONS. CARE SHOULD BE EXERCISED TO OBSERVE OTHER PARAMETERS WHICH WOULD INDICATE ANY LOSS OF RCS INVENTORY.
- 1. Take manual control of the charging and letdown system.
- 2. Lower RCS pressure by using auxiliary sprays into the pressurizer.
- 3. As voiding occurs in the upper reactor vessel head, a surge of water from the RCS will cause pressurizer level to increase rapidly.
Terminate auxiliary spray prior to peessurirer level increasing to 70% indicated level.
- 4. Cool the upper reactor vessel head region by charging with a charging pump to the RCS loop (s). Continue charging until either of the following conditions occur:
4.1 Pressurizer level decreases to 30% indicated level 9.R. 4.2 The upper reactor head is charged solid. NOTE: A solid upper head condition will be evident by an increasing pressurizer level as charging to the loops is continued. -
- 5. Repeat steps 1 thru 4 above until SDC entry conditions are established.
e 0
l Page 21 of 22 ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE NUMBER 2-0120040, REVISION 0 NATURAL CIRCULATION /COOLDOWN sw APPENDIX E r' "' I t~ -i AUGMENTED C00LDOWN WITH THE STEAM DUMP Q {. BYPASS SYSTEM (SBCS) If the desired RCS cooldown rate cannot be attained, the SBCS can be used jI jF l.f either by itself or in conjunction with the atmospheric dump valves. 4 ~-~f Since condenser vacuum will not be available, the following actions should L-- ' be taken to place the SBCS in service:
- 1. Call available maintenance personnel onsite to remove the target flange on a SBVS valve (preferable V-8803).
NOTE: If no maintenance personnel are on site, call the Duty Call Supervisor.
- 2. Isolate all other SBCS valves from the condenser (except the selected valve).
- 3. Jumper low vacuum interlock in SBCS. (Performed by I & C.)
- 4. Raset the condenser vacuum interlock by depressing the reset button (on the outside of the RRS #2 cabinet) and observe that the condenser-vacuum interlock yellow light goes out.
NOTE: This will bypass the vacuum permissive and allow operation of V-8803 to atmosphere af ter removal of the carget flange.
- 5. Place all SBCS controllers in Manual
! 6. When the taget flange for V-8803 has been removed and the vacuum interlock jumpered, manually adjust the controller for V-8803 to control RCS cooldown rate.
CAUTION: DO NOT EXCEED A C00LDOWN RATE > 750 /HR. I
.~m.--_ _ . - -- . , - - - - - - - < t
. Page 22 of 22 ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDdRE NUMBER 2-0120040, REVISION O NATURAL CIRCULATION /COOLDOWN APPENDIX F y, uy,%
INITIATION OF SHUTDOWN COOLING we {'} NOTE: Perform bracketed steps for train "B"
,f
,f a)
- 1. Open HCV-3557 (3512] (SDC disch to LPSI hdr) /I #
- 2. Open MV-3517 (3658] (LPSI pump supply to SDC EX) [ *[""""
- 3. Check to be open FCV-3306 [3301] (SDC EX bypass) {"
- 4. Open MV-3536 (3535] (SDC recirc warmup)
- 5. Open MV-3456 [3457] (SDC EX isol)
- 6. Check to be open V-3204 [3205] (LPSI pump mini-flow)
- 7. Check to be open V-3495 and 3659 [3496 and 3660] (Mini-flow hdr s' top)
- 8. Start 2A (2B] LPSI pump
- 9. Check co be closed V-3661 (Check valve leakage drain)
- 10. Open HCV-3615 and 3625 [3635 and 3645] (LPSI isol)
- 11. Open HCV-3618 and 3623 [3638 and 3648] (Check valve leakage control)
- 12. Open V-3459, V-3463, and 2I-SE-03-2A and 2B (RWT recirc stop)
- 13. Check the boron concentration in the system after circulating for ten minutes. Continue circulation until the boron concentration is > to the concentration in the RCS. .
- 14. Close HCV-3618, HCV-3628, [HCV-3638, and HCV-3648] (Check valve leakage control)
- 15. Close V-3459, v-3463 and 2I-SE-03-2A and 23 (RWT recirc stop)
- 16. Close HCV-3615 and 3625 (3635 and 3645] (LPSI isol)
- 17. Close HCV-3657 [3512] (SDC disch to LPSI hdr)
- 18. Continue to run LPSI pump to heat the SDC system as much as pratical.
- 19. Verify flow on FI-3306 [3301).
- 20. Close V-3204 (3205]. Ensure pump sinimum flow requirements are met.
- 21. Stop the LPSI pump.
- 22. Close V-3444 (3432] (LPSI pump suction from RWT)
- 23. Close MV-3536 [3539] (SDC recire warmup)
- 24. Check RCS pressure < 275 psia, then open V-3480, 3481 and 3664
[V-3451, 3452 and 3665] (SDC return valves)
- 25. Open HCV-14-3A [3B] (CCW to SDC EX)
- 26. Start 2A [2B] LPSI pump.
- 27. Slowly inch open HCV-3625 [3635] to bring SDC system up to temperature.
- 28. Adjust FIC-3306 [3301] to maximum flow in AUTO mode ,
- 29. When temperature has stabilized, open fully HCV-3615 and 3625 (3635 and 3645] and adjust FIC-3306 [3301] to control at 3000 gpm in AUTO.
- 30. Adjust RCV-3657 (3512] to maintain desired cooldown rate.
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Pcgo 1 of 15 EMERGENCY PROCEDURE 2-0120041 RSV 1 SGTR
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e 4 Lj i l' ,; 2 8 sw FLORIDA POWER & LIGHT COMPANY ST. LUCIE PLANT UNIT 2 EMERGENCY PROCEDURE NUMBER 2-0120041 REVISION 1 STEAM GENERATOR TUBE RUFTURE (SGTR) OCTOBER 25, 1982 O e TOTAL NO OF PAGES 15 4ha g.
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i i i Pdga 2 M '15 5 Ii SGTR f*% g EMERGENCY PROCEDURE NUMBER 2-0120041 7 ,, s REVISION-1 ' 3 js e
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1.0, SCOPE: This procedure provides operitor instruction for two conditionsi
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J (A) S/G tube leak less than charging pump capacity (Reactor l-shutdown-SIAS not recieved) R1 (B) S/G tube leak greater than charging; pump capacity (SIAS revieved). The procedure leaves the RCS in a cold shutdown condition and the affected Steam Generator isolated. . R1
.y -' '
2.0 SYMPTOMS
L ' E NOTE-These symptoms are alike for both a large and small leak.,
.s Y
2.1 Unique to this incident: 2.1 Radiation monitoring system ( ,, 2.1.1 S/G Blowdown Monitor Alarm 1 \ 2.1.2 Condenser Air Ejector Alarm i \t s
' NOTE
- Any or all of the following may be evident due to a tube failure.- ,
iN 2.2 Decreasing PRZa level 2.2 _Indicacions BU Clnar31ng pump start PRZR heaters de-energize 1 l s Alarms I,H-l7,H-18,H-25,H-26, H-29,H-30 2.3 Decreasing PRZR pressurce ' 2.3 Indications
, , BU heaters energize Alarms H-9,H-10,H-1,H=2,H-3, l H-4 2.4 Inicial increa'se in affected S/G 2.4 Dependent on size of level followed by return to tube leak programmed level LR-90ll, 9012
1 Psgs 3 of 15 SGTR EMERGENCY PROCEDURE NIBiBER 2-0I20041 s REVISION l g', NA"$ L
- '4 .h k
- 2. 0, SnTTOMS : (Cont.) /,/
2.5 Feed flow less than stea:n flow on affected S/G 2.5 Dependent on size of [- j cube leak l FR-8011/9011 FR8021/9021 2.6 Decreasing letdown flow 2.6 Caused by decreasing PRZR level
. FIA-2202 2.7 Increasing charging flow 2.7 Will cause VCT level to decrease LIC-2226
< FIA-2212
> Alarms
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- 6 .
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Pega 4 of 15 SGTK EMERGENCY PROCEDURE NUMBER 2-0120041
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REVISION 1 7 g* 1 i /% It 3.0 AUTOMATIC ACTIONS: 3.1 PRZR level coatrols close 3.1 On both large leak and .' to minimum on small leak. 3.2 S/G blowdown and sample 3.2 On both large leak and valves close on high , on small leak. radiation 3.3 PRZR backup heaters 3.3 on small leak only. energize 3.4 Reactor trip from TM/LP (variable) 3.5 SIAS when RCS pressure decreases to 1600 PSIA 3.6 CIS from initiation of SIAS 3.7 Turbine trip from reactor trip 3.7.1 FW Reg valves close and 15% bypass valves open to 5%
^
flow position 3.8 PRZR heaters de-energize on low low level 3.9 PORV's open at 2400 PSIA i l
i Pega 5 of 15 SGTR EMERGENCY PROCEDURE NUMBER 2-0120041
- REVISION 1
,g,,%
. 1 A V1 4.0 IMMEDIATE OPERATOR ACTIONS: [,j; ). ,
4.1 Ensure all required automatic actions . have occured, or initiate manually. jf 2 4.2 Start additional charging pumps as necessary. f^~-~} 4.3 Ar. tempt to shutdown the turbine and reactor in a controlled manner prior to recieving any automatic reactor trip signals. , 5.0 ' SUBSEQUENT ACTIONS: Check-5.1 Reactor Shutdown - SIAS not recieved. NOTE: If SIAS occurs during these actions, proceed immediately to Step 5.2, SIAS recieved. 5.1.1 Isolate letdown if necessary to maintain pressurizer level. 5.1.2 Attempt to determine the affected steam generator by comparing levels, steam and feed flow, and by - radiation monitoring and sanpling. 5.1.3 Ensure condensor air ejector vent is aligned to the plant vent. 5.1.4 Ensure atsoapheric staam dump on affected stets gensrator is closed ! and in manual. 5.1.5 Ensure blowdown Ls aligned es nonitor tsaks. Isolate blowdown . on affected steaa generator except as needed to main:ain level within the indicated range. 5.1.6 Stop one reactor coolant pu=p in each loop. 5 . '. 7 Commence borating to cold shutdown boron concentration, and start cooling down the on non-affected steam generator R1
, - - - ~ , ,- - - - - - - - ~,- - -
Pago 6 of 15 SGTR EMERGENCY PROCEDURE NUMBER 2-0120041 REVISION 1 ,,e., ,
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$"\ I 5.0 SUBSEQUENT ACTIONS: (Cont.) ',
5.1 (Cont.) .;I / 5.1.8 As soon as plant conditions allow, Check /
/
3
.depressurize RCS to 900 psia. #
3
$ s 5.1.9 Isolate the affected steam generator as follows: ;
- 1. Shut MSIV
- 2. Close AFW manual isolation valves to the affected steam generator.
2A: V-9152 and V-9120 23: V-9158 and V-9136
- 3. Close affected steam generator main feed header block valves.
- 4. Close steam supply to 2C AFW pump from affected S/G.
5.1.10 If plant conditions warrant, implement the Emergency Plan per EPIP 3100021E. 5.1.11 Continue the cooldown to Cold Shutdown conditions. 5.2 SIAS recieved 5.2.1 Following a SIAS caused by low RCS prasaure and after it has been verified that
- CEA's have been fully inserted for 5 seconds, stop all operating RCPs.
5.2.2 If pressurizer is availible use heaters to establish 20 Fb 7 subcooled conditions. CAUTION: A BUBBLE MAY EXIST IN THE VESSEL READ. IF PRESSURIZER LEVEL STARTS TO DROP RAPIDLY WHEN HEATERS ARE ON, DE-ENERGIZE HEATERS AND ATTEMPT TO RESTORE 1 LEVEL WITH CHARGING PUMPS. 4 R1 1
?tge 7 of 15 SGia EMERGENCY FROCEDURE NLHBER 2-0120041 REVISION 1
- r e. g.,
5.0 SUBSEQUENT ACTIONS: (Cont.) ,, i b
*)
5.2 (Cont.) Chect 5 *. }' f y 5.2.3 If the Pressurizer is not _f' jr available, cooldown by natural / jr circulation to establish 20 0e ; < 4 subcooling. If pressurizar becomes available, use heaters to maintain pressure. Do not raise pressure except as needed to maintain subcooling. The preferred method to remain subcoolad is by RCS cooldown. 5.2.4 Ensure equipment operation per Table I, Safety Injection Actuation and Table II, Containment Isolation. 5.2.5 Upon verification that SIAS is the result of S/G tube rupture, and when plant conditions permit, start one reactor coolant pump in each loop. 5.2.6 Determine affected steam generator by comparing level and by radiation monitors and by sampling. . 5.2.7 Ensure blowdown is aligned co-conitor tanks, isolate blowdown on affected steam generator. Slowdown as needed to maintain level within indicated band. 5.2.8 Continue plant cooldown at a cate determined by cocidown of affected steam generator. El
1 Pego 8 cf 15
. SGTR l EMERGENCY PROCEDURE NUMBER 2-0120041 REVISION 1 p.
5.0 SUBSEQUENT ACTIONS: (Cont.) p~ N 3 f* I 5.2 (Cont.) {_3 j i Check l E 5.2.9 When RCS pressure is < 900 psia, / isolate the affected steam generator as follows: I
- 1. Shut MSIV
- 2. Close AFU manual isolation valves to the affected steam generator.
2A: V-9152 and V-9120 23: V-9156 and V-9136
- 3. Close affected steam generator main feed header block valves.
- 4. Close steam supply to 2C AFW pump from affected steam generator.
NOTE: Steam generator must be above AFAS reset point before AFW pumps can be stopped . 5.2.10 If HPSI is no longer needed to maintain pressurizer level, secure both EPSI pumps. 5.2.LL Continue cooldown to cold shutdown coaditions. R1 l i 9 i v , ,.. .-. - v . . . . , . . , - - - - . . . . , - . . . . n --- - , , - - - - - - . . . - - -
I Prga 9 of 15
. SGTR l EMERGENCY PROCEDURE NLHBER 2-0120041 l
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REVISION 1 TABLE I f g j SAFETY INJECTION. ACTUATION SYSTEM (SIAS) J CONDITION CHECX ETGB 206, Left to Right (2) CCW PPS 2A, 2B, oji 2C ON j (2) CCW to Fuel Pool HX Isolation Valves MV-14-17, NV-14-18 Closed (4) CCW Hdr Non-essential Isolation Valves HCV-14-8A, HCV-14-8B, HCV-14-9, HCV-14-10 Closed (2) CCW Outlet from Shutdown HX 2A, HI-2B, Valves, HCV-14-3A, HCV-14-3B Open (2) LPSI Pumps On (2) EPSI Punps On (4) LPSI Disch to Loops HCV-3615, HCV-3625, HCV-3635, - HCV- 3645 Open ' ~ (8) EPSI Disch to Loops HCV-3617, HCV-3627, HCV-3637, HCV-3647 - A Header HCV-3616, HCV-3626, HCV-3636, HCV-3646 - 3 Header Open ,
~
(2) HPSI Pp Fill to SIT's V3572, V3571 Closed (2) SI Test to RWT I-SE-03-2A, I-SE-03-2B Closed (4) SIT Isolation Valves V3614, V3624, V3634, V3644 Open (4) SIT Fill / Drain Valves I-SE-03-1A, I-SE-03-13, I-SE-03-lC, I-SE-03-lD Closed (4) SIT Check Leakoff Valves HIC-3628, HIC-3618, HIC-3638, HIC-3648 Closed (4) S/G Feed Pump Discharge , i ISOL Valves HCV-09-1A, HCV-09-2A, HCV-09-1B, J HCV-09-23 Closed )
Paga 10 of 15
. SGTR EMERGENCY PROCEDURE NUMBER 2-0120041 REVISION 1
.J ,4ame u~-)
TABLE I (SIAS) (Cont.) ") - j
. 9 CONDITION CHECK
=/ / -
(4) CCW To/From RCP's # #p
'HCV-14-1, HCV-2,HCV-7, ' #
HCV-6 Closed j
"""}
(2) Containment Sump Isolation LCV-07-llA, LCV-07-113 Closed ETGB 205, Left to Right (1) BA Makeup Valve V2512 Closed (2) BA Gravity Feed V2509, V2508 Open (1) VCT Discharge 72501 Closed (2) Letdown Isolation V2516, V2515 Closed ITGB 203, Left to Right (2) ICW Pumps 2A, 23, or 2C On _ (3) ICW Isolation Valves MV-21-3, MV-21-4, MV-21-2 Closed RTGB 201 (2) Diesel Generators 2A, 2B On RVAC Panel, left to~Right (4) RA3 Main Supply and ECCS Exhaust Fans 2HVS-4A, 2HVE-9A, l 2HVS-HB,2HVE-9E On (4) Containment Fan Cooler 2HVS-LA, 2HVS-lb, 2HVS-1C, on 2HVS-lD (Slow Speed) I (8) ECCS Isolation Dampers DSA D6A, D9A, D12A - A Train DSB, D6B, D9B, D123 - B Train Closed (2) Rx Support & Cavity Cool Fans 2HVS-2A, 2HVS-23, i 2HVE-3A, 2HVE-3B off L i l NOTE: Any spare equipment that is running, and not needed for controlling this incident should be STOPPED O
P0ga 11 of 15 SGTR EMERGENCY PROCEDURE NUMBER 2-0520041 REVISION 1
*' s TABLE II ,e. {
i h3 2 Containment Isolation Actuation Signal (CIAS) ' CONDITION CHECK, ETGB 206 Left to Right (2) SIT to RWT 3 I-SE-03-2A, I-SE-03-2B Closed (5) SIT Sample Isolation Valve FCV-03-LA, FCV-03-1B, FCV-03-lC, FCV-03-lD, FCV-03-lE Closed (4) S/G Blowdown Isolation Valves and 2 S/G Sample Isolation Valves (Isolation FCV-23-3, FCV-23-5, FCV-23-4, FCV-23-6) Closed (Sample FCV-23-7, FCV-23-9) (2) Containment Sump Isolation Valves LCV-07-llA, LCV-07-11B Closed (6) RCS & PRZR Sample Isolation Valves V5200, V5201, V5202, V5203, V5204, V5205 Closed (1) Primary Water Isolation HCV-15-1 Closed (1) Instrument Air Isolation HCV-18-1 Closed (1) N2 Supply Isolation V6741 _ Closed (2) Waste Gas Isolation V6750, V6718 Clo sad _ (2) RCP Bleed-Off Isolation V2505, V2524 Closed (2) RX Drain TK Isolation V6341, V6342 closed 9
, - ,n -
s - - ,
Pegs 12 of 15
. SGTR EMERGENCY PROCEDURE NUMBER 2-0120041 REVISION 1 TABLE II (CIAS) (Cont.) ' #%
i CONDITION CitECK RTGB 205 (3) Letdown Isolation Valves ' V2516, V2522, V2515 Closed RTGB 201 (2) ' Diesel Generator 2A, 2B On HVAC Panel, Left to Right (2) Shield Bldg. Ventilation Fan 2HVE-16A Control Room Fan 2HVE-13-A on (4) Control Room Isolation Valves FCV-25-24, FCV-25-17, FCV-25-18, FCV-25-16 Closed, (2) Shield Bldg. Ventilation Fan 2-HVE-16B Control Room Filter Fan 2RVE-13B On * . (4) Control Room Isolation Valves FCV-25-25, FCV-25-14, FCV-25-15, FCV-25-19 Closed (2) Containment Purge Exhaust Fans 2-HVE-8A, 2-HVE-8B Off (6) Containment Purge Isolation Valves FCV-25-1, FCV-25-3, FCV-25-5, FCV-25-6, FCV-25-4, FCV-25-2 Closed , (3) Continuous Containment H2 P"#88 Isolation FCV-25-20, FCV-25-26, FCV-25-21 Closed (2) Shield Bldg. Vent Isolation Valves FCV-25-32, FCV-25-33 Open (2) Fuel Bldg. Emerg. Vent Isolation Valves FCV-25-30, FCV-25-31 Closed j (6) Containment Sample Isolation t Valves (on RTGB 206) FCV-26-2, + FCV-26-4, FCV-26-6, FCV-26-1, FCV-26-3, FCV-26-5 Closed l l l l
r Pega.13 of 15
. SGTR EMERGENCY PROCEDURE NUMBER 2-0120041 REVISION 1 h
6.0 PURPOSE / DISCUSSION: 7 enable the operator to identify a Steam Generator 6.1 The purpose of this procedure is to list the indications that will
' g/
# Tu 4
to provide the action to be taken to control.che accident and minialze radioactive release to the environment. Q I e This procedure provides instructions for two cases, " Leak Within the Capacity of the Charging Pumps" (SIAS. not recieved) and " Tube f ailure" (exceeds Char 31ng Pump Capacity - SIAS recieved). R1
6.2 Discussion
A Steam Generator Tube Failure causes leakage of reactor coolant into the steam system. If the leakage exceeds the capacity of the charging pumps, pressurizer pressure will decrease rapidly, causing a enermal margin / low pressure trip. The subsequent cooldown a following the reactor trip combined with the continued leakage of reactor coolant into the Steam Generator will cause a further reduction in pressuriser pressure and level, resulting in initiation of safety injection and containment isolation. The tube rupture will cause a reduction in reactor coolant system volume and due to
- reactor coolant leakage into the steam generator, the af fected steam
; generator level will continue to increase after the feedwater block valves are closed by SIAS. The resulting decrease in RCS pressure and volume will result in.che RCS briefly being at saturation conditions. The possibility the exists for void, formation in the reactor coolant system.
Operator action should be directed toward prompt isolation of the i affected Steam Generator, to mininise 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 accampanies the Steam Generator Tube failure, steam is dunped to tha condenser, rather than the atmosphere, to prevent gross release of contamination to the environment. Action must be taken to identify the af fected Steam Generator as soon as possible and to isolate its feedwater flow to prevent water slugging the steam lines. i The Steam Generator Tube failure accident is nose severe when it l occurs at low power levels, due to the low inventory of water inicially present in the pressurizer. 1 0 0
Pega 14 of 15
- SGTR EMERGENCY PROCEDURE NUMBER 2-0120041 REVISION 1
.p %
6.0 PURPOSE / DISCUSSION: (Cont.) L.,6[12 5 6.2 (Cont.) . g a If a controlled reactor shutdown is commenced, reduce plant load at - f ["""j a maximum rate which will not of itself cause a plant trip; a power . reduction of approximately 5%/ minute is recommended. Minimize the use of the atmospheric steam dump valves. Any necessary releases that are made must receive appropriate authorization. Use motor driven emergency or normal feedwater pumps to reduce the release of potentially radioactive steam from turbine driven pump exhausts. Maintain reactor coolant pressure slightly greater than the affected steam generator. R1 Do not exceed a maximum cooldown rate of approximately 75 F/HR Condensate activity may be- transferred to the Circulating Water System by way of condenser tube leakage. The condenser should be isolated if vacuum is lost and the condenser is not being used for reactor plant cooldown. R1 To facilitate cooldown a main steam isolation signal may be avoided by bypassing the signal setpoint on each safety channel. If reactor coolant pressure control is maintained, a safety injection actuation signal may be avoided by bypassing the signal setpoint on each pressurizer pressure safety channel, thus facilitating cooldown and depressurizaticn. Maintain the affected steam generator level below the maxinum indicatable levnl by draining by way of the blowdown or sampling systems to the radioactive waste system. Although it is possible in the long term to note an increasing steam generator level, automatic feedwater modulation keeps the steam Senerator level approximately constant during the short term. After the faulted steam generator has been isolated and the cooldown is proceeding via natural circulation an inverted AT (i.e., T e high than Th ) may be observed in the idle loop. This is due to a small amount of reverse heat transfer in the isolated steam generator and will have no effect on natural circulation flow in the intact steam generator. i O f
Pcgn 15 of 15 . SGTR
- C(ERGENCY PROCEDURE NUMBER 2-0120041 REVISION 1 yP%,
7.0 REFERENCES
- ~' 2
-4 Y! L 7.1 Instruction Manual - Steam Generators, St. Lucie Unic No.1 "El [
8770-5008. JE 7.2 EBASCO Prints 8770-G-079, 089. g/l 7.3 Accident Analysis, FSAR, Section 15.4.4, Steam Generator Tube I I Failure. 7.4 CEN 117, Inadequate Cooling. 8.0 Records Required: 8.1 Normal Log Entries. 8.2 Applicable Transient Recorder Charts
9.0 Approval
Reviewed by: Facility Review Group October 12, 1982 Approved by: C. M. Wethy Plant Manager October 14,19__, Revision / Reviewed by,.FRG ~k I- ,C.i 19/ ~s Approved by: .C M / i . >. '. _ e Je 21 ant Manager " r / .- 1971 l "L A S T P A G E"
- EmerSency Procedure 2-0120041 Rev.1 TOTAL NO. OF PAGES 15
UNIT II OCCUMENT REVISION DISTR 3UTION SHEET - opF NOP3.AL & EMERGENCY OPER. PROCDURE CCCUMEN* T::LZ '# 5 S Of o/g h e <,.,'gw7~ (d-6 C/ CCCUME:C FII.E NUM3ER h - 6 / .2. O 4T (/ 1 CCCUMENT REVISICtf NUM3ER d OCCUMENT CISTR!3UTED CN 7 b
- cATE OCCCME C SENT TC: -
COPY TRANSMI"TAL COPY
!!C .
TRA!SMITTAL CCCUAENT HCLDER RE*URNED NC. CCCUME C HOLDER RE*C?3ED MASTER UNCONTROLLED COPIES 1 D. A. Sager 2 3 NRC - Region II 4 Atta: EPPS Branch C hief H. Paduano - GO 5 N. G. Roos A. W. Bailey 6 TSC G. Anglehart - CE 7 8 9 10 Watch Engineers II G. Regal 11 12 Ug el ow, Al -3ackfi: I3 TrairJng - Larry Baker 14 15 Training J. Spedick T. Vogan - GG G. J. Soissy 4 R. R. Jennings H. M. Mercer A. Pell R. J. Frechette _Re ident_NRC g NRC - IE: HQ Chief, Nuclear Response ) LA # C. Burns - CZ i PRCCESSED ST: [ DA*E [0 '2-7 M
Pega 1 of 25
- Emergency Procedure 2-0120042 Rev 1 LOCA O,
f g 8 'l. b) E j
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/
ee, ( 6} " FLORIDA POWER & LIGHT COMPANY ST. LUCIE UNIT 2 EMERGENCY PROCEDURE NUMBER 2-0120042 REVISION 1 OCTOBER 22, 1982 LOSS OF COOLANT ACCIDENT
- a. ace -
F0 R I !?ORET10!! Oill.Y ' This document is not centrollad. Before ase, verify information wi;h a controlled document. TOTAL NO. OF PAGES 25 e
Page 2 of 25 LOCA - EMERGENCY PROCEDURE NUMBER 2-0120042 REVISION 1 . r"% s ?. I c'T
1.0 SCOPE
Nb 'i 4 This procedure provides instructions which leaves the plant in a cold shutdown condition following a small or large break LOCA.
/ /[!cz e=3
2.0 SYMPTOMS
N# 2.1 Decreasing pressurizer pressure 2.1 Indications PI-1102 A, PI-ilO2 B, P1-1102 C, PI-1102 D PR-1100 Alarms
- 11-9, H-10, H-1, H-2, H-3, H-14 2.2 Decreasing pressurizer level 2.2 Indications Leakage greater than charging pump capacity.
LI-il10X, LI-il10Y, LIC-1110X, LIC-1110Y, L7-1110X, LR-1110 Alarms H-l7, H-18, H-25, H-26, H-29, H-30 - 2.3 Reactor Trip / Turbine Trip 2.3 Indications CEA's inserted (ADS) core Mimic RPS-Ch.1, RPS-Ch.4, RPS-Ch.7, RPS-Ch.9, RPS-Reactor Trip Breakers OPEN Alarms' L-3, t.-9, L-11, L-17, L-36, L-44, L-5, L-13, D-8 L-10, L-18 R1 FOR IDF990AT100 ONLY This document is not contro!Iod. Eefore use, verify information with a controlled document. e
Page 3 of 25y LOCA g EMERGENCY PROCEDURE NUMBER 2-0120042 REVISION 1 g i
=r.,
2.0 SYMPTOMS
(Cont.) 8 E
/ /
2.4 SIAS/CIS Actuation 2.4 Indications Przr press < 1600 PSIA [ h=9 /' g Equipment starts / isolates g ,,. j Tables 1 and Table II Alarms R-6, R-16, R-26, R-3, P-3, P-13, P-23. 2.5 CSAS Signal 2.5 Indications FI-07-1A, F1-07-1B, PIS-07-3A, PIS-07-3B Alarms S-7, S-17 2.6 Increasing Containment Pressure, 2.6 Indications Temperature and Humidity PIS-07-2A, PIC-07-23, PIS-07-2C, PIS-07-2D PR-07-4B, PR-07-5B, TR-07-3B, TR-07-5B, TI-07-3A, TI-07-5A, PI-07-4A, PI-07-5A Alarms P-13,P-23 2.7 Increasing Reactor Cavity 2.7 Indications Sump Level LIS-07-6,FR-07-3 Alarms N-21,H-29 2.8 High containment radiation 2.8 Indications RIS-26-6-2D, RIS-26-5-2C, RIS-26-4-2B, RIS-26-3-2A I Alarms P-5, P-15 , 2.9 Quench tank high level, 2.9. Indications ! temperature, pressure LIA-lll6, IIA-lll6, i PIA-lll6 l l Alarms H-16, H-24, R-32 0 l l
Pegs 4 of 25 LOCA EMERGENCY PROCEDURE NUMBER 2-0120042 REVISION 1 f*%
'i 5 fl j L=.,3 3 t
2.0 SYMPTOMS
(Cont.)
],['
s f [ 2.10 Decreasing VCT level 2.10 Indications i
,/
LIC-2226 [. Lw , g,,, 9? e - N' M-3, M-11 2.11 Unbalanced charging and 2.11 Indications letdown flow FIA-2202, HIC-1110, FIA-2212 Alarms M-5, M-13, M-15 2.12 Pressurizer safety valves 2.12 Indications open PIA-lll6, LIA-lll6,
- TIA-lll6, TIA-1109, TIA-1108, TIA-1107 Alarms H-12, H-11, H-19, H-27, H-16, H-24, E-32 2.13 RCS subcooling margin 2.13 Indications decrease TR-1115, TI-ill5, TI-1102, A, B,'C, D, TR-ll23, TI-1123, TR 1111X/1121X Alarms
. E-5, H-6, H-7, E-8 2.14 Reactor Coolant Pumps 2.14 Indications motor amps decreasing AM-ll3, AM-105, AM-109, and/or erratic. AM-101, PDI-110lA, PDI-1101B, PDI-1101C, PDI-1101D Alarms J-5, J-16,.J-32, J-21 R1 d
I S 6
---- - - - -- - . , . . . , , - . - , - , _ - . . . - . . . - - - - . - - . 4--- . - _ , . . - , . - . - - - . - - - -
Pcg3 5 of 25
- LOCA EMERGENCY PROCEDURE NUMBER 2-0120042 REVISION 1 / g 3.0 AUTOMATIC ACTIONS: / ,.;I N .?
*' I CAUSE 3.1 Reactor Trip 3.1 TM/LP or Low Pressurizer l -
Pressure 1 d 3.2 Turbine Trip 3.2 Reactor trips turbine 3.3 SIAS 3.3 RCS press i 1600 PSIA 3.4 CIAS 3.4 SIAS initiates 3.5 CSAS 3.5 High containment pressure 3.6 RAS 3.6 RWT level 3 feet, indicated i i 1 l l 1 l l l 0 0
- f. .,_-- _ . _ , . . . _ ,,-__,.___s, _ _ _ .
7,. ,,___ ._ _-- . , , , , . _ - _ . _ - . _ .
Pega 6 of 25
. LOCA EMERGENCY PROCEDURE NUMBER 2-0120042 .r * %
REVISION 1 [ g 1 f.
) 4
$mn& } .
4.0 IMMEDIATE OPERATOR ACTION: j' ..,Y 4.1 Carry out immediate operator d ,,*' actions for a reactor trip per Off-Normal 0F #2-0030130. f y Lausa _ , _j 4.2 If SIAS was caused by low RCS pressure: 4.2.1 Verify CEA's inserted > 5 sec. 4.2.2 Stop the operating RCP's. 4.3 Establish and maintain S.G level with the Auxiliary Feedwater System. 5.0 SUBSEQUENT ACTIONS: Check 5.1 Classify the event as conditions dictate, according to EP 3100021E,
" Criteria for Evaluation of Emergency" and implement the Emergency Plan as neces sa ry.
5.2 Ensure all required Automatic Actions (3.0) have occured. 5.3 Allow time for RCP coastd'own 5.3 Reason: Verify adequate and verify adequate core flow across the core, cooling by incore thermocouples. caused by flow'through _ the break. 5.4 Check the ESFAS Bypass Status 5.4 Reason: To ensure - board, availability of equipment for auto functions. 5.5 Ensure SIAS, CIAS are functioning 5.4 Refer to Table I and properly or manually initiate. Table II. CAUTION: Overfeeding the S/G's may cause excessive cooldown. Do not exceed 75 F/ER cooldown race. 5.6 If Containment pressure 5.6 Ensure CSAS components approaches 10 psig function. Refer to initate CSAS. Table III. R1
i Pega 7 of 25
. LOCA ,p=%
EMERCENCY PROCEDURE NUMBER 2-0120042 e REVISION 1 0 f c._: j 5.0 SUBSEQUENT ACTIONS: (Cont.) /' CHECK h [ ., 5.7 Refer to Reactor Trip / Turbine Trip, 2-0030130 and *'*""'" ensure that all subsequent acticas (Section 5) have been or are being performed. 5.8 When containment pressure decreases to < 10 psig: Reset CSAS Stop 2A and 2B CS pps Close FCV-07-1A, FCV-07-1B Ensure Iodine Removal Pps 2A, 2B stopped Ensure Iodine Removal System Isolation valves I-SE-07-3A and I-SE-07-3B closed 5.9 Within one (1) hour, stop RCS/BAMT boration via the charging pumps. 5.10 Conduct area radiation surveys as soon as possible to determine excent of damage. 5.11 Commence RCS cooldown per 0F 2-0030127 as soon as possible and in any case within one (1) hour. Refer to Appendix "A" for Reactor Head Cooling precautions & instructions. CAUTION Ensure RCS is maintained in a subcooled condition. After any SIAS, operate the SIS until RCS hot and cold leg temperatures are at least 20 F below saturation temperature for the RCS pressure. 5.12 Ensure proper operation of the safety injection system by checking flow rates and SIT levels. 5.13 If steam dump to condenser is available, close the atmospheric steam dump and begin dumping steam to the condenser. 5.14 If offsite power is lost, steam dump to the , atmosphere must be used for cooldown. CAUTION Do not exceed 750F/ hour cooldown race. R1
,1, - , , . - . - - - - -
s Pega 8 of 25 LOCA EMERGENCY PR0i:EDURE NUMBER 2-O'120042 e-- REVISION 1 x
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g :.. 1 ii hl Sam. . c 5.0 SUBSEQUENT ACTIONS: (Cont.) j // Check jI , j 5.15 continue auxiliary feedwater flow to the L * *1 steam generators during cooldown. [ % 5.16 Immediately prior to RAS, ensure power is available to V3659, V3660, V3495, V3496.. (HPSI and LPSI return to RWT.) 5.17 Ensure RAS occurs when the RWT level decreases to 3 ft. indicated - (4 ft. from bottom of the tank).
. Table IV, page 18, may be used as a check list.
5.18 If all HPSI pumps and charging pumps are operating and the RPSI pumps are delivering less than 75 GPM per pump, stop the charging pumps one at a time, then RPSI pumps one at a time until only one HPSI pump remains operating. Do not allow HPSI pumps to operate dead headed. , 5.19 Check RAB radiation levels and sump levels after RAS to detect SIS leakage. Even if leaks are detected, at least one HPSI pump must remain in operatioc. to provide flow to the core. 5.20 Establish radiation areas and warnings where necessary. Be cautious when initiating SDC because of possible high RCS activity. 5.21 Within ten (10) hours of the incident occurrence, initiate hot leg injection. This will be in conjunction with the existing cold leg injection. 5.22 If the pressure and inventory control with the SIS cannot be established after eight hours and RCS pressure is less than 300 PSIG, continue hot and cold leg injection. R1
P% Pcgs 9 of 15 LOCA i f5 EMERGENCY PROCEDURE NUMBER 2-0120042 Ljj l j' REVISION 1 i k' i 5 j' 5.0 SUBSEQUENT ACTIONS: (Cont.) C[ek y
^
5.23 If pressure and inventory control with the SIS are established after eight (8) hours and RCS pressure is greater than 300 PSIG, conduct one of the following activities (in order of decreasing
. preference). This condition indicates the system is refilled and subcooling has occurred.
5.23.1 1.) Verify subcooling by checking the saturation temperature for the existing pressure.
. 2.) Realign the SIS for cold leg injection.
3.) Continue to maintain subcooling and reduce RCS pressure to <275 PSIA for shutdown cooling by reducing the flow delivered by the high pressure injection and charging pumps. 4.) While reducing pressure and after shutdown cooling is initiated, maintain RCS pressure , with the charging pumps and/or the HPSI pumps
. to maintain at least 200 subcooling.
OR 5.23.2 Continue to remove decay heat using auxiliary feedwater and steam dumps if adequate condensate is available and _ _ _ (5.23.1) cannot be implemenced. OR
- 5.23.3 If 5.23.1 of 5.23.2 above cannot be implemented, open pressurizer power operated relief valves and align the safety injection system for cold leg injection.
l l To open the PORV's, pull two RPS pressurizer high pressure j trip unit bistables. l 5.24 Place both hydrogen recombiners in service (see Appendix "C"). 5.25 If containment hydrogen concentration cannot be maintained below 3.5% as indicated on the containment hydrogen' sample system, then f p, lace the containment hydrogen purge system in operation (see l Appendix "D"). I i R1 1 i 1u - l l . i I
Pega 10 of 25
- LOCA EMERGENCY PROCEDURE NUMBER 2-0120042 /. 7+3 REVISION 1 i O Lawbh h 1.
6.0 PURPOSE AND DISCUSSION: j-' f
.s j
This procedure provides instructions to be followed in the event that C ung leakage from the Reactor Coolant System exceeds the capacity of the i
",,3 operable charging pumps. When conditions in the Reactor Coolant System *'
degrade to the point that a Limiting Safety System Settin3 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 Injection System automatically provides a flow of subcooled water to the core foe 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 fission products to the containment atmosphere. The spectrum of breaks which would cause a LOCA is from approximately at
.2 inch diameter break up to a double-ended hot leg rupture. For an example: Analysis show that the flow from an unrestricted .3 inch diameter break is approximately 180 GPM at 2250 PSIA. A major concern for these small breaks is that the flow through the break may not be sufficient for decay heat removal. In those circumstances it is imperative that a secondary heat sink be available.
R1 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 conditions in the RCS during the cooldown to prevent void formation. Figure 1 is a quick reference for operator actions. Some instruments (valve position, temperature, pressure, level indications, etc.) specified for use in this procedure have not been desiSned for long term post LOCA conditions inside containment. l Therefore, the operator should be especially alert that the potential ! exists for erroneous indication after >15 minutes have elapsed following a LOCA event. l l If there is a hi Sh radioactivity level in the reactor coolant system, circulation of this fluid in SDC may result in high area radioactivity readings in the RAB. It may be necessary to fill th% przr solid to regain pressure control and to achieve 20'F subcooling. If this is the case, HPSI discharge valves will have to be carefully throttled during the cooldown to reduce system pressure. t
,, -- .- , ,,-- , --- , - . -n.-,,- - , - - , , , . - - - - - - -
---,.-,----,--.,,,-.,-------n-
I Pag 911 of 25
. LOCA j/
- EMERGENCY PAOCEDURE NUMBER 2-0120042 REVISION 1 p t b 1 g1 :
6.0 PURPOSE AND DISCUSSION: (Cont.) [ / Ensure HPSI flow to the core continues after RAS. Do not allow the HPSI ~# pumps to operate " dead-headed". EPSI shutoff head (no flow) 1250 PSIG. I 0***"i 1 Do not exceed 750F/ hour cooldown race. 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 the sample lines. Przr level may not always be a true indicator of RCS fluid inventory. Przt. steam space ruptures, reference leg failures, and reference leg heating may cause indications which are contrary to true conditions. Take appropriate action to keep core covered or reflood if it becomes partially uncovered. Maintain or re-establish a heat removal path. Regain RCS pressure and level control. Follow long term shut down procedures in order to assure that boron precipitation does not occur. R1 G
EMERCE'TCY PROCEDURE NU'!BER . 2-0120042 ? age 12 of 25 REVISION 1 ~" LOCA - - FIGURE I - i A LOSS OF COOLANT ACCIDENT STRATEGY CHART IA J LOSS OF 4 CCOLANT <? / ACC:D ENT j' '- ' - REACTIVITY CCNTROL CEA INSERTION SORATION PRESSURE CCNTROL PPC SPRAY a HEATERS MANU(AL CCNTROL CF) SPRAY & HEATERS SIS LSCLATE LEAK INVENTCRY CCNTROL SIS PLCS CHARGING a LETCOWN) MAN AL CONTROL OF CHARGING & LETDOWN ISCLATE LEAK RCS HEAT REMOVAL MAINTAIN STEAM GEN. INVENTCRY SIS CONTAINMENT CSAS CIS YES NO PRESSURE CCNTR PPCS SPRAYS HEA ) V RAPT 0 CONTROI f A INVEN RY CCNTROL COOLDOWN PLCS (CHARGING & STEAM GENERATCRS LETDOWN)
- RCS HEAT REMOVAL RESTART RCP'S ,
PRESSURE INVENTCRY YES '/ CCNTROLLED AND NO [ TERMINATE kfh/NG b EA ( GulCELINE Wlj3 g / RCS HEAT REMOVAL glGy 7 g!SO F] [NJECTION I-YES SCC NO TERMINATE AVAILAaLE Gul0EL:NE y RCS HEAT REMOVAL MAINTAIN RCS HEAT REMOVAL SCC STEAM GENERATORS PRESSURE CCNTRCL PORV a CCLD LEG INJECTION INVENTORY CONTRCL ,NVE PRES Y CCgTRg TERMINA ; i ERMINATE
, Gul0ELINE GUICEL!N E m
Page 13 of 25 . EXERGENCY PROCEDURE NUMBER 2-0120042 LOCA [~] g ,., g REVISION 1 ; I a 5' TABL*. I f f*S.. d f# SAFETY INJECTION' ACTUATION SIGNAL (SIAS) CORDITION CRECK RTGB 206, Le.ft to Right Two (2) CCW Pp (2A, 2B, or 2C) on Two (2) CCW to Fuel Pool HX Isolation Valves (XV-14-17, MV-14-18) Closed Four (4) CCW HDR Non-esdential Isolation Valves (HCV-14-8A, HCV-14-8B, HCV-14-9, HCV-14-10) Cloded Two (2) CCW Outlet Valves frcm shutdown HX 2A, 2B (HCV-14-3A, HCV-14-3B) Open Tv.s (2) LPSI PPS On Two (2) HPSI PPS On Four (4) LPSI Disch Valves'to Loops (HCV-3615, HCV-3625, HCV-3635, HCV-3645) Open Eight (8) HPSI Disch Valves to Loops (HCV-3617, HCV-3627, HCV-3637, HCV-3647 - Header A) (HCV-3616, ECV-3625, HCV-3636, HCV-3646 - Header B) Open Two (2) Hot Leg Injection Check Viv. Leakage Valves. (V3572, V3571) Closed Two (2) SI Test to RWT (I-SE-03-2A, I-SE-03-23) Closed , Four (4) SI Tank Isolation Valves (V3614, V3624, V3634, V3644) Open Four (4) SI Tank Fill / Drain Valves (I-SE-03-1A, I-SE-03-1B, I-SE-03-1C, I-SE-03-lD) Closed Four, (4) SI Check Leakage Test (HCV-3618, HCV-3628, HCV-3638, HCV-3648) Closed Four (4) CCW To/From RCP's (HCV-14-1, HCV-14-2, HCV-14-7, HCV-14-6) Closed O
s
\ .
'Page 14 of 25 LOCA y=
EMERGENCY PROCEDURE NUMBER 2-0120042 y , REVISION 1 > '. 1.
&]<,7 ' )\
(s e .e TABLE I (Cont.) , 3 j$ SAFETY INJECTION ACTUATION SIGNAL (SMS) f. i - CONDITION CHECK k[d,_e.. 3 RTGB 205
~
- i -*
Two (2) Boric Acid Make-up Pumps 2A and 23 Start' N N Two (2) Boric Acid Make-up Tank Recire Viv's i 2A (V-2650), 2B (V-2651) Closed One (1) Boric Acid Make-up Viv (V-2512) Closed Two (2) Boric Acid Gravity Feed Viv's j (V-2508, V-2509) Open One (1) Volume Control Tank Discharge ' 4 Viv. (V-2501) , close:Li Two (2) Letdown Isolation Viv's (V-2516, V-2515)
\
closed
\
Start ' Three Charging Pumps (2A, 2B and 2C) Signal ( One (1) Boric Acid Make-up Flow Viv I ' (FCV-2210Y) Closed Two (2) Containment Sump Isolation Varves Closed (LCV-07-11A, LCV-07-113) \ Two (2) Intake Cooling Water, Lube Watcr t'o '
- . Cire. Water Pumps, Isolation Valves (MV-21-44, MV-21-4B) Closed ,
RTGB 202 i Two (2) Intake Cooling Wtr ? umps On , , L Two (2) Intake Cooling Wtr Isolation t Valves (MV-21-3, MV-21-2) ' close_d ( ) RTGB 201
.e Two (2) Diesel Generators On s k
\
O
'b , s Peg'2 15 of p g LOCA f
EMERGENCYPROC2DURENUMBER2-d120042 w 7 REVISION 1 L)3ll 1
. j' ,
TABLE I (Cont.) I [ g ,,', , SAFETY INJECTION ACTUATION SIGNAL (SIAS) CONDITION. CHECK !- - - '
- HVAC PANEL LErr TO RIGKf Four (4) RAB Main Supply an'd ECCS Exhaust Fans (2-HVS-4A, 2-HVE-9A, 2-HVS-4B, 2-HVE-9B) On Four (4) Containment Fan Coolers On slow (2-HVS-1A, 2-HVS-13, 2-HVS-1C, 2-HVS-1D) Speed Eight (8) ECCS Isolation Dampers (DSA, D6A, D9A, D12A, D5B, D9B, D123) Closed NOTE Any spare equipment that is running and not needed for controlling this incident should be STOPPED.
R1 e ?)
's e
0
Pego 16 of 25 LOCA f**g EMERGENCY PROCEDURE NLHBER 2-O'120042 7 6 REVISION 1 E b j 6:n=I :.l f
.; ,y TABLE II ,.,/ /
CONTAINMENT ISOLATION ACTUATION SIGNAL (CIAS) g ,, CONDITION CHECK 5 _ . . . RTGB 206, Left to Right Two (2) SI Tank return to RWT (I-SE-03-2A, 1-SE-03-2B) Closed Five (5) SI Tank Sample Isolation Valves (FCV-03-1A, FCV-03,lB, FCV-03-lC, FCV-03-lD, FCV-03-lE) Closed Four (4) S/G Blowdown and two (2) S/G Sample Isolation Valves (Isolatiod FCV-23-3, FCV-23-5, FCV-23-4, FCV-23-6) (Sample FCV-23-7, FCV-23-9) Closed Two (2) Containment Sump Isolation Valves (LCV-07-IIA, LCV-07-llB) Closed Six (6) RCS and pressurizer Sample Isolation Valves (V5200, V5201, V5202, V5203, V5204, VS205) Closed One (1) Primary Water Isolation (HCV-15-1) Closed One (1) Instrument Air Isolation (HCV-18-1) Closed One (1) N2 Supply Isolation (V6741) Closed Two (2) Waste Gas Isolation (V6750, V6718) Closed Two (2) RCP Bleed-off Isolation (V2505, v2524) Closed Two (2) RDT Isolation (V6341, V6342) Closed RTCB 205 Three (3) Letdown Isolation Valves - (V2516, v2522, V2515) Closed RTGB 201 Two (2) Diesel Generators On HVAC Panel, Left to Right Two (2) Shield Bldg. Ventilation and Control Room Filter Fans (2-HVS-13A, 2-HVE-6A) On Four (4) Control Room Isolation Valves (FCV-25-24, FCV-25-17, FCV-25-18, FCV-25-16) Closed Two (2) Shield Bldg. Ventilation and Control Room Filter Fans (2-HVS-13B, 2-HVE-6B) On l Four (4) Control Room Isolation Valves (FCV-25-25, FCV-25-14, FCV-25-15, FCV-25-19) Closed
. Pego LOCA 17 of 25.,%.
EMERGENCY PROCEDURE NLMBER 2-0120042 REVISION 1 k[n ?;
?
TABLE II (Cont.) .E
- CONTAINMENT ISOLATION ACTUATION SIGNAL (CIAS) 7 CONDITION CRECK L u..
Two (2) Containment Purge Exhaust Fans (2-HVE-8A, 2-HVE-8B) Off Six (6) Containment Purge Isolation Valves (FCV-25-1, FCV-25-3, FCV-25-5, FCV-25-6, FCV-25-4, FCV-25-2) Closed Three (3) Continuous Containment H2 Purge Isolation (FCV-25-20, FCV-25-26, FCV-25-21) Closed Two (2) Shield Bldg. Vent. Isolation Valves (FCV-25-32, FCV-25-33) Open Two (2) Fuel Bldg. Emerg. Ventilation Isolation Valves (FCV-25-30, FCV-25-31) Closed Six (6) Containment Sample Isolation Valves (FCV-26-2, FCV-26-4, FCV-26-6, FCV-26-1, FCV-26-3, FCV-26-5) (RTGB 206) Closed O e O
Pego 13 of 25 EMERGENCY PROCEDURE NUMBER 2-O'120042 g REVISION 1 1 [ f4j
=
.5 TABLE III 4' j' CONTAINMENT SPRAY ACTUATION SIG:fAL (CSAS) ;Tf {.i _.., ,
R1 ; a CONDITION CHECK Two (2) Containment Spray Pumps On Two (2) Containment Spray HDR Isolation Valves (FCV-07-1A, FCV-07-1B) Open Two (2) Iodine Removal System Pumps On Two (2) Iodine Removal System Isolation Valves (I-SE-07-3A, I-SE-07>3B) Open i NOTE: Verify Flow on FI-07-1A and FI-07-13. 1 J l, 4 0 I
l Pcgs 19 of 25
. LOCA EMERGENCY PROCEDURE NUMBER 2-0120042 N ,,
RIVISION 1 . 9 5 W; TABLE IV ,;,
.i RECIRCULATION ACTUATION SIGNAL (RAS) g k .---
CONDITION -CHECK
=w.
Two (2) LPSI PPS Off Two (2) SI Pump Recire. to RWT Isolation Valves (V3659, V3660) Closed Four (4) Minimum Flow Isolation Valves (V3495, V3496, V-3659, V-3660) Closed Two (2) Containment Sump Outlet Valves (MV-07-2A, MV-07-2B) Open Two (2) RWT Outlet Valves (MV-07-1A, MV-07-1B) Closed R1 4 e
Pego 20 of 25
~ LOCA EMERGENCY PROCEDURE NUMBER 2-0120042 ,,J %,
REVISION 1 4 ..rn ,; N l i, e-APPENDIX "A" 4 I
.!~
REACTOR HEAD COOLING
.J
[(I i;.=q Analyses have demonstrated that the upper reactor head region fluid can L._.m 3 be cooled to Shutdown Cooling System (SDC) entry conditions without void formation using a hot leg temperature cooldown rate of 500 7/hr in approximately 14.2 hours. In order to provide additional conservatism, a 0 0 cooldown race of about 50 F/hr to 325 F should be utilized, followed by a 0 soak of 325 F for 20.4 hours for a total cooldown tLae of approximately 25.7 hours from cooldown initiation. The condensate supply required for this cooldown is 270,500 gallons. Makeup water cat; be supplied from the Water Treatment Plant and the two 500,00 gallon City Water Storage Tanks, or Treated Water Storage Tank. Pumping capability from all sources can be supplied from the diesel generators. If voiding in the RCS is indicated, perform the following:
- a. Isolate letdown by closing V-2515 and V-2516 (Lecdown Containment-Isolation).
. b. Stop the RCS depressurization,
- c. Stop the RCS cooldown.
- d. If possible, review and select one RCP in each loop for .
restarting.
- e. Repressurize the RCS to eliminate the void by operating pressurizer heaters or HPSI and charging pumps.
NOTE: If the HPSI or charging pumps are utilized to charge the RCS solid, the pumps should be stopped after solid RCS conditions are indicated.
- f. If required to continue the cooldown with the known presence of a steam void io the reactor vessel head, proceed using the Fill
; and Drain method (Appendix "B").
- g. When conditions permit, re-initiate letdown and resume depressurization to SDC intiation pressure.
R1
. Pass 21 of 25 LOCA EMERGENCY PROCEDURE NUMBER 2-O'120042 r *\
REVISION 1 f gc, c* 1 a- 4 a .; APPENDIX."A" ; ji-REACTOR READ COOLING - Ca. - (conticued) l wm .-u An alternative to the above cooldown procedure is the fill and drain method (See Appendix "B"). This method may be employed should an extremely low probability event occur which could cause a loss of condensate makeup capacity or require a rapid RCS de pressurization rate. It provides for cooling of the upper reactor vessel head region by using auxiliary spray to the pressurizer 'to lower RCS pressure and create a void in the upper head. Voiding in the upper head flushes hot upper head fluid into the cooler RCS where it mixes with RCS water. The water flushed out of the upper head will cause a surge of water from the RCS into the pressurizer. The process is halted by stopping the spray. The insurge compresses the pressurizer steam space, raising the pressure, thus stopping the insurge and halting flashing the upper head. Charging to the RCS will then force fluid into the upper head due to the elevation difference between the reactor vessel upper head and the pressurizer. Mixing of colder loop water with the hot upper head cools the upper head and causes an outsurge from the pressurizer. The process is continued until the upper head in solid. The cycle is then repeated until RCS temperature and pressure have been reduced to SDC entry conditions. R1 d
Pegs 22 of 25 LOCA ,,m===3 EMERGENCY PROCEDURE NLHBER 2-O'120042
- a REVISION 1 <
j U].I APPENDIX "B" ." RCS FILL AND DRAIN METHOD OF COOLING . REACTOR VESSEL HEAD REGION A* ^ " ' ' NOTE: This method of RCS cooldown should only be employed in the event that rapid de pressurization of the RCS is required, or Condensate Storage Tank level decreases below 150,000 gallons. CAUTION: During this evolution, pressurizer level is not a valid indicator of RCS inventory during transient conditions. Care should be exercised to observe other parameters which would indicate any loss of RCS inventory.
- 1. Take manual control of the charging and letdown system.
- 2. Lower RCS pressure by using auxiliary sprays into the pressurizer.
- 3. As_ voiding occurs in the upper reactor vessel head, a surge of water from the RCS will cause pressurizer level to increase rapidly.
Terminate auxiliary spray prior to pressurizer level increasing to 70% indicated level.
- 4. Cool the upper reactor vessel head region by charging with a charging pump to the RCS loop (s). Continue charging until either of the following conditions occur:
4.1 Pressurizar level decreases to 30% indicated level 9.E. 4.2 The upper reactor head is charged solid. NOTE: A solid upper head condition will be evident by an increasing pressurizer level as charging to the loops is continued.
- 5. Repeat steps 1 thru 4 above until SDC entry conditions are i established.
R1 l l r l
Pego 23 of 25 LOCA - EMERGENCY PROCEDURE NUMBER 2-O'120042 REVISION 1 [ ("} 1 g j ba= h$J i APPENDIX "C" ,<V ;- J-PLACING H, RECOMBINERS IN SERVICE f. ' [ 5 szw-a, I. Place recombiners in service as follows: I=sre-u=u5' 1A 13 4
- 1. Ensure breakers #41262 in 480V MCC 2A5 (2A) and
#42103 and in 480V MJO 2B6 (2B) are closed.
- 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 illuminate.
CAUTION 4 There is a lag in the following meter reading, so turn the potentiometer knob slowly. Do not . exceed 75 KW.
- 5. Gradually turn the Power Adjust potentiometer to 70 KW as indicated on the Power Out Wattmeter.
- 6. Periodically check the temperature of the three thermocouples using the temperature channel selector switch. And, when the temperature reaches 12500 F, adjust the power adjust potentiometer to maintain temperature between 1250 0F and 1400 F. Do not exceed 14000F.
R1 4
- , < e .
1 Pega 24 of 25 LOCA EMERCENCY PROCEDURE NUMBER 2-0'120042 ...~""% REVISION 1 8 k 3 !"n 2 1- $ $ 3 APPENDIX "D" J' j. ! f PLACING CONTAINMENT E9 PURGE IN SERVICE gf f
"~""~"' '
II. Place containment H2 Purge in service as follows:
- 1. Close FCV 25-35, normal discharge to plant vent.
- 2. Close FCV 25-9, filter train inlet.
- 3. Open FCV 25-20 and FCV 25-21, containment isolation valves
- 4. Open FCV 25-28, filter train bypass valve.
- 5. Ensure that 2-HVE-10A or 2-HVE-10B is running.
- 6. Open FCV 25-29 or FCV 25-34 as appropriate to direct the purge fan exhaust to the active SBVS filter train inlet.
- 7. Start 2-HVE-7A or 2-HVE-7B.
- 8. Open FCV-25-26 to peovide makeup air to the containment.
- 9. Throttle FCV-25-28 to provide the proper purge flow rate based on the hydrogen concentration rate of increase.
R1 S
Pega 25 of 25 LOCA EMERGENCY PROCEDURE NUMBER 2-0120042 #"% REVISION 1 [ ..
.i .
em.:.I) 1 .
7.0 REFERENCES
- / -
//
St. Lucie Unit #1 Emergency Procedures Unit #2 FSAR SECT. 1.0, 6.0, 9.0. ,[ e/ --. Lund Consulting report to C. E. (Feb. 6, 1981)
'( J Drafe of NUREG - 0799 8.0 RECORDS REQUIRED:
Nor:nal los entries LER Transient indicators and recorder charts i
9.0 APPROVAL
Reviewed by Facility Review Group October 12, 1982 Approved by C. M. Vechy Plant Manager October 14 1982 Revision _ Reviewed by Facility Review Group ? < S 3 n'. 19.? 2 - Approved by O' /b N r _ < c , , riPtant Manager
./ l '.' 19 c' ( . "L A S T P A G E" Emer3ency Procedure 2-0120042 Rev 1 O
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. Emergency Provadure 2-0120043 Rev 1 ICC'-
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'i FLORIDA POWER & LIGHT COMPANY ST. LUCIE PLANT UNIT 2 EMERGENCY PROCEDURE NUMBER 2-0120043 REVISION 1 IMADEQUATE CORE COOLING (ICC)
OCTOBER 25, 1982 TOTAL NO. OF PAGES 5 FOR This do 0 v erif D l10hTiCU cum n y inform e t is o a tio nt n n o withcontrolied aco retr !!ad. Befo00!.7 use, Ja cum ent, 0
8 Pego 2 of 5 FLORIDA POWER & LIGHT COMPANY ICC ST. LUCIE PLANT UNIT 2 EMERGENCY PROCEDURE NUMBER 2-0120043 ICC REVISION 1 fs. j eq i I
1.0 SCOPE
Provides actions to recognize and correct inadequate core cooling.
2.0 SYMPTOMS
NOTE: Any of the following symptoms may be indication of ICC. 2.1 Steam Generator levels at or RTGB 202 near zero on wide range level indication. 2.2 Loss of RCS subcooling or RCS superheated. 1.3 Loss of natural circulation Tgincreasing steadily, Tc increasing steadily, Core exit thermocouple Temps increasing Loop 6T > 46 0 3.0 AUTOMATIC ACTIONS: None 3.0 IMMEDIATE OPERATOR ACTIONS: 4.1 Ensure at least one steam , generator wide range level is greater than 33%. 4.2 Ensure atmos steam dump Steps 4.1 and 4.2 insure or SBCS is operating a secondary heat sink R1 0
Page 3 of 5 1C C.,, EMERGENCY PROCEDURE NUMBER 2-0120043 (ICC) REVISION 1 4.0 # e IMMEDIATE OPERATOR ACTIONS: (Cont.) , 4.3 Regain or raaintain 200 g subcooling in RCS y 4.4 If natural cire. can not be regained and RCP's can J[ 2 not be restarted, depressurize RCS to initiate i
]
HPSI flow to core. 5.0 SU3 SEQUENT ACTIONS: 5.1 Refer to the Emergency' Procedure which covers the event which initiated the inadequate core cooling (Natural Circulation /Cooldown, Total Loss of AC Power, Loss of Feedwater or S/G Level ECT.) R1 e
- - - - - - - ~ -
Pcgo 4 of 5
, ICC EMERGENCY PROCEDURE NUMBER 2-0120043 (ICC) REVISION 1 6.0 PURPOSE / DISCUSSION:
g g Inadequate core cooling (ICC) is a term that defines a reactor core g s') 1 g condition that is degraded beyond that anticipated during normal plant ,,,; ){ J operations. The ICC conditions could result from operator error or a # # combination of equipment failures. In order to induce ICC, established 8 jI
, operating procedures must have been violated or equipment failures 3 8
gecacer than considered credible in design criteria have occured. !j 3 This procedure is to be considered as a guide to avoid ICC and not a replacement for procedures which refer to specific accidents or conditions. On CE plants the core is protected from DNB by either the TM/LP Trip or loss of flow trip. These systems trip the reactor automatically if the design DNBR is approached, assuring that a lower DNBR, which could lead to ICC, is not reached. A postulated flow blockage in the core support plate or fuel channel would result in a flow maldistribution in the core. that could result in a lower DNBR. Any evidence of core non-symmetry should be investigated. The operator should be aware that Natural Circulation may be temporarily lost due to the isolation of a Steam Generator. As the temperature of that Steam Cenerator increases (due to metal temp) above the RCS temperature, a reverse flow will result, causing a. temporary loss of Natural Circulation. As the RCS heats above the Steam Generator, Natural Circulation will begin again. This should not necessarily be the time to open tha PORV's to establish core flow. However, core parameters . should be closely monitored during this period. Loss of feedwater to both S/G during power operation has the potential of producing conditions which could lead to ICC. Compliance with LOCA guidelines assures that the appropriate corrective actions are accomplished. Tne LOCA discussed is synonymous with a small break LOCA. Do not exceed 750 F/hr cooldown rate during steam dump operation. If a SIAS occurs, operate the HPSI pumps until the RCS is at least 20
.subcooled, and there is level indication in the przr. Restart HPSI pumps as necessary to maintain this condition.
, If RAS occurs assure that flow rates are > minimum HPSI pump flow, (30 gpm). If necessary stop charging pps until one HPSI pp is operating. Rascart pps as necessary to maintain 20* F subcooling. Maximum safety injection flow and PORV operation is suggested only as an alternative due to multiple malfunctions. It is the least desirable means of inventory and pressure control. R1 1 I
Pago 5 of 5 tCC EMERGENCY PROCEDURE NUMBER 2-0120043 _(ICC) REVISION 1
7.0 REFERENCES
Mr 7.1 St. Lucie Unic #1 Emergency Procedures / i 7.2 St. Lucie Unit #1 FSAR Chapter 6 , ? I,*- 7.3 CE guidelines CEN 152 'h3h 7.4 Draft of NUREG 0799 8.0 RECORDS REQUIRED: 8.1 Normal log entries I 1 3 8.2 Applicable recorder charts --
9.0 APPROVAL
Reviewed by the Facility Review Group October 12, 1982 Approved by C. M. Wethy , Plant Manager October 14 1982 REV / Reviewed by the Facility Review Group ,R c 1,' 19 2 Approved by 1 t / >iev M lant Manager ,-,,_ ac 19 n i
"L A S T P A G E" .
TOTAL NO. OF PAGES 5 r h
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Page 1 of 7 Emergency Procedure 2-0700040 Rev 1 LOF
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FLORIDA POWER & LIG'dT COMPANY ST. LUCIE PLANT UNIT 2 EMERGENCY PROCEDURE NUMBER 2-0700040
, REVISION 1 LOSS OF FERDWATER OR S/G LEVEL OCTOBER 22, 1982 l
t TOTAL NO. OF PAGES 7
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Pego 2 of 7 LOF EMERGENCY PROCEDURE NUMBER 2-0700040 REVISION 1
! es 1
1.0 SCOPE
Provide actions to control plant during a loss of main feed or staam generator level.
2.0 SYMPTOMS
I
#//
2.1 Low feed pump succion pressure Feed pump suction sigma on RTG3 202 and applicable alarms 2.2 Feed pump trip Feed pump amps and Red / Green indicator lights on RTGB 202 and applicable alarms. 2.3 Low-Low steam generator level Steam generator level sigma's and recorders on RTG3 202 and applicable alarms. 2.4 Steam flow greater than feed Steam / feed flow flow and decreasing steam recorders on RTGB 202. generator level. NOTE Main feed rupture, main steam line break, LOCA and steam generator tube rupture have some similar indications, Figure 1 may provide assistance in accident analysis. R1
EMERGENCY PROCEDURE UUMBER 2-0700040 Page 3 of 7
. RE"ISION 1 Loy '
~
FIGURE .1 - BREAX DIOGNOSTIC CHART g - % .s - e
]
L.=.: .- l
/
IF _2RESSURIZER LEVEL C'riANGING p Gr-- J d3 AND PRESSURIZER PRESSURE RAPIDLY DECREASING AND STEAM GENERATOR PRESSURE o , ABNCRMALLY LOW IN ONE' OR NORMAL OR RIS!NG & BOTH STEAM GENERATORS 3 mb t c. .DWATER OR S~c.AM LINE 5REAK LOCA i ANbIF _ ANdIF CCNTAINMENT PRESSURE CONTAINMENT PRESSURE 4 4
, o UP NORMAL
- UP NORMAL +
AND CCNTAINMENT THEN THEN E RADIATICN NO MS/FW EREAK MS/FW SREAK INCREASING IN CTMT CUTSIDE OF TNEN THEN
.MS=EP2-0810040 CTMT LOCA S/G TUEE FW=EP2-0 TOC 040 MS=EP2-0810040 EP2-G12OO41 RUPTURE FW=EP2-0TOOC40 EP2-Ol2OO4.
*MAY DECREASE SLIGHTLY AFTER REACTOR TRIP
Pego 4 of 7 LOF EMERGENCY PROCEDURE NUMBER 2-0700040 REVISION 1
, cf *%,,
J 3.0 AUTOMATIC ACTIONS: j d } homE h ) 3.1 Reactor Trip If steam generator-levels go below 39%. 3 / y/
# ,j f .
3.2 Turbine Trip On reactor trip-I [r d.f _ $ 3.3 Generator lock-out On turbine trip 3.4 Runback To 92% on loss of both heater drain pumps Oj! to 60% on loss of 1 feed pump. 3.5 Aux Feed Actuation Signal (AFAS) Steam generator level goes below 39% 4.0 IMMEDIATE OPERATOR ACTIONS: 4.1 Lamediat e operator actions, if transient causes reactor trip 4.1.1 Perform immediate operator actions of OP #2-0030130,
" Reactor Trip".
4.1.2 If steam generators are Faulted' steam g4nerator below 39% level insure AFAS is indicated by a has aligned the aux feed difference in steam system to feed the non-faulted pressure or feed steam generatoes pressure between A & B generators. 4.1.3 If SIAS is actuated insure CEA's RCP's may be restarted inserted greater than 5 sec.'s if LOCA has not occured and stop RCP's. 200 subcooling is achieved and pzr level and pressure control is gained. 4.2 Immediate Operator Actions, if Transient has Not caused Reactor Trip 4.2.1 Insure steam generator Steam flow must equal levels cau be maintained feed flow, indicated with available main feed on RTGB 202. or reduce steam demand until levels can be , maintained. 4.2.2 If runback occurs insure TAV = TREF RX power is matched with turbine, power. R1
Pcgs 5 of 7
~
LOF EMERGENCY PRO'CEDURE NUMBFR 2-0700040 REVISION 1
, p "*c. ,
5.0 SUBSEQUENT ACTIONS: ! t ) S...i )
~~~ i Check I
- . /
5.1 If feed rupture has occured all available means /l' should be used to isolate it, while maintaining d ,, at least 1 steam generator as a heat sink. _ _ _ _ - .j 5.2 If Reactor Coolant Pumps were tripped in step 4.1.3 action should be taken to establish conditions necessary for restarting them. 5.3 One condensate pump should be left running, if_ possible, for secondary equipment cooldown and protection. 5.4 If transient did not cause reactor trip, establish stable plant conditions and identify and correct cause of loss of feed. 6.0 PURPOSE / DISCUSSION: 6.1 This procedure provides instructions to be followed in the event of loss of feedwater flow and/or loss of steam generator level. It is to be used when specific symptoms indicate this condition and the immediate actions of the Reactor Trip / Turbine Trip procedur,es have been completed. 6.2 Loss of steam generator level results in a reduction in capability of the secondary system to remove the heat generated in the reactor core. Loss of steam generator level results from the inability to supply feedwater in an amount equal to the existing steam demand. Excessive steam demand, i.e., above feedwater system capability is considered in Emergency OP 2-0810040, Main Steam Line Break. 6.3 The loss of all feedwater to the steam generator and the subsequent heatup of the Reactor Coolant System will result in saturation conditions at high temperature and pressure in the Reactor Coolant System. This would cause a loss of reactor coolant mass through the FORV's and code safeties and void formations throughout the system. A maximum effort should be directed toward the initiation of feedwater flow to the steam generators. Without feedvater, the steam generators could boil dry within approximately 13 minutes. 6.4 The inability to supply feedwater in the required quantity could result from one or a combination of the following: 6.4.1 Pipe break in the condensate /feedwater system. 6.4.2 Flow path blockage due to valve closure or strainer stoppage. 6.4.3 Loss of pumping capacity due to pump trip, loss of AC power, or pump cavitation. R1
Prgo 6 of 7 LOF EMERGENCY PROCEDURE NLMBER 2-0700040 REVISION 1
/% '
$ ,B ' I 6.0 PURPOSE / DISCUSSION: (Cont.) iJy w
'i 1
6.5 The following protective functions are provided to prevent loss of 9} ,f l heat sink. / a) Reactor trip: I"=m Steam generator low-low level &t 39%. b) Turbine Runback; due to:
- 1. Loss of both heater drain pumps if turbine power is 2;92%.
"0R"
- 2. Loss of feedwater pump if turbine power is
};60%.
6.6 The action taken for loss-of steam generator level is basically the same regardless of cause. That is, to trip the reactor, thereby removing the heat source, and restoring steam generator level with the auxiliary feedwater pumps. This approach is due to the self-sufficient nature of the auxillery feed system. It, in no way, depends on the normal feedwater system. Three auxiliary feed pumps are available. Two motor driven pumps, either of which can, supply either steam generator and one steam driven pump which can supply either steam generator. The leak must be isolated in any incident involving a break even though the break does not immediately affect the auxiliary feedwater system. The isolation of a leak is necessary to conserve the water available in the condensate storage tank. The leak is isolated by stopping the steam generator feed pumps and condensate pumps. R1 4 0
Ptgs 7 of 7 LOF EMERGENCY PROCEDURE NLHBER 2-0700040 REVISION 1 7% J 7
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7.0 REFERENCES
k 7.1 FSAR, Section 15.2.8 and Section 10.5.3 < , 7.2 Combustion Engineering Emergency Procedure F-EP-9 7.3 C.E. LOF guidelines, CEN-128 7.4 FP&L EP 0700040 Rev. 8 (Unit 1) (Loss of Feedwater or Steam Generator Level) 7.5 Drafe of NUREG 0799 8.0 RECORDS REQUIRED Log Book Entries Applicable chart recorders 9.0 APPROVAL Reviewed by the Facility Review Group October 12, 1982 Approved by C. M. Wethy Plant Manager October 14, 1982 Rev. / Reviewed by Facility Review Group m - r- J (. 19 d A Approved by / / i L N b lant Manager ,. v- r! 19 L ~
*/ .
"L A S T P K G E" Emergency Procedure 2-0700040 Rev.1
. TOTAL NO. PAGES 7
U!(IT II CCCU ENT REV!SION CISTRI3CTION SEEIT - ory yop,w,At 5 ,mIRGE'CY CPER. ?ROCEDURE CCCUIENT TITLZ [//M/ h/ 87YW/ ) b44 A (# A /( Cec :ENT 7::.z t<Uteza cCCairNT arv:S:Cu treM3ra U -o f2c / o o Md 8 d CCCU:ENT DIST2:3CCD ON / # " 2- [ CATE CCCCENT, SENT TC: COPY TRANSMI"" AL COPY NC. TRANSMITTAI. OCCOMENT ECLDER REW? LED NC. CCCUMET2 HOLDER PITJRNID MASTER UNCONTROLLED COPIES 1 D. A. Sager 2 3 NRC - Region II 4 Aten: E??S Branch Chief 5 N. G. Roos H. Paduano - GO 6 TSC A. W. Bailey 7 G. Anglehart - CE 8 9 10 Watch Engineers II G. Regal 11 12 Ugelow, Al ~34ckfi: 13 Training - Larry Ba'e er
~
14 15 Training J. Spodick T. Vogan - GO G. J. 3oissy R. R. Jennings H. M. Mercer A. Pell R. J. Frechette dent _NRC NRC - IE: HQ ( Atta: Chief, Nuclear Response 3 ranch C. Burns _ , PROCISSID 3T: [ M CAC /#~ D
i Page 1 of 20 Emergency Procedure 2-0810040 M.S.L.3. Rev.0 -% g i
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FLORIDA POWER & LIGHT COMPANY ST. LUCIE PLANT UNIT 2 EMERGENCY' PROCEDURE NUMBER 2-0810040 REVISION O October 25, 1982 MAIN STEAM LINE BREAK REV. FRG. Approval Pit.Mngr. TOTAL NO. OF PAGES 20 FOR I?!F0T!;.ini!0:1 ONLY This document is not control!:d Befo 8 '50 verify information with a controlled do:ument.
Page 2 of 20
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FLORIDA POWER & LIGHT COMPANY g
... ST. LUCIE PLANT UNIT 2 # i EMERGENCY PROCEDURE NUMBER 2-0810040 l e x REVISION 0 *
[,,j} p i 4/
) s?
1.0 SCOPE
#- d'
, f iw-Provide operator actions to be taken when an uncontrolled steam release k n=o=aa3 occurs from a steam generator. -
2.0 SYMPTOMS
h NOTE: Figure 2.1, page 5, may assist.in evaluating this event. 2.1 Loud noise audible in the 2.1 Indications , E control room Steam breas outside containment 2.2 Continuously decreasing TAVE 2.2 Indications Excess steam demand frome secondary syst+a TR-1111, TR-il21, (RIGB 134) TR-1120E 2.2 Alarms K-25 2.3 Abnormally low pressure 2.3 Indications in one or both steam PI-8023A,3,C,D generators. PI-8013A,B,C,D PR-8013D, 8023D \' 2.3 Alarms Il
'I P-17,P-19 s is s
1 1 s i
Page 3 of 20 M3L3 i ST. LUCIE PLANT UNIT 2 7 l MAIN STEAM LINE BREAK EMERGENCY PROCEDURE NUMBER 2-0810040 fp% 3j j 4, REVISION O c j
,2
./
2.0 SYMPTOMS
(Cont.) g 2.4 Rapid decrease'S/G 1evel 2.4 Indications k_ k
=_.,'tu
._j LR-9013D, 9023D LR-9011, 9021 LIC-9013-A,B,C,D LIC-9023-A,B,C,0 LIA-9012, 9022 LA-9012/9022 2.4 Alarms G-1, G-9 2.5 Reactor Trip 2.5 Indications Turbine Trip CEA's inserted (ADS)
RPS-CH.4, CH.1, CH.7 or CH.9 RPS-RIB's Open Gen. Output -0 , W-REC-81, core mimic 2.5 Alarms L-17, L-9, L-11, L-3, L-36, L-44, L-5, L-13, D-8 2.6 A. Increased steam flow 2.6 Indications
,f feed flow Until MSIS occurs B. Decreased' generator output FR-8011,9011 FR-8021, 9021 , FI-08-1A,1B, FI-09-1A,1B, .! W-REC-81
): 2.6 Ala rms G-17 2.7 Decreasing Ptessurizer level and 2.7 Indications pressure LI-1110X,Y,LIC-1110X,Y PI-110 2A, B , C , D t' - PR-1100, LR-1110, LR1110X
\ 2.7 Ala rms H-9,H-10,H-17,H-18,H-25, H-26,H-1,H-2,H-3,H-4 2.8 Containment Radiation 2.8 Indications monitors are normal NO hi radiation alarms from Entainment. Differentiates between LOCA and MSLB.
is I . i e __ - . _. . _ - . - m.
Pago 4 of 20 MSLB 37 [ ,., %( ST. LUCIE PLANT UNIT 2 MAIN STEAM LINE~ BREAK $ j . EMERGENCY PROCEDURE NUMBER 2-0810040 REVISION O 6 ]3 g}+ AV ,-
2.0 SYMPTOMS
(Cont.) 2.9 El Containment Pressure 2.9 Indications g, _j Break inside containment PIS-07-2A,23,2C ,20 2.9 Alarms P-13,P-23 2.10 Containment Reactor Cavity 2.10 Indications Samp level increasing Break inside containment LIS-07-6,FR-07-3 2.10 Alarms N-21,H-29 2.11 MSIS Actuated 2.11 Indications Equipment isolates as per cable 1 2.11 Alarms P-7,P-9,P-17,P-19 2.12 SIAS, CIAS Actuated 2.12 Indications Equipment starts and-isolates per table II and cable III 2.12 Ala rms R-6,R-16,R-26,Q-3,P-3, P-13,P-23 2.13 CSAS Actuated 2.13 Indica. ions Equipment operates per table IV 2.13 Alarms S-7,S-27 0
Pegs 5 of 20 MSLB [,% " ST. LUCIE PLANT UNIT 2 ' l' MAIN STEAM LINE BREAK 4 5' EMERGENCY PROCEDURE NUMBER 2-0810040 Dj ~ REVISION O A if f FIGURE 2.1 # p BREAK IDENTIFICATION CHART J PRESSURIZER LE'!E'. CHAT:GIi:G. Afl0 PRESSURIZER PRESSURE PAPIOLY DECREASI?iG
.. SG YES PRESSURE fiO+
ABriORi4 ALLY - LOW
- V . .. V SEC0fiOARY PRI;4ARY
~
SIDE ~ TIDE BREAK BREAK YES C0!!TAlit?tEfl pgg33ggg fi0 YES C0i! TAI!!!!E IT li0 It!CRE!SIflG PRES SU.S.C ilCREASIt:G V ' V U 57 itAIt! STEAi4/ i4Alti STEAti/ LOCA SGTR CP, FEEOUATER FEEDWATER INSIDE SBLOCA BREAK It! . BREAK OUT OF C0iiTAltiME?iT GUTSIDE COMTAI!:".E::T CO.3tTAlt:t!E:IT CO:ITAI;CiE:!T
*Ill CilE OR BOTH -
+F%Y CECREASE STEA!I GEliE?.ATORS SLIGHTLY AFTER TRI?
Pcgt 6 of 20 MSLB ST. LUCIE PLANT UNIT 2 MAIN STEAM LINE BREAK e-k'~ EMERGENCY PROCEDURE NUMBER 2-0810040 REVISION O Qf h JV ." 3.0 IMMEDIATE AUTOMATIC ACTION: # .f"
~~
AUTOMATIC ACTION INITIATING EVENT 5 3
# a 3.1 Reaccor Trip 3.1 S/G low press 600 psia decreasing 3.2 Turbine trip 3.2 Reactor trip bus low voltage 3.3 Generator lock-out 3.3 Turbine trip /Bkrs closed 3.4 Auxiliaries change to 3.4 From gen. lock-out Start-up transformer 3.5 MSIS 3.5 600 psia S/G press.
decreasing or 5 psis cont. press increasing 3.6 SIAS 3.6 1600 PSIA RCS press.
. decreasing or 5 psig cont.
press increasing 3.7 CIAS 3.7 5 PSIG cont. press. increasing or H1 cont. radiation > 10 R/HR or from SIAS actua' tion. 3.8 CSAS 3.8 10 psig cont. press. concurrent with SIAS 3.9 AFAS (feeds only the 3.9 S/G level < 39% non-faulted S/G)
Pego 7 of 20
. MSLB ST. LUCIE PLANT UNIT 2 ,j g "
MAIN STEAM LINE BREAK 9 .m EMERGENCY PROCEDURE NUMBER 2-0810040 '. REVISION O f j j. 4.0 IMMEDIATE OPERATOR ACTION:
*--~'
ACTION NOTES g La-n:.J 4.1 Carry out staudard immediate 4.1 If necessary, refer to operator actions on a reactor RX Trip Procedure trip OP #2-0030130 4.2 Ensure SIAS actuates if 4.2 SIAS actuates on: if conditions require. 1600 psia low RCS press. 5 psig Hi cont. press. If SIAS actuates on low RCS pressure, after verification of all rods inserted > 5 sec. then stop all Reactor Coolant Pumps. 4.3 Ensure MSIS actuates if 4.3 MSIS actuates on: conditions require 600 psia low S/G press. 5 psig hi cont. press. 4.4 Determine affected generator 4.4 Observe S/G pressures and levels 4.5 Ensure AFAS is establishing flow only to the non-effected generator. r
Page 8 of 20 MSLB ,,,==g., , ST. LUCIE PLANT UNIT 2 N MAIN STEAM LINE BREAK f f% EMERGENCY PROCEDURE NUMBER 2-0810040 W,l REVISION O ,f
.-? $
5.0. SUBSEQUENT ACTIONS: /' .! '
"~
CHECK fL---'4*=- 5.1 Use all available indications to determine sub-cooled or saturated conditions in the RCS. If this occurs the operator must ensure that the RCP's are turned off, the SIS is providing makeup to the RCS, and that the operable steam generator is removing heat from the RCS. NOTE: Information can be obtained from the SPDS display, RCS hot leg temperature, RCS cold leg temperature, incore thermocouple temperature and RCS pressura to determine if the RCS is sub-cooled or saturated. An increase in temparature above the saturation temperature for the existing pressure is an indication of voiding in the RCS. (P-T Nomograph Available on RTGB-203) 5.2 Check the ESFAS BYPASS STATUS BOARD (ensure equipment availability for auto functions). Refer to Tables to ensure the proper operation of engineered safety features as time and ~ conditions permit. 5.3 Implement the Emergency Plan as necessary in accordance with EPIP 3100021E, " Duties and Responsibilities of the Emergency Coordinator". 5.4 Isolate steam generator blowdown; close FCV-23-3, 5, 4, 6 and sample FCV-23-7,0 5.5 When S/G level rises > 39%, take control of aux. feed to halt further feeding of relativly cold water until cooldown transient has terminated. NOTE: Erroneous indications may be observed > 15 minutes after a break inside containment.
Page 9 of 20 MSLB ST. LUCIE PLANT UNIT 2 fwww ,
.f .
MAIN STEAM LINE BREAK j N .' EMERGENCY PROCEDURE NUMBER 2-0810040 dj REVISION O , fja 5.0 SUBSEQUENT ACTIONS: (Cont.) / M CHECK i 5.6 When the cooldown has stopped and RCS h=" temperature is above 4000 F, reinciate aux. feed flow to non-faulted steam generator not exceeding 150 GPM for a period of 5 minutes. Maintain RCS temp. stable with atmospheric dumps on non-effected generator. 5.7 Maintain hot leg temperature less than 520 F with auxiliary feed and steam dump
. to atmosphere. __
NOTE: Do not admit auxiliary feed flow to the faulted steam generator regardless of location of break. 5.8 When pressurizer level on control channels indicates 30% energize all pressurizar heaters to aid in increasing RCS pressure. 5.9 When pressurizer level indicates 40% secure all charging pumps. 5.10 As hot leg temperature is maintained less than 5200 F verify that pressurizer press. stabilizes at approximately 1250 PSIA (shut off head of HPSI) NOTE: Ensuring hot leg temperature less than 5200 F and pressurizer pre'ssure greater than 1250 psia ensures a margin of 50 0F subcooled. 5.11 Stop emergency diesel generators if offsite power is available and feeding the emergency buses. 5.12 When containment pressure is < 10 PSIG a) Reset CSAS b) Stop CS pumps c) Close FCV-07-1A, 1B o O
Page 10 of 20 MSLB ST. LUCIE PLANT UNIT 2 y#,,,*t MAIN STEAM LINE BREAK (( g k EMERGENCY PROCEDURE NLWBZR 2-0810040 REVISION O y j s}P 4 5.0 SUBSEQUENT ACTIONS: (Cont.) - CHECK l!.V y
/ i 5.13 OPEN ICW to TCW Heat Exchangers a ,)
MV-21-3, MV-21-2. 5.14 CLOSE CCW outlet from SDC Heat Exchangers, RCV-14-3A, 3B. 5.15 Restore CCW on the RCP's by performing the following steps: 5.15.1 Open the "N" header supply and return valves from A and B CCW header:
"0VERRIDE" HCV-8A, HCV-9 (A side)
"0VERRIDE" HCV-8B, HCV-10 (B side)
(Taking these valves to "0VERRIDE" position will open valvas) SIAS signal present. 5.15.2 Restore CCW to containment "N" header by opening containment isolation valves: -
~
"0 PEN / RESET" HCV-14-2 "0 PEN / RESET" HCV-14-6
, "0 PEN / RESET" HCV-14-1 "0 PEN / RESET" HCV-14-7 (Taking valves to "0 PEN / RESET" position will override SIAS signal) 5.15.3 Restore CCW to individual RCP's seal coolers by opening valves: Open HCV-l'4-il-1A1 Open HCV-14-il-LA2 Open HCV-14-il-131 Open HCV-14-ll 132
. NOTE: It may be necessary to cycle these valves to restore flow.
i
- -. .--.n,
Pego 11 of 20 ST. LUCIE PLANT UNIT 2 # MAIN STEAM LINE BREAK ( EMERGENCY PROCEDURE NUMBER 2-0810040 REVISION O Q. A/f e'
,1 5.0 SUBSEQUENT ACTIONS: (Cont.) 7 4'
;? r.
CHECK f1 __. 5.16 When at least 20 degrees subcooling has been re-established, and control of pressure and level have been regained, the HPSI pumps can be secured. 5.17 once control of transient has been gained with normal pressure control, the safety injection signal may be reset by first key-blocking the ESFAS SIAS signal, then 4 manually resetting the SIAS signal present by taking the channel control switches to the reset position. 5.18 Once SIAS signal has been reset, the CIAS ESFAS signal can be reset by taking the CIAS channel control switches to the reset position, allowing control of the letdown isolation ealves. 5.19 When CIAS has been resot, open the letdown isolacton valves, and es-establish charging - and letdown per OP #2-0210030, " Charging and Letdown off-Normal Procedure". 5.20 Resume forced cooling as soon as conditions permit. 5.21 Notify Chen. Dept. to sample RCS for indications of fuel failure. 5.22 Continue controlled cooldown in accordance with OP #0030127. NOTE: If containment spray system has actuated, portions of the containment spray i system will contain Hydrazine. ) 9
Page 12 of 20 MSLB # ST. LUCIE PLANT UNIT 2 -7 4 MAIN STEAM LINE BREAK
]e EMERGENCY PROCEDURE NUMBER 2-0810040 REVISION O ?)Y.
TABLE I [;t'W, [,/ a MAIN STEAM ISOLATION SIGNAL (MSIS) _3 CONDITION CHECK One (1) Main Steam Line A ISOL. Valve HCV-08-1A closed One (1) Main Steam ISOL. Valve A bypass MV-08-1A closed Two (2) W. DISCH. to S/G 2A IICV-09-1A, HCV-09-1B closed Two (2) W. DISCH. to S/G 2B HCV-09-2A, HCV-09-23 closed One (1) Main Steam ISOL. Line B ISOL. Valve HCV-08-1B closel One (1) Main Steam ISOL. Valve B bypass MV-08-1B closed 'l i l t l I' l
Pega 13 of 20-
- MSLB <2g ST. LUCIE PLANT UNIT 2 , T MAIN STEAM LINE BREAK j f'g EMERCENCY PROCEDURE NUMBER 2-0810040 (4; }
REVISION O 'l , 51 TABLE II E gI 8
* ),
SAFETY INJECTION ACTUATION SIGNAL (SIAS) 1 .._ ~ a CONDITION CHECK RTGB 206, Left to Right Two (2) CCW Pp (2A, 2B, or 2C) On Two (2) CCW to Fuel Pool HX Isolation Valves (MV-14-17, MV-14-18) Closed Four (4) CCW HDR Non-essential Isolation Valves (HCV-14-8A, HCV-14-8B, HCV-14-9, HCV-14-10) Closed Two (2) CCW Outlet Valves from shutdown HX 2A, 2B (HCV-14-3A, HCV-14-3B) Open Two (2) LPSI PPS On Two (2) HPSI PPS On Four (4) LP3I Disch Valves to Loops (HCV-3615, HCV-3625, HCV-3635, HCV-3645) Open - Eight (8) HPSI Disch Valves to Loops (HCV-3617, HCV-3627, HCV-3637, HCV-3647 - Header A) (HCV-3616, HCV-3626, HCV-3636, HCV-3646 - Header B) Open Two (2) Hot Leg Injection Check Viv. Leakage Valves. (V3572, V3571) Closed Two (2) SI Test to RWT (I-SE-03-2A,
- I-SE-03-23) Closed Four (4) SI Tank Isolation Valves (V3614, V3624, V3634, V3644) Open Four (4) SI Tank Fill / Drain Valves (I-SE-03-LA, I-SE-03-13, I-SE-03-lC, I-SE-03-lD) Closed Four (4) SI Check Leakage Te ot -
(HCV-3618, HCV-3628, HCV-3638, HCV-3648) Closed Four (4) CCW To/From RCP's (HCV-14-1, HCV-14-2, HCV-14-7, HCV-14-6) Closed
. Page 14 of 20 ST. LUCIE PLANT UNIT 2 ,,
MAIN STEAM LINE BREAK EMERGENCY PROCEDURE NUMBER 2-0810040 l ? y7 ( REVISION O ji e TABLE II (Cont.) SAFETY INJECTION ACTUATION SIGNAL (SIAS) " m? CONDITION CHECK RICB 205 Two (2) Boric Acid Make-up Pumps 2A and 2B Start Two (2) Boric Acid Make-up Tank Recire Viv's 2A (V-2650), 2B (V-2651) Closed One (1) Boric Acid Make-up Viv (V-2512) Closed Two (2) Boric Acid Gravity Feed Viv's (V-2508, V-2509) Open One (1) Volume Control Tank Discharge Viv. (V-2501) Closed Two (2) Letdown Isolation Viv's (V-2516, V-2515) Closed Start Three Charging Pumps . (2A, 2B and 2C) Signal One (1) Boric Acid Make-up Flow Viv (FCV-2210Y). Closed Two (2) Containment Sump Isolation Valves Closed (LCV-07-llA, LCV-07-11B) Two (2) Intake Cooling Water, Lube Water to Cire. Water Pumps, Isolation Valves (XV-21-41, MV-21-43) Closed RTCB 202 Two (2) Intake Cooling Wer Pumps On Two (2) Intake Cooling Wtr Isolation Valves (MV-21-3, MV-21-2) Closed ITGB 201 Two (2) Diesel Generators On O
, Page 15 of 20 ST. LUCIE PLANT UNIT 2 #
j +g MAIN STEAM LINE BREAK '
#3 i EMERGENCY PROCEDURE NUMBER 2-0810040 '4 ;
REVISION O s TABLE II (Cont.) - fj e SAFETY INJECTION ACTUATION SIGNAL (SIAS) "" M 9.__ 3 HVAC PANEL LEFT TO RIGHT Four (4) RAB Main Supply and ECCS Exhaust Fans (2-HVS-4A, 2-HVE-9A, 2-HVS-4B, 2-HVE-9B) on Four (4) Containment Fan Coolers On slow (2-HVS-1A, 2-HVS-13, 2-HVS-1C, 2-HVS-lD) Speed Eight (8) ECCS Isolation Dampers (USA, D6A, D9A, D12A, D53, D9B, D12B) Closed NOTE Any spare equipment that is running and not needed for controlling this incident should be STOPPED. e 1
Pegs 1,6 of 20 MSLB, # ST. LUCIE PLANT UNIT 2 , / ]2 MAIN STEAM LINE BREAK i > EMERGENCY PROCEDURE NUMBER 2-0810040 REVISION O b I)J [ j' j7
.9 ,1 TABLE III
[ _j~ . CONTAINMENT ISOLATION ACTUATION SIGNAL (CIAS) ] ' CONDITION CHECK ETGB 206 Left to Right Two (2) SI Tank return to RWT (I-SE-03-2A, I-SE-03-2B) Closed Five (5) SI Tank Sample Isolation valves (FCV-03-1A, FCV-03,lB, FCV-03-LC, , FCV-03-lD, FCV-03-lE) Closed Four (4) S/G Blowdown and two (2) S/G Sample Isolation Valves (Isolation FCV-23-3, FCV-23-5, FCV-23-4, FCV-23-6) (Sample FCV-23-7, FCV-23-9) Closed Two (2) Containment Sump Isolation Valves (LCV-07-11A, LCV-07-113) Closed Six (6) RCS and pressurizer Sample Isolation valves (V5200, V5201, V5202, V5203, VS204, V5205) Closed One (1) Primary Water Isolation (HCV-15-1)
~
Closed ~ One (1) Instrument Air Isolation (HCV-18-1) Closed , One (1) N2 Supply Isolation (V6741) Closed Two (2) Waste Gas Isolation (V6750, V6718) Closed Two (2) RCP Bleed-off Isolation (V2505, V2524) Closed Two (2) RDT Isolation (V6341, V6342) Closed RTGB 205 Three (3) Letdown Isolation Valves (V2516, v2522, V2515) Closed RTGB 201 Two (2) Diesel Generators On HVAC Panel Left to Right Two (2) Shield Bldg. Ventilation and Control Room Filter Fans (2-HVS-13A, 2-HVE-6A) On Four (4) Control Room Isolation Valves (FCV-25-24, FCV-25-17, F V-25-18, FCV-25-16) Closed 0
P ga 17 of 20 ST. LUCIE PLANT UNIT 2 ' /* MAIN STEAM LINE BREAK j ,r, j EMERGENCY PROCEDURE NUMBER 2-0810040 .Q j 1 REVISION O f
- j
- 7 TABLE III (Cont.) "
../
CONTAINMENT ISOLATION ACTUATION SIGNAL (CIAS) CONDITION CHECK Two (2) Shield Bldg. Ventilation and Control Roon Filter Fans (2-HVS-13B, 2-HVE-6B) On Four (4) Control Room Isolation Valves (FCV-25-25, FCV-25-14, FCV-25-15, FCV-25-19) Closed Two (2) Containment Purge. Exhaust Fans (2-HVE-8A, 2-HVE-8B) Off Six (6) Containment Purge Isolation Valves (FCV-25-1, FCV-25-3, FCV-25-5, FCV-25-6, FCV-25-4, FCV-25-2) Closed Three (3) Continuous Containment H 2 Purge Isolation (FCV-25-20, FCV-25-26, FCV-25-21) Closed Two (2) Shield Bldg. Vent. Isolation Valves (FCV-25-32, FCV-25-33) open Two (2) Fuel Bldg. Emerg. Ventilation Isolation Valves (FCV-25-30, FCV-25-31) Closed Six (6) Containment Sample Isolation Valves (FCV-26-2, FCV-26-4, FCV-26-6, FCV-26-1, FCV-26-3, FCV-26-5) (RTCB 206) - Closed
~ .
Page 1"8 of 20 MSLB ST. LUCIE PIJLTI UNIT 2 MAIN STEAM LINE BREAK ( 3 9 4 EMERGENCY PROCEDURE NUMBER 2-0810040 4 2 REVISION O ., ;
*l TABLE IV 7 CONTAINMENT SPRAY ACTUATION SIGNAL (CSAS)
{ ll ]a
- CONDITION CHECK Two (2) Containment Spray PPS. 2A, 23 On Two (2) Containment Spray HDR. ISOL.
j Valves FCV-07-1A, 1B Open Two (2) Iodine Removal System PP's 2A, 2B Cn Two (2) Iodine Removal System ISOL. Valves I-SE-07-3A, 3B Open l NOTE: Verify Flow on F1-07-LA, 1B l e W 4 o
, - _ . , . _ _ . . - , , . - . . . - _ , , , _ _ , .-.1
Pcg2 19 of 20
. MSLB y;**" q ST. LUCIE PLANT UNIT 2 y ,
MAIN STEAM LINE BREAK j f ' EMERGENCY PROCEDURE NUMBER 2-0810040 b=4}) REVISION O / .;
6.0 PRECAUTIONS
/ p
.l
/
e L-r..: A rupture of a steam line is assumed to include any accident which [ _, results in an uncontrolled steam release from a steam generator. The release can occur due to a break in a pipe line or from the malfunction of an atmospheric dump valve, steam dump and bypass valve or safety valve. The steam release results in an initial increase in steam flow which decreases during the accident as the steam pressure falls. The energy removal from the Reactor Coolant System causes a reduction of coolant temperature and pressure. This transient results in the RCS being at saturation conditions with the potential for void formations in the system. Operator actions should be directed toward establishing subcooled conditions in the Reactor Coolant System. Core protection af ter a break would be provided by MSIS at 600 PSIA steam generator pressure or 5 PSIG containment pressure (break inside containment) and SIAS at 1600 PSIA pressurizer pressure or 5 PSIG containment pressure (break inside containment). All available indications should ha used to aid in diagnosing the event since the accident may cause irregularities in a particular instrument reading. Critiegl parameters must be verified when one or more confirmatory indications are available. With the safety parameter display system (SPDS) operating normally, use the nomograph, in conjunction with the SPDS to eliminate dependence on a single . instrument. With the SPDS inoperable refer to the nomograph utilizing control room indicators such as T he pressurizer pressure and incore thermocouples to determine the margin to saturation. Subcooling margin can also be deterained by subtracting hot leg temperature from pressurizer temperature. 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 must ensure that the RCP's are turned off, the SIS is providing makeup to the RCS, and that the operable steam generator is removing heat from the RCS.
i Pega 20 of 20 ST. LUCIE PLANT UNIT 2 ' .f" .., MAIN STEAM LINE BREAK + ca - _ EMERGENCY PROCEDURE NUMBER 2-0810040 REVISION O gl[ } j j
7.0 REFERENCES
- t n 4[
FSAR Sect. 6, 7, 15 l "94
.s OP. Proc. 0810040 (Unic #1)
C. E. Guidelines ~(CEN-152) Draft of Nureg - 0799 8.0 RECORDS REQUIRED: Normal log entry Recorders covering transient conditions
9.0 APPROVAL
. Reviewed by Facility Review Group A //.')d/Y[2 Approved by d///h t [\ Plant Manager ,
,e dj/
/ ~
Revision _ Reveiwed by FRG Approved by Plant Manager LAST PAGE Emergency Procedure 2-0810040 Rev.0 TOTAL NO. OF PAGES 20 4 0}}