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Public Version of Revised Offnormal & Emergency Operating Procedures,Including Procedures 2-0030140 Re Blackout operator,2-0030143 Re Total Loss of Ac Power & 2-0250030 Re Emergency Boration
	ML20079R307
Person / Time
Site:	Saint Lucie
Issue date:	04/26/1983
From:	; FLORIDA POWER & LIGHT CO.
To:	; NRC OFFICE OF INSPECTION & ENFORCEMENT (IE)
Shared Package
ML17214A246	List: ML20079R307;
References
	PROC-830426, NUDOCS 8306220236
	Download: ML20079R307 (87)
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ST. LUCIE UNIT #1 'i EMERGENCY OPERATING PROCEDURE NO. 0030140 / .)

REVISION 26 3

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1.0 Title.: " .9 ",."o' '4 i97 r 3.7 3F ...3..

W 46a '.1 .J' D.4 ]. s BLACKOUT OPERATION This do:umant is not cen;:oded. Eefe.o uts, verify informatien with a eenhol fed document.

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Reviewed Approved byby [ dmPlant3Nuclear Plant SafetyManager Committee (J 4/es / ; --~

19 Revision 25 Reviewed by Facility Review Group - . . .. 19 .

Approved 5 (1@M/1/M Plant Manager 4 . zA - 19 11 Revision 26 Reviewed by Facility Review Group dar-J[ d 19 b Approved by /h L'.e.i_ . . . f' Plant Manager e.d - i 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 3.2.1 A loss of power to the 4160 V buses, results in a loss of power to all 480 V 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 6900 V buses supplying the reactor coolant pumps and will be accompanie'd by a turbine trip and generator lockout.

3.2.2 Steam dump to atmosphere must be used to remove reactor decay heat. Initially, steam generator safety valves may actuate to augment the steam flow and to help control steam generator pressure i= mediately after the trip.

3.2.3 On site power will be supplied by Emergency Generators.

3.3 A rapid reduction in steam generator water levels will occur due to the reduction of the steam generator void fraction on the secondary side and also because steam flow will continue after normal feedwater flow stops. Auxiliary feedwater flow will automatically' initiate 3 minutes after the first steam generator level reaches 34% (2/4 logic).

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"1 ) l 3 i EMERGENCY OPERATING PROCEDURE NO. 0030140, REV 26 3j j j BLACKOUT OPERATION S I

J 3.0 Purpose or Discussion: (Cont'd) 3.4 Core decay heat removal is accomplished by natural circulation in the reactor coolant loops.

3.5 Core damage is not expected as a result of a loss of power condition as the steam generators are maintained as a heat sink and no loss of water occurs from the pressurizer.

3.6 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.

4.0 Symptoms

4.1 Alar =s associated with the loss of operating plant components.

4.2 Loss of normal control room lighting and DC lighting energized.

4.3 Reactor and turbine trip.-

4.4 L:ergency diesel generators start.

4.5 Reactor coolant pump trip and steam generator feed pump trip.

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. 1 Page 3 of 14 E:1ERCENCY OPERATING PROCEDURE NO. 0030140, REV 26 BLACKOUT OPERATION 2_, a 5.0 Instructions :

1 Jf :I 5.1 l= mediate auto action 3 ;

l W 5.1.1 Reactor and turbine trip, generator lockout 5.1.2 Generator breakers open.

4 5.1.3 Incoming feeder breakers open to 4160 V and 6900 V buses.

5.1.4 Tie breakers between Normal 4160 buses (IA2 and 132) and the emergency 4160 V buses (IA3 and IB3) open.

5.1.5 Ties between essential and non-essential sections of emergency 480 V MCC's open.

5.1.6 Breakers open for the following non-safety related loads which are normally fed from emergency buses.

t NOTE: These loads can be manually reconnected to the ,

- emergency buses as needed.

5.1.6.1 Pressurizer heater transformers 1A and 13.

5.1. 6.'2 Fire pump 1A and 1B.

5.1.6.3 CEA Drive M.G. lA & 13.

5.1.6.4 Fuel Handling 480 V MCC 1A8, 1B8/

5.1.6.5 Reactor cavity sump pump 1A 5.1.6.6 Reactor building elevator 5.1.6.7 Electrical equipment room hoisc 5.1.6.8 120/208 power panel 121 transformer 5.1.6.9 Lighting panel transformers 110, 112, 114, 117, 125, 126 5.1.6.10 Incoming feeder from 1A2 & IB2 4160V buses 5.1.6.11 RCP oil lift pumps (8 pumps only - A pumps running) 3.1.6.12 Airborne radioactivity removal fans RVE-1&2

. 5.1.6.13 Pressurizer relief isol valves 1403 & 1405 5.1.6.14 CVCS heat tracing transformer 1A & IB 5.1.6.15 480V Lighting panel 2A, 2B & 2C 5.1.6.16 Waste management heat tracing transformers 2A & 23 5.1.6.17 Air conditioner HVA-4, ACC-4.

5.1.6.18 Pcwer pt--1 120 5.1.6.19 Lighting <anels 113, 116, 109, 115, 130 5.1.6.20 Refueling equipment 5.1.6.21 Refueling water to charging pumps V-2504 5.1.6.22 Boric Acid batching tank heaters 5.1.6.23 Fire siren I

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Paga 4 of 14 EMERGENCY OPERATING PROCEDURE NO. 0030140, REV 26 _,,

BLACK 0UT OPERATION g .]

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Instructions: (cont)

N2 5.1 (cont) .

] Q 5.1.7 }

All loads on emergency buses are tripped except the following: M}k i 5.1.7.1 Boric Acid makeup pumps 5.1.7.2 Charging pumps 5.1.7.3 Emergency lighting 5.1.7.4 Class I power panels 5.1.7.5 RCP oil lift pumps (A pumps only - B pumps off) 5.1.7.6 Diesel' fuel transfer pump.

5.1.8 Diesel generators A & B start and energize 4160 V emergency buses lA3, 1B3, and 1A3 and loads listed in step 5.1.7.

5.1.9 Subsequent loads are started at 3 second intervals.

See Table 1, Emergency Diesel Generator Loading Sequence.

5.1.10 Auxiliary Feedwater auto start sequence initiates when the first steam generator level decreases to 34".

NOTE: Pump start and flow initiation is delayed for 3

=inutes. Pumps may be started by the operator g ANY TIME.

5.2 Immediate operator Actions 5.2.1 Trip turbine and reactor manually.

5.2.2 Check all full length CEA's are fully inserted and reactor trip breakers are open.

5.2.3 Check turbine valves are closed.

5.2.4 Check generator field and 240 KV breakers are open.

5.2.5 Place reheater control system in manual, close TCV's.

5.2.6 Check that diesel generators have started and are feeding only emergency buses.

5.2.7 Open start-up transfor=er breakers.

5 '. 2. 8 Reduce Tavg to reference set point by manual . operation of the steam dump valves to atmosphere.

5.2.9- I'solate steam generator blowdown. j 9

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Page 5 of 14 EMERGENCY OPERATING PROCEDURE No. 0030140. REV. 26 BLACKOUT OPERATION ,m e J 'l

3 i 1

5.0 Instruction

(Cont'd) { j 3' s 5.2 Immediate operation Action (Cont'd) 8 5.2.10 Scare steam driven aux. feed pump and establish flow L to S.G.'s. If aux. feed pumps have started due to the auto start f eature, the motor driven pumps may be secured 30 seconds after they start, if desired.

5.2.11 If all feedwater flow is stopped or lost and steam generator level is less than 42% then:

1. Reinitiate auxiliary feedwater flow as soon as possible; however, do not exceed a flow rate of 150 gpm per steam generator.

2. Limit feedwater flow rate to 150 gpm per

steam generato,r until continuous feedwater flow to the SG has been maintained for five minutes.

5.2.12 If any of the automatic actions listed in 5.2.2 thru 5.2.9 do not occur automatically, then manually initiate that action.

5.2.13 Implement the Emergency Plan as necessary in accordance with EPIP 3100021E, " Duties of the Emergency Coordinator '.

5.3 Subsequent Action 5.3.1 Ensure adequate natural circulation flow by ensuring that hot and cold leg temperatures, pressurizer pressure and level stabilize within minutes. The core AT should be less than N 46 F (AT for full power).

5.3.1.1 If the above conditions are not established:

5.3.1.1.1 Check QSPDS saturation =argin display and egsure that the RCS and Upper Head are at least 20 F but less than 200 0F subcooled. R26 5.3.1.1.2 Ensure auxillary feed flow to the steam generators has been initiated and the steam dumps to atmosphere are in operation.

5.3.1.2 Return at least one RCP in each loop to operation as soon as offsite power is available.

$. 5.3.2 Start equipment in Table 1.if required.

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Page 6 of la EMERGENCY OPERATING PROCEDURE No. 0030140, ,#r" t REVISION 26 BLACKOUT OPERATION L d

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5.0 Instruction

(Cont'd) 3$

H 4, 2

n 5.3 (cont'd) i 5.3.3 If one diesel fails to start, attempt a manual start.

rL 5.3.3.1 If manual start attempt is unsuccessful, an operator should be sent to the diesel local control station to inspect status of local alarm panel.

5.3.3.2 If no alarms are present on the local alarm panel, an inspection of the overspeed trip lever should be made to insure it has not tripped.

5.3.3.3 If the overspeed trip levers are latched, the norma?. isolate switches on the local control panel should be placed in the isolate position and a local start attempt should be made.

I 5.3.3.4 Refer to Operating-Procedure 2200020, 2200050 Emergency Diesel Standby Line up and Periodic Test.

5.3.4 Locally open condenser vacuum breakers MV10-1A and MV10-13. Locally close MSR main steam block valves MV08-4, MV08-6, MV08-8, and MV08-10.

5.3.5 Check MSR warm-up valves MV08-5, MV08-7, MV-9, and MV08-ll to be closed or close manually.

'5.3.6 Send an operator to align and start emergency cooling water to the instrument air compressor, then reset local handswitch and manually start the instrument air compressor.

CAUTION: Do not overload the diesel generators when

, starting additional equipment. (3500 KW max. continuous rating).

5.3.7 When diesel generator power is available energize equipment as may be required for plant safety and to achieve an orderly shutdown within the diesel gener-

, ator load limitations by:

5.3.7.1 Verify one set of cavity and support cooling fans operating. If not, start one set.

5.3.7.2 Locking out automatic starting equipment that is not in service.

.' 5.3.7.3 Manually opening all. breakers on any'non-vital bus or motor control center that is to be re-energized.

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Page 7 of 14 EMERGENCY OPERATING PROCEDURE NO. 0030140, REVISION 26 7,g BLACKOUT OPERATIGF 34' ;

6

5.0 Instructions

(Cone) }ji

' 'i 5.3 (Cont) ,i j a

5.3.7 (Cont) ij -

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5.3.7.4 Resetting lockout relays for each required bus to allow closing of feeder breakers.

5.3.8 Energize 4160 V buses lA2, 1B2, 480 V load centers LA1, 1B1 and 480 MCC's lAl, IB1, lA4, 134, and 1C as follows:

ACTION LOCATION 5.3.8.1 Scrip non-vital 4.16 KV busses lA2 1B2 (All should be opened automatically) 5.3.8.2 Insert sync plug, close 4.16 KV 1A2-20109 132-20309 non-vital breaker and hold control switch closed while closing 4.16 KV vital breaker, lA3-20209 133-20411 5.3.8.3 Strip non-vital load center lAl 131 5.3.8.4 Close 4.16KV feed breaker to non-vital load centers lA2-20110 1B2-20310

5. 3.8 . 5 Strip 480V MCC 1A1 131 1A4 134 1C 5.3.8.6 Close 480V load center feed breaker to MCC LAl &'1B1 1Al-40ll5 131-40411 5.3.S.7 Close 480V load center feed breaker to MCC 1A4 & 134 lAl-40ll3 131-40413

5. 3.3 . 8 Close 480V load center feed breaker to MCC 1C LAl-40119 131-40410 5.3.9 At MCC 1C, close breakers for turning gear, bearing oil pump, air side seal oil pump and hydrogen seal oil pump.

5.3.10 Place turbine plant cooling water pump in operation.

5.3.11 Align turbine cooling water system to the instrument air compressor back to normal alignment.

5.3.11.1 Open all Ckt's 'on PP-104 except Ckt's 21 & 23.

. 5.3.11.2 Close Breaker 40851 on MCC LAl 3.3.11.3 Open all Ckt's on PP-146 except Ckt 1.

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EMERGENCY OPERATING PROCEDURE NO. 0030140, .! .

REVISION 26 f' /.

BLACKOUT OPERATION- L^3 t, S

'i

5.0 Instructions

(Cont) j p 5.3.11.3.1 Open all Ckt's on PP-150 except Ckt's 7,9 and 11. }bh 3 4

%J NOTE: PP-146 is located on the wall of the new cold lab just west of MCC 131. PP-150 is located-in the new cold lab closet.

5.3.11.4 Close Breaker 41634 on MCC 131.

5.3.12 Place turbine drain valve switch in the open pcsition.

5.3.13 Start bearing oil pump before.turbing bearing oil pressure reaches 12 psig. decreasing. Pump starts automatically at 12 psig decreasing turbine bearing oil pressure. NOTE: If bearing oil pump fails to start, the emergency DC oil pump will start at 10 psig decreasing bearing oil pressure. 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.

5.3.14 Remove the following components from service:

5.3.14.1 Steam jet air ejectors 5.3.14.2 Priming ejector 5.3.14.3 Auxiliary priming ejector

-5.3.14.4 Auxiliary steam to R.A.B.

5.3.14.5 Gland seal system 5.3.15 Start CEDM cooling fans A & 3.

5.3.16 Start reactor support cooling fans A & 3.

CAUTION: Consider equipment starting requirements.

Alternate operation of equipment may be required to avoid overloading the diesel generators. (3500 KW-Max. continuous rating).

5.3.17 Manually close breakers for pressurizer' heater buses on 4150 V buses lA3 and 1B3.

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Page 9 of 14

=1 EMERGENCY OPERATING PROCEDURE NO. 0030140, REV 26 #

BLACKOUT OPERATION r y. .

5.0 Instructicas

(cont) {,

5.3 (cont) kP 5.3.13 Check that the bearing oil lift pump starts automatically when turbine speed decreases to approxi=ately 600 rpm.

5.3.19 Start turbine lube oil vapor extractor and generator oil vapor extractor.

5.3.20 Check that the turning gear engages and starts auto-matically when turbine speed decreases to zero rpa, or manually engage it.

5.3.21 Reduce the flow of cooling water to maintain the temperature of the oil leaving the turbine lube oil and the air side and hydrogen side oil coolers be-tween 95 - 100 F.

5.3.22 Isolate cooling water supply to the generator hydrogen coolers.

5.3.23 If additional condensate storage tank water is required and sufficient power is ava'.lable from the

. diesel generators, place the water treatment plant in service.

5.3.24 Place the spent fuel pit cooling pump in operation as necessary.

NOTE: With spent fuel elements from 3-1/3 cores present, the spent fuel pit can safely withstand 5 hours5.787037e-5 days 0.00139 hours 8.267196e-6 weeks 1.9025e-6 months without cooling before reaching the boiling point.

5.3.25 Periodically check fuel oil levels in' the diesel generator day tanks to confirm proper operation of the fuel oil transfer system and to ensure uninter-rupted diesel generator operation.

5.3.26 Sample and analyze the reactor coolant to determine if fuel element clad failure has occurred.

5.3.27 Determine expected duration of power outage. If unable to do so or if outage is to be prolonged, borate RCS !

to cold shutdown concentration.

5.3.28 If.the outage will exceed 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months and the RWT is available, proceed to cold shutdown conditions utilizing thermal

. circulation, atmospher'ic steam dump and feedwater ;

' addition. Place shutdown cooling in service when appropriate temperatures and pressures are reached.

Proceed to step 5.3.32.

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Page 10 of 14 NGENCY OPERATING PROCEDURE NO. 0030140, REV 26 BLACKOUT OPERATION ,), .

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5.0 Instructions

(cont) ! j s o 5.3 (cont) j j 5.3.28 (cont) 4 m

j NOTE: Do not begin plant cooldown until cold shutdown boron concentration is verified.

5.3. 29 If the outage will exceed 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months and the RWT is not available, the Safety Injection tanks should be used for makeup to the RCS, if other sources are not available.

5.3.30 Make the following preparations:

5.3.30.1 Close either or both non-essential tie breakers for MCC 1A5 and MCC IB5 1A5 - 41230 IB5 - 42027 This will provide power to the containment instrument air compressors.

5.3.30.2 If running of containment instrument air compressors is not desirable, insure that a turbine building instrument air compressor is running and containment instrument air pressure is normal.

5.3.30.3 Open the 480 V AC breakers for MOV-2501 and MOV-2504.

MOV-2501 - 42021 MOV-2504 - 42017 5.3.30.4 Open and lock the following valves:

V-07009 SlT test line return to RWT penetration #41 V-3463 SIT test line return to RWT penetration #41 V-03920 SIT test line tie to VCT inlet 5.3.30.5 Borate the RCS to cold shutdown boron concent ation.

CAUTION: Insure that one.BAMT tank ramains in service to use as a source of borated water while in mode 5.

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Page 11 of 14 EMERGENCY OPERATING PROCEDURE NO. 0030140, REV - 26 /* ,1 BLACK 0UT OPERATION ,/. j ian i :

5.0 Instructions

(cont) 2 $

>. i 1 5.3 (cont) j j i

i 5.3.31 Proceed to cold shutdown conditions utilizing thermal [,,g circulation, atmospheric steam dump and feedwater addition.

, 5.3.31.1 When makeup to VCT is necessary, select a l S.I.T. to use as makeup source. Open the appropriate tanks, fill and drain valve.

lAl - A0V-3621 1A2 - A0V-3611 1B1 - A0V-3631 IB2 - A0V-3641 5.3.31.2 Close the appropriate fill and drain valve

. when VCT is restored to normal level.

CAUTION: Use one" SIT tank at a time.

Insure RCS is 1750 psia before i the second SIT tank is used.

5.3.31.3 Place shutdown cooling in service when appropriate temperatures and pressures are-reached.

5.3.32 If pressurizer cooldown cannot be accomplished in a timely manner from the addition of cooler liquid (Aux.

Spray) from the charging pump via the pressurizer spray line, proceed with the alternate positive means of depressurization as follows:

5.3.32.1 Place the switches for the power operated .

relief valves V1402.and V1404 in the override I position.

5.3.32.2 Initiate a high p'ressurizer. pressure trip signal on two RPS channel trip units.

5.3.32.3 Place the switch for either power operated relief valve (V1402 or V1404) in the normal

- range position and vent the pressurizer to the quench tank. Return'the switch to-override to'close valve.

'5.3.32.4 Control the rate of cooldown and depressurization by selective operation of the power operated

. Lrelief valves in this mode untiliccoldown via

' the Auxiliary Spray valves can be' initiated.

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EMERGENCY OPERATING PROCEDURE NO. 0030140, REV 26 BLACKOUT OPERATION ,m

/1 15.0 Instructions: (cont)

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D

. 5.3 (cont) b. j1 E

5.3.33 When normal AC power is available:

> 5.3.33.1 Restore bus sections to their normal supplies.

5.3.33'.'2 . Place the diesel generator system in standby lineup as per OP 2200020.

5.3.33.3 Restore all plant systems to normal.

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r-Page 13 of 14 EMERGENCY OPERATING PROCEDl"RE NO. 0030140, REV 26 .?+ 1 BLACKOUT OPEMTION af f, b

6.0

References:

f:

I 6.1 FSAR, Section 15

}h 6.2 PSAR, Section 8 ,,g 6.3 Operating Procedure #0030130, Shutdown Resulting Prom Reactor / Turbine Trip 6.4 Operating Procedure #0210020, Charging and Letdown 6.5 Operating Procedure #0330020, Turbine Cooling Water operation 6.6 Operating Procedure #0250031, Boron Concentration Control, Off-Normal 6.7 Operating Procedure #1010040, Loss of Instrument Air 6.8 Operating Procedure #1540020, Water Plant Startup and Shutdown 6.9 Operating Procedure #2200020, Emergency Diesels - Standby Lineup 6.10 Operating Procedure #0700022, Aux. Feedwater Systes Operation 7.0 Records / Notification:

7.1 Normal Log Entries.

7.2 Notify Duty Call. Supervisor.

7.3 AP 0010134 " Component Cycles and Transients" l

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% ,_ _ _ 0030140 3 Rev 2h j g op g

- ..A EMERGENCY DIESEL CENERATOR I.0ADING SEQUENCE Loss of Coolant Accident I.oss of-and Loss of off-Site Power ' '

W !-Site Power Nominal Running Timing * .

Running Starting Running Load - Ku Service h Load - Ea Load - Ku HPSI pump 1 400 IIP 330 From 0.2 Sec - Cont -

~

Boric acid makeup pump 1 2 5' llP 22 From 0 Sec - 4 hrs 1st 22 Charging pump 1 100 Igp 80 From 0 Sec - 4 hrs Block 80

!!ator opera ted valves Lot 60 IIP 40 From 0 Sec - 1 min -

Emergency lighting Lot 50 KW 50 From 0 Sec - Cont 50 Class I power panels 4 45KVA 40 From 0 Sec - Cont 40 Fuel Transfer Pump 1 5 llP 5 From 0 Sec - Cont 5 I.PS I ptunp 1 400 llP 330 From 3 Sec - 90 min 2nd 330 containmnet fan coolers 2 150 llP 245 From 3 Sec - Cont Block 167 Component coolant pump 1 450 llP 376 From 6 Sec - Cont 376 Shield bid vent fan 1 60 IIP 54 From 6 Sec - Cont 3rd -

Shield Bld Vent Sys Elec litr 1 30KU 30 From 6 Sec - Cont Block -

D-G Bld Exh. Fan 1 lilP 1 From 6 Sec - Cont I

- Intake cooling pump 1 600 llP 492 From 9 Sec - Cont 4th Block 492 Containment spray ptunp 1 500 IIP 400 From 12 Sec - Cont 5th Block -

Auxiliary feedwater pump 1 350 IIP 305 From 15 Sec - 4 hrs 6th Block 305 Boric acid heating 1 Lot 51.75 KW 51.75 From 18 Sec - 4 hrs 51.75 Auxiliary bld supply fan 1 60 llP 54 From 18 Sec - Coat 54 ECCS Area exhaust system 1 50 llP 44 From 18 Sec - Cont 7th 44 Control Room AC Outdoor Unit 1 50 llP 44 From 18 Sec - Cont Block 44 Control room AC Indoor Unit 1 7.5 !!P 8 From 18 Sec - Coot 8 Control room booster fan 1 , 3 IIP 3 From 18 Sec - Cont 3 Reactor Support CLG Fan 1. 40 ll? 37 From 13 Sec - Cont 37 Iteactor Cavi t y CLG Fan 1 20 llP 19 From 18 Sec - Cont 19 Hattery Charger 1 68 KVA 68 From 30 Sec - Cont 8th 68 20 KVA 20 From 30 Sec - Cent Block 20 Plant Security Inverter 1 UPS Inverter 1 15 KVA 15 From 30 Sec - Cont 15 Fire Pump 1 250 llP ** Prom 35 Sec ** 198 2429.75 kw Totals: 1163.75 kv_

(maxi mtmi, 18 Sec -

30 min)

Counting from the time the D-G breaker closes

- Auto-start feature on fire pump is defeated if SIAS is present.

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t FLORIDA POWER & LIGHT COMPANY ST. LUCIE UNIT 2 EMERGENCY PROCEDURE NUMBER 2-0030140 REVISION 2 BLACKOUT OPERATION

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Page 2 of 14 E

FLORIDA POWER & LIGHT COMPANY j ST. LUCIE UNIT 2 EMERGENCY PROCEDURE NUMBER 2-0030140 -

1 REVISION 2 l

d

1.0 SCOPE

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.

2.0 SYMPTOMS

2.1 Alarms associated with the loss of operating plant components.

2.2 Loss of normal Control Room lighting and DC lighting energized.

2.3 Reactor and Turbine trip.

2.4 Emergency Diesel Generators start.

2.5 Reactor Coolant Pump trip and Main Feedwater Pump trip.

3.0 AUTOMATIC ACTIONS:

NOTE: Any Automatic Actions that should occur and do not, must be

., manually initiated. ,

AUTOHATIC ACTION INITIATING EVENT 3.1 Reactor Trip 3.1 RCS Low Flow <95%

3.2 Turbine Trip 3.2 Reactor trip bus low voltage 3.3 Generator lock-out 3.3 Turbine trip /Bkrs closed 3.4 Generator breakers open 3.4 Turbine Trip 3.5 Incoming feedar breakers 3.5 Start up transformer open to 4160V and 6900V buses breakers fail to close 3.6 Tie breakers between normal 3.6 Undervoltage on 2A2 and 2B2 4160V buses (2A2 and 2B2) and 4160V buses the emergency 4160V buses (2A3 and 2B3) open 3.7 Ties between essential and 3.7 Undervoltage on Emergency r.on-essential sections of 480V MCCs emergency 480V MCCs open O

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Paga 3 of 14 I B0 !

ST. LUCIE UNIT 2 es '

EMERGENCY PROCEDURE NUMBER 2-0030140, REVISION 2 3 '

BLACKOUT OPERATION f

/

3.0 IMMEDIATE AUTOMATIC ACTION: (Cont.)

AUTOMATIC ACTION INITIATING EVENT _ . ,

3.8 Breakers open for the following 3.8 Diesel load shedding sequence 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 pump 2A and 2B /R2 Containment building elevator Electrical equipment room hoist 120/208 Power Panel 121 transformer

.. Lighting panel transformers 110, 112, 114, 117, 125, 126

(.s Incoming feeder from.2A2 and 2B2 4160V buses RCP oil lif t pumps (B pumps only - A pumps running)

Pressurizer relief isol valves (1476 and 1477) /R2 CVCS heat tracing transformer 2A and 2B 480V Lighting panel 2A, 2B and 2C Waste management heat tracing transformers 2A and 2B Air conditioner 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 l

i

Page 4 of 14 ST. LUCIE UNIT 2 b EMERGENCY PROCEDURE NUMBER 2-0030140, REVISION 2 l O}

BLACKOUT OPERATION w}

3.0 IMMEDIATE AUTOMATIC ACTION: (Cont.)

AUTOHATIC ACTION INITIATING EVENT ]

3.9 All loads on emergency buses 3.9 Diesel load shedding sequence l are tripped except the following:

Boric Acid Makeup Pumps Charging Pumps Emergency lighting Class I power panels RCP oil lift pumps ( A pumps only - B pumps off) Diesel fuel oil transfer pump 3.10 2A and 23 Diesel Generators 3.10 Undervoltage on 2A3 and 233 start and energize 4160V 4160V buses emergency buses 2A3, 2B3, and 2AB and loads listed in Step 3.9 3.11 Subsequent loads are started 3.11 Diesel Generator Loading at three second intervals sequence

(~ (See Table 1, Emergency Die,sel

- Generator Loading Sequence).

3.12 Auxiliary Feedwater auto start 3.12 2A or 23 Steam Generator initiates level decreases to 20.6% /R2 i

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i Page 5 of 14 I ST. LUCIE UNIT 2

EMERGENCY PROCEDGRE NUM3ER 2-0030140, REVISION 2 ,

BLACKOUT OPERATION ,y i i

1 4.0 IMMEDIATE OPERATOR ACTION:

ACTION LOCATIONS 4.1 Trip Turbine and reactor 4.1 RTGB-201 and 204 manually 4.2 Check all CEAs are fully 4.2 RTGB-204 and top of RPS inserted and reactor trip Panels breakers are open 4.3 Check turbine valves are 4.3 RTGB-201 closed 4.4 Check generator Exciter Supply 4.4 RTGB-201 Breaker and Generator Breakers 8W49 and 8W52 are open /R2 4.5 Place reheater control system 4.5 RTGB-201 system in MANUAL, close TCVs 4.6 Check that Diesel Generators 4.6 RTGB-201 have started and are feeding only emergency byses 4.7 Open Startup Transformer 4.7 RTGB-201 breakers 4.8 to reference 4.8 RTGB-203 ReduceT*Ehmanualoperation setpoint of the steam dump valves to atmosphere /R2 4.9 Isolate Steam Generator 4.9 RTG3-206 blowdown 4.10 Verify 2C steam-driven AW 4.10 RTGB-202 pump has started and has established flow to the Steam Generators. If AFW pumps have started due to the auto start feature, the motor driven pumps may be secured, if desired mue O

Page 6 of 16 So s**" ,

ST. LUCIE UNIT 2 P EMERGENCY PROCEDURE NUMBER 2-0030140, REVISION 2 L ',

)

SLACK 0UT OPERATION

.1 3 5.0 SUBSEQUENT ACTIONS:

b

/

- 5.1 Implement the Emergency Plan as necessary in accordance with EPIP 3100021E, " Duties of the Emergency Coordinator".

5.2 Verify adequate natural circulation flow by ensuring that hot and cold leg temperatures, Pressurizer pressure and level stabilize within approximately 15 minutes. The core d, T should be

<49'F ( th T for full power). /R2

1. If the above conditions are not established:

A. Check RCS temperature and pressure to ensure that the RCS is subcooled.

B. Ensure AFW flow to the Steam Generators has been initiated and the steam dumps to atmosphere are in operation.

C. Refer to E0P 2-0120043, " Inadequate Core Cooling".

2. Return at least one RCP in each loop to operation as soon as off-site power is available and the requirements for pump restart are satisfied in accordance with E0P 2-0120040,

(' Paragraph 5.8. /R2 5.3 Start equipment in Table 1 if required.

5.4 If one Diesel fails to start, attempt a manual start.

1. If manual start attempt is unsuccessful, an operator should be sent to the diesel local control station to inspect status of local alars panel.

2. If no alarms are present on the local alarm panel, an inspection of the overspeed trip lever should be made to ensure it has not tripped.

3. If the overspeed trip levers are latched, the Normal / Isolate switches on the local control panel should be placed in the ISOLATE position and a local start attempt should be made.

4 Refer to OP 2-2200020 and OP 2-2200050.

5.5 Locally open Condenser vacuum breakers (MV-10-1A and MV-10-13).

Locally close MSR main steam block valves (MV-08-4, MV-08-6, MV-08-8, and MV-08-10).

5.6 Check MSR wart-up valves (MV-08-5, MV-08-7, MV-08-9, and MV-08-11) to be closed or close manually.

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ST. LUCIE UNIT 2 p EMERGENCY PROCEDURE NUMBER 2-0030140, REVISION 2 BLACROUT OPERATION Q4 J

5.0 SUBSEQUENT ACTIONS: (Cont.)

5.7 Send an operator to align and start emergency cooling water to the Instrument Air Compressor, then reset Control Room handswitch and manually start the Instrument Air Compressor (Plant Auxiliaries Control Panel). /R2 CAUTION: Do not overload the Diesel Generators when starting additional equipment (3685KW maximum continuous rating).

5.3 When Diesel Generator power is available, energi:e equipment as may be required for plant safety and to achieve an orderly shutdown within the Diesel Generator load limitations as follows:

1. Verify one set of reactor cavity and reactor support cooling fans operating. If not, start one set. /R2

2. Lock out automatic starting equipment that is not in service.

3. Manually open all breakers 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 closing of feeder breakers.

{ .

5.9 Remove the following components from service:

Steam jet air ejectors Prining ejector Auxiliary priming ejector Auxiliary steam to RAB Gland seal system 5.10 start 2A and 23 CEDM cooling fans.

5.11 Start 2A and 23 reactor support cooling fans.

CAUTION: Consider equipment starting requirements. Alternate operation of equipment may be required to avoid overloading the Diesel Generators (3685KW maximum continuous rating).

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Paga 3 of la

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30 ST. LUCIE UNIT 2 (",

EMERGENCY PROCEDURE NUM3ER 2-0030140, REVISION 2 Q4 -

j BLACKOUT OPERATION j/ l 5.0 SUBSEOUENT ACTIONS: (Cont.) l e

5.12 Manually close breakers for Pressurizer heater buses on 4160V buses' I 2A3 and 2B3. Place the Override Key Switch to the PRESSURE OVERRIDE position and reset the Backup heater breakers. This should be accomplished within two hours following the loss of off-site power.

CAUTION: Consider equipment starting requirements. Alternate operation of equipment may be required to avoid overloading the Diesel Generators (3685KW maximum continuous rating).

NOTE: The above actions will only energize B-1 and B-4 banks of Backup heaters.

5.13 Check that the Bearing Oil Lift Pump starts automatically when Turbine speed decreases to approximately 600 rpm.

5.14 Start oil reservoir vapor extractor and generator oil vapor extractor. /R2 5.15 Check that the turning gear engages and starts automatically when

(, turbine speed decreases to zero rpm, or manually engage it.

(

5.16 Reduce the flow of cooling water to maintain the temperature of the oil leaving the turbine lube oil and the air side and hydrogen side oil coolers between 95 - 100o?.

5 .17 Isolate cooling water supply to the Generator hydrogen coolers.

5.18 If additional Condensate Storage Tank water is required, have Unit 1 personnel place the Water Treatment Plant in service.

5.19 Place the Spent Fuel Pool Cooling Pump in operation as necessary.

NOTE: With spent fuel element assemblies from 3-1/3 cores present, the Spent Fuel Pool can safely withstand at least five hours without cooling before reaching the boiling point.

5.20 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.

5.21 Sample and analyze the reactor coolant to determine if fuel element clad failure has occurred.

5.22 Determine expected duration of power outage. If unable to do so or if outage is to be prolonged, borate RCS to Cold Shutdown concentration.

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Page 9 of 14 I 30 l ST. LUCIE UNIT 2 EMERGENCY PROCEDURE NUMBER 2-0030140, REVISION 2 p

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BLACKOUT OPERATION i l

in-.

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5.0 SUBSE00ENT ACTIONS: (Cont.) ,p P"

==

5.23 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. Refer to EOP 2-0120040, " Natural Circulation /Cooldown". Place Shutdown Cooling in service whec appropriate temperatures and pressures are reached.

NOTE: Do not begin plant cooldown until Cold Shutdown boron concentration is verified.

5.24 If Pressurizer cooldown cannot be accomplished in a timely manner from the addition of cooler liquid (auxiliary spray) from the Charging Pump via the Pressurizer spray line, proceed with the alternate positive means 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 on two RPS channel trip units.

Place the switch for either Power Operated Relief Valve (V-1474

(' 3.

or V-1475) in the OFF position and vent the Pressurizer to the Quench Tank. Return the switch to OVERRIDE to close valve. /R2 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.

5.25 When normal AC power is available:

1. Restore bus sections to their normal s 2pplies.

2. Place the Diesel Generator system in standby lineup as per OP 2-2200020,

3. Restore all plant systems to normal.

6.0 DISCUSSION

6.1 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.

6.2 Steam dump to atmosphere must be used to remove reactor decay ;

[ heat. Initially, Steam Generator safety valves may acuacate to l

augment the steam flow and to help control Steam Generator pressure j immediately after the trip. )

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Page 10 of 14 30 s ST. LUCIE UNIT 2 EMERGENCY PROCEDURE NUM3ER 2-0030140, REVISION 2 3LACKOUT OPERATION

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6.0 DISCUSSION

(Cont.)

6.3 On-site power will be supplied by the Emergency Diesel Generators. I 6.4 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 after normal feedwater flow stops. Auxiliary feedwater flow will automatically initiate after the first Steam Generator level reaches 20.6%

(2/4 logic). /R2 6.5 Core decay heat removal is accomplished by natural circulation in the reactor coolant loops.

6.6 Core damage is not expected as a result of a loes of power condition since the Steam Generators are maintained as a heat sink and RCS pressure and inventory control are available. /R2 6.7 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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ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE 2-0030140, REVISION 2 Bl.ACKollT OPERATION TABl.E 1 DIESEL. CENERATOR LOADING SEQUENCE __

idN11tC IIMD (IGJ)

Ibr Ihminal lira Diesel tant or Sut4m With (Recirmlatico) linin Steau l.ine Atituiutic Statting Generator 11steplate Startirg Timirg lass of W P- Witti lass of WP- Break With laas of T11M Erydpient (4) Onitity IF KVA Sistienm Site hur (1111') Site hwr (IlYP) Offsite ihr (IfYP)

I liigh Pressure Safety Inj. nsap 1 400 2422.0 0 Sec. -

324 324 2 ntor cieratal Valves let - -

0 Sec. 6.7 27.2 33.1 3 D:urlFncy Lidtirg lot - -

0 Sec. 125 125 125 4 ihr Parets lot - -

0 Sec. 19 5 19 5 195 5 Diesel 011 Trainfer ninps 1 3 21.5 0 Sec. 3 3 3 6 ICP Oil I.if t hwps 4 10 66.85 0 Sec. 40 20 20 7 thiluterrugttble Itwr Sipply 1 0 Sec. 55 55 55 tl IIVAC limgurs lot - -

0 Sec. 4 4 4 9 INAC Valves let - -

0 Sec. 1.5 1.5 1.5 10 im Presaire Safety inj. hanp I 400 2183.3 3 Sec. 274 321 274 11 Gmtalistent Fan Gnlers 2 125/83 828.4 3 Sec. 134 96 96 12 Elec. Erpdp. thua Supply 1 100 584.12 3 Sec. 95 95 95 13 Gnupcment untlig Water 1 450 2491.2 6 Sec. 351 351 351 14 Sateld Buildlig thust 1 60 %0.6 6 Sec. -

40.2 . 40.2 15 Siteld Hutidlig Ibaters Ier - -

6 Sec. -

31.5 31.5 16 Intake unitig Water haip 1 600 3/W.0 9 Sec. 453 453 453 k

.m i

Page 12 of 14 ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE 2-0030140, REVISION 2 lli.ACKOllT OPERATION

-. TABI.E I DIESEL. GENERATOR 1.OADING SEQtlENCE IdtMItU IIMD (IGJ) 1%!r thainal IICA Diesel lent or Slaitdown With (Rect raslation) Main Ste.ma 1.ine Antonitic "startlig Ccamitor Ruinglate Starting Tiinirg less of GV- Witti Isus of GP- Break Wit ti lais <f FnM lipipinuit (4) Qiantity IF KVA Supence Site Power (Inne) Site P<wr (InnP) Offsite Ptwr (InnP) 17 Cuntainient Spray linnp 1 500 2892.6 12 Sec. -

405 405 18 ilydrazlic lisy 1 3 21.5 12 Sec. -

1 1 19 Reactor Supgurts Giollry 1 40 234.76 18 Sec. 22 - -

20 Peactor Cavity Supply Fan 1 20 124.15 18 Sec. 15 - -

21 Intake Buildlig Gallig Fan 1 7.5 44.0 21 Sec. 7.5 7.13 7.5 22 Battery Rua knf Ventilator 2-RV-1 1 0.75 8.5 21 Sec. .75 75 .75 23 Elec.191 ulp. Enn Exluist , 2-RV-3 1 5 34.22 21 Sec. 5 5 5 24 IIXE Area Exluist Fan 1 60 358 24 Sec. 45 45 45 25 nmtrol Rxua Dier. Filter Fan i 10 62.0 24 Sec. -

10 10 26 Gmtrol thna Air Gnlitluitig 2 55 -

24 Sec. Gl N1 Q1 27 lbric Acid Ibat Tra<n let leit -

.27 Sec. 30 31 30 28 11attery Cliarger 1 U13J -

27 Sec. 60 , G) 60 29 Antilary Feulwater lisap 1 39) 1951.4 3) Sec. 255 255 255 k

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"D Page 13 of 14 j

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ST. 1.UCIE UNIT 2 .' i EMERGENCY OPERATING Pit 0CEDURE 2-0030140, REVISION 2 / /

Bl.ACK0t!T OPERATION f'

TABLE 1

,-_ y ..

DIESEL, CENERATOR II)ADING SEQUENCE idtNIN: IIMD (W)

Ibr thatnal III:A Diesel lani or SinstAnas With (Necitadation) K11n Stema 1.fre Automatic Startirg Gsurator I!= plate Startirg 11mdig Ims of (t?- With las of (DV- Brealt With lemss of I11H 19paigmast Qiastity IF KVA. Sarpamm Site Itwr (IDF) Site hwr (IAP) Offsite hwr (In?)

!H HAB Snipply Fan i 150 9X).1 33 Sec. 111 111 111 31 Elec.19 pip. Rorum Exf6 asst, 2-IIVE-Il 1 50 244.7 3tl Sec. 38 3t! Jtt

.32 Omarging hogs 2 125 1656.8 5 Min. 60 60 60 ,

33' L;ric Acid Hakamp hssp (2) - 2 25 124.1 5 Min. 24 24 24 34 Ir9tnansit Air usupressor _1 60 340.6 Kumul lan! 60 60 60 35 14e1 Pool Gm11rg hssp 1 40 234.6 Kuual lo m! 26 -

26 36 Ilyderen ReanalJw.r 1 75m -

Kunnal loal -

75 75

~17 Presairizer Ibatem 1 20lEW -

Kanal lam! 20t) - -

(after 2 luurs IDF)

Notes:

,. (1) Actisitol uit RAS (2) Ikth ik>ric Acid Kanssp hsqm are lambi outa Diesel Cererator A e

Pags 14 of 14 ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE NO. 2-0030140. REVISION 1 ( 'g BLACROUT OPERATION ! g

)

7.0 REFERENCES

[

7.1 St. Lucie Unit 2 FSAR, Sections 8 and 15 .

t 7.2 Off-Normal OP 2-0030130, " Shutdown Resulting From Reactor / Turbine Trip' 7.3 OP 2-0210020 " Charging and Letdown" 7.4 OP 2-0330020, " Turbine Cooling Water Operatiois" 7.5 Off-Normal 0F 2-0250031, " Boron Concentration Control, Off-Normal" 7.6 Off-Normal OP 2-1010040, " Loss of Instruisent Air" 7.7 OP 2-1540020, " Water Plant Startup and Shutdown" 7.8 OP 2-2200020, " Emergency Diesels - Standby Lineup" 7.9 OP 2-0700022, " Auxiliary Feedwater System Operation" 8.0 RECORDS / NOTIFICATIONS:

8.1 Normal log entries

. 8.2 AP 0010134, " Component Cycles and Transients"

9.0 APPROVAL

Reviewed by Facility Review Group October 26 1982 Approved by J. R. Barrow (for) Plant Manager October 26 1982 Revision 2 Reviewed by FRG c

M 1L n

8*If $ , 1963 Approved by q kaNt4 s_ e _ .

. N Plant Manager fh_?_ i Li49 1 I V

"LAST PAGE" EP 2-0030140 Rev. 2 Total No. of Pages 14 ee.

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f FLORIDA POWER & LIGHT COMPANY ST. LUCIE UNIT 2 EMERGENCY PROCEDURE NUMBER 2-0030143 REVISION 2 TOTAL LOSS OF AC POWER (TLOP)

TOTAL NO. OF PAGES 9

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This document is not contre!!cd. Before use, b ; verify information with a centre!!od document.

Pags 2 of 9 ST. LUCIE UNIT 2 EMERGENCY PROCEDURE NUMBER 2-0030143, REVISION 2 TOTAL LOSS OF AC POWER

1.0 SCOPE

)

This procedure is to be used in the event of a total loss of both of f site j i AC power and loss of both Diesel Generators.

2.0 SYMPTOMS

2.1 Loss of power to 2A1, 2B1 6.9 KV Bus.

2.2 Loss of power to 2A2, 2A3, 232, 2B3 and 2AB 4.16 K7 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 @ 20.6% /R2 3.4 PORV's Operate 3.4 Ri Pressurizer Press

@ 2370 PSIA /R2

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i Pega 3 of 9 ST. LUCIE UNIT 2 A EMERGENCY PROCEDURE NUMBER 2-0030143, REVISION 2 7 TOTAL LOSS OF AC POWER 4.0 IMMEDIATE OPERATOR ACTIONS: #

4.1 Ensure all CEA's on bottom, 4.1 RTGB-204 and top of RPS d --

and reactor trip breakers open. panels 4.2 Ensure 2C Auxiliary Feedwater Pump 4.2 RTGB-202 is restoring Steam Generator level.

4.3 Close HCV-08-1A and HCV-08-13 4.3 RTGB-206 (Main Steam Isolation Valves).

4.4 Isolate letdown flow by closing 4.4 RTGB-205 V-2515, V-2516, and V-2522 (Letdown isol).

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Pege 4 of 9 ST. LUCIE UNIT 2 EMERGENCY FROCEDURE NUMBER 2-0030143, REVISION 2 TOTAL LOSS OF AC POWER l l t

5.0 SUBSEOUEVE ACTIONS:

CHECK 5.1 Ensure Generator OCB's and field breaker open.

5.2 open 2-30102 (S.U. Transformer to 2A1 6.9 KV bus).

Open 2-30202 (S.U. Transformer to 231 6.9 KV bus).

Open 2-20102 (S.U. Transformer to 2A2 4.16 KV bus).

Open 2-20302 (S.U. Transfor=er to 232 4.16 KV bus).

5.3 Ensure D/G breakers open:

2A D'/G: 2-20211 23 D/G: 2-20401 5.4 Ensure 2AB 4.16KV bus feeders are open:

2-20208, 2-20505 (2A3 4.16KV to 2A3 4.16 KV bus) 2-20409, 2-20504 (2B3 4.16KV to 2A3 4.16 KV bus) 5.5 Open 2-40103 (2A2 4.16KV feed to 2A1 L.C. - H1 side).

Open 2-20110 (2A2 4.16KV feed to 2A1 L.C. - Lo side).

Open 2-40219 (2A3 4.16KV feed to 2A2 L.C. - Lo side).

s Open 2-20210 (2A3 4.16KV feed to 2A2 L.C. - Hi side). /R2 5.6 Open 2-40419 (232 4.16KV feed to 2B1 L.C. - Lo side).

Open 2-20310 (2B2 4.16KV feed to 231 L.C. - Hi side).

Open 2-40503 (2B3 4.16KV feed to 2B2 L.C. - Lo side).

Open 2-20402 (2B3 4.16KV feed to 2B2 L.C. - Ei side). /R2 5.7 Ensure 2A3 480V Load Center Feeders are open:

2-40220, 2-40702 (2A2 480V L.C. to 2A3) 2-40706, 2-40504 (232 480V L.C. to 2AB) 5.8 Ensure the main steam isolation bypass valves both indicate closed or dispatch an operator to locally take control and close the valves.

5.9 Open 2A sad 2B Atmospheric Dump Valves to reduce Steam Generator pressure below safety valve lift pressure. AC power to controllers will be lost, so DC operation of the valves will become necessary as below:

1. Take desired ADV auto / man switch to MANUAL.

- 2. Modulate the dump valve open or closed with direct DC power with the open/close control switch.

_s

Psga 5 of 9 ST. LUCIE UNIT 2 .,9 *-

EMERGENCY PROCEDURE NUMBER 2-0030143, REVISION 2 f a TOTAL LOSS OF AC POWER

/

5.0 SUBSEQUENT ACTIONS: (Cont.)

CHECK 5.10 Close FCV-23-3, 5, 4 and 6 (2A and 2B S/G 31owdown 1 Isol).

5.11 Close FCV-23-7 and FCV-23-9 (2A and 2B S/G 3 lowdown Sample Isol).

5.12 Close V-5200, 5201, $203, 5204 and 5205 (Primary Coolant and Pressurizer Sample Isol). /R2 5.13 Implement the Emergency Plan as necessary in accordance with EP 3100021E, " Duties of the Ehergency Coordinator."

5.14 Minimize atmospheric steam dump use thereby ensuring minimum RCS heat loss; however,

1. Maintain S/G pressure less than S/G safety setpoint.

2. With decreasing RCS pressure, maintain hot leg temperature (Th) at least 20 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 (<460 F).

2. Cold leg (Tc) constant or decreasing.

3. Hot leg (Th) stable (i.e., not steadily increasing).

5.16 If RCS pressure decreases to 1836 psia, verify receipt of block permissive annunciator R-8 and block SIAS. /R2 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 rate of 150 GPM per af fected Steam Generator.

1"

2. Limit feed flow rate to 150 CPM per affected Steam Generator until continuous feed flow to the affected Steam Generator has been maintained for five minutes.

Paga 6 of 9 ST. LUCIE UNIT 2 EMERGENCY PROCEDURE NUM3ER 2-0030143 REVISION 2 I.C'*h'. i l

TOTAL LOSS OF AC POWER f nn-e j

y n

)

5.0 SUBSEOUENT ACTIONS: (Cont.)

CHECK

/ ,

f 5.19 Use all available resources to restore one Emergency Diesel Generator to operable status.

5.20 The following restoration sequence assumes "A" train power supply 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 RERTZ.

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 2-20210 2A3 4.16KV 2A2 and 2A5 480V L.C.

B. Close 2-40219 Incoming Feeder to 2A2 480V L.C.

C. Close 2-40361 Incoming Feeder to 2A5 480V L.C.

4 Energize 2AB 480V Load Center by closing 2-40220 and 2-40702 (2A2 480V L.C. feed to 2AB L.C.).

5. Energize 2AS, 2A6, 2A7 and 2A8 480V MCC's as follows:

A. Close 2-40203 (2A2 480V L.C. feed to 2A5 MCC).

B. Close 2-40351 (2A5 480V L.C. feed to 2A6 MCC).

C. Close 2-40202 (2A2 480V L.C. feed to 2A7 MCC).

D. Close 2-40352 (2A5 480V L.C. feed to 2A8 MCC).

O

Page 7 of 9 ST. LUCIE UNIT 2 EMERGENCY PROCEDURE NUMBER 2-0030143, REVISION 2 g rp ,\

TOTAL LOSS OF AC POWER }

1

("}

3 5.0 SUBSEQUENT ACTIONS: (Cont.) j 5.20 (cont.) j CHECK 3

6. Energize non-essential sections of 2AS, 2A6 and 2A8 MCC's as follows:

A. Close 2-41234 (MCC 2A5 non-essential breaker). ,

B. Close 2-41332 (MCC 2A6 non-essential breaker).

C. Close 2-41514 (MCC 2AS non-essential breaker). / R2

7. Ensure 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, 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 continue 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. Ensure closed 2-20204 (Pressurizer heater transformer 2A 4.16V f eed).

I

11. When Pressurizer level indicates >302, energize l Pressurizer heaters 3-1, B-2, B-3 and F-1.

12. Ensure ICW seal water from Unit 1 Domestic Water System is available, l ,

1

ST. LUCIE UNIT 2 /

EMERGENCY ?ROCEDURE NUMBER 2-0030143, REVISION 2 O l !

TOTAL LOSS OF AC POWER k

,7 o 5.0 SUBSEOUENT ACTIONS: (Cont.)

5.20 (Cont.) l -

CHECK

13. Reestablish "A" train Intake Cooling Water System as follows:

A. Establish seal water.

B. Throttle 2A ICW punp discharge valve.

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 hCV-14-1, 2, 6 and 7 (to prevent thermal shocking RCP seals).

B. Throttle 2A CCW pump discharge valve.

C. Ensure 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 operating level.

16. Commence boration to Cold Shutdown boron concentration.

17. Start one set of cavity and support cooling fans.

18. Proceed to E0P Oz-0120040, " Natural Circulation /Cooldown", Step 5.10, and perform in conjunction with the balance of this procedure.

19. Restore balance of secondary plant in accordance with EOP 2-0030140, " Blackout Operation".

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Paga 9 of 9 ST. LUCIE UNIT 2 EMERGENCY PROCEDURE NUMBER 2-0030143, REVISION 2 f

J TOTAL LOSS OF AC POWER ;

u

6.0 DISCUSSION

[t The " Total Loss of AC Power" event consists of a loss of of f-site power in conjunction with f ailure of the Emergency Diesel Generators to provide s .

emergency power. This results in a loss cf all AC electrical power except that provided by inverters powered from the vital DC buses. The termination of AC power causes a loss of forced reactor coolant flow, main feedwater flow, steam flow to the Turbine and Pressurizer pressure control. The reactor trips on either low reactor coolant flow, high Reactor Coolant System 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. Reactor Coolant System heat removal is accomplished using Atmospheric Pump Valves and the steam-driven Auxiliary Feedwater Pump. ,

7.0 REFERENCES

7.1 CE Emergency Procedure Guidelines, CEN-152 7.2 St. Lucie Unit 1 Off-Normal Operating Procedures 8.0 RECORDS REQUIRED:

8.1 Normal log entries

9.0 APPROVAL

Reviewed by the Facility Review Group October 26 1982 Approved by J. H. Barrow (CMW) Plant Manager April 13 1983 Revision 2 Reviewed by FRG M 43., 1993 Approved by Ske% I'41 ant Manager ' 4h .i a 1 19 f )

"L A S T P A G E" EP 2-0030143 REV. 2

.' TOTAL NO. OF PAGES 9

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Page 1 of 12 I l' -

FLORIDA POWER & LIGHT COMPANY

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ST. LUCIE UNIT 2 OFF-NORMAL OPERATING PROCEDURE NO. 2-0110030 w}- *j REVISION 1 /

k

1.0 TITLE

CEA 0FF-NOP. MAL OPERATION AND REALIGhMENT

2.0 APPROVAL

Reviewed by Facility Review Croup March 10 1983 Approved by C. M. Wethy Plant Manager March 10 1983 Revision 1 Reviewed by FRG M 2. "& 19 8 3 Approved by b b(tam " [ Elant Manager

M / c1 1 19 5 3 f/'

3.0 PURPOSE AND DISCUSSION:

3.1 Purpose

This procedure provides instructions for operator action during abnormal operation and realignment of Control Element Assemblies (CEA).

3.2 Discussion

1. The action statements applicable to a stuck or untrippable CEA, to two or more inoperable CEAs and to a large misalignment (115 inches) of two or more CEAs, require a prompt shutdown of the reactor since either of these conditions may be indicative of a possible loss of mechanical functional capability of the CEAs and in the event of a stuck or untrippable CEA, the loss of Shutdown Margin.

2. For small misalignments (<15 inches) of the CEAs, there is 1) a small effect on the time dependent long term power distributions relative to those used in generating LCOs and LSSS setpoints,

2) small effect on the available Shutdown Margin, and 3) a small effect on the ejected CEA worth used in the safety analysis.

Therefore, the action statement associated with small misalignments of CEAs permits a 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months time interval during which attempts may be made to restore the CEA to within its alignment requirements. The one hour time limit is sufficient to (1) identify causes of a misaligned CEA, (2) take appropriate corrective action to realign the CEAs and (3) minimize the effects of xenon redistribution.

pg3 {",g$%5 .1.a. 2 . . s 4 This document is ne c ^,.,ud. ucr.,j,u".

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Psgs 2 of 12 ST. LUCIE UNIT 2 -

0FF-NORMAL OPERATING PROCEDURE NO. 2-0110030, REVISION 1 CEA 0FF-NORMAL OPERATION AND REALIGNMENT p)

I 3.0 PURPOSE AND DISCUSSION: (Cont.)

J )}

3.1 (Cont.)

3. Overpower margin is provided to protect the core in the event of a large misalignment (2,15 inches) of a CEA. However, this misalignment would cause distortion of the core power distribution. This distribution may, in turn, have a significant ef fect on 1) the available Shutdown Margin, 2) the time dependent long term power distributions relative to those used in generating LCOs and LSSS setpoints, and 3) the ejected CEA worth used in the safety analysis. Therefore, the action statement associated with the large misalignment of a CEA requires a prompt realignment of the misaligned CEA.

4. The action statements applicable to misaligned or inoperable CEAs include requirements to align the operable CIAs in a given group with the inoperable CEA. Conformance with these alignment requirements bring the core, within a short period of time, to a configuration consistent with that assumed in generating LCO and LSSS setpoints. However, extended operation with CEAs significantly inserted in the core may lead to perturbations in

1) local burnup, 2) peaking factors, and 3) available Shutdown Margin which are more adverse than the conditions assumed to exist in the safety analyses and LCO and LSSS setpoint determination. Therefore, time limits have been imposed on operation with inoperable CEAs to preclude such adverse conditions from developing.

4.0 SYMPTOMS :

4.1 Upon observation from ADS, digital position indicators, or data processor, one or more CEAs are misaligned, dropped, or slipped.

4.2 CEA position deviation alarm.

4.3 CEA motion inhibit alarm.

4.4 Dropped CEA alarm.

4.5 AWP alarm.

4.6 PDIL and PPDIL alarms.

4.7 Group out of sequence alarm.

4.3 Short ters, steady state insertion alarm.

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Page 3 of 12 ST. LUCIE UNIT 2 ,A 0FF-NORMAL OPERATING PROCEDURE NO. 2-0110030, REVISION 1 ',

CEA 0FF-NORMAL OPERATION AND REALIGNMENT l[ '

6-- )

.i -

5.0 INSTRUCTIONS

'[

5.1 CEA inoperable or nisalignment of greater than 7.0 inches but less d.

than 15.0 inches. 3 8

5.1.1 Immediate Automatic Action:

1. CEA motion inhibit.

5.1.2 Immediate Operator Action:

1. Place CEDs control panel in OFF.

2. Determine if any mismatch exists between reactor power and turbine power. If a mismatch exists, adjust turbine power to equal reactor power.

5.1.3 Subsequent Operator Action:

1. Determine from symptoms and CEA position indications the cause of the inoperability or if the CEA is operable but misaligned, in accordance with Appendix "B".

2. Ensure automatic functions have initiated.

3. Determine Shutdown Margin within one hour af ter detection of an inoperable CEA to be greater than the Shutdown Margin specified in Technical Specification 3.1.1.1 and once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter.

4 If excessive friction or mechanical interference prevents movement of the CEA or the CEA is untrippable, be in Hot Standby in six hours. See OF #2-0030125, " Turbine Shutdown Full Load to Zero Load". ~

5. If one or more CEAs are inoperable due to other reasons than stated in Step 5.1.3.4, declare inoperable within one hour and realign remainder of operable CEAs in group within 7.0 inches of inoperable CEAs, without violating CEA sequence and insertion limits, within one hour (or be in Hot Standby within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ). Operation in Modes 1 and 2 may continue provided the thermal power level is restricted pursuant to Technical Specification 3.1.3.6 during subsequent operation and the Shutdown Margin requirement of Technical Specification 3.1.1.1 is determined at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . /R1 O

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- -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - a

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Page i of 12 l ST. LUCIE UNIT 2 l OFF-NORMAL OPERATING PROCED' J RE NO. 2-0110030 REVISION 1 < .

CEA 0FF-NORMAL OPERATION AND REALIGNMENT .

Or s I n- J ! 7

/ #J

5.0 INSTRUCTIONS

( Cont . )

5.1 (Cont.)

5.1.3 (Cont.)

6. If CEAs are functioning properly, realign CEA(s) within one hour, in accordance with Appendix "A".

CAUTION: If CEA(s) become misaligned by 15 inches or more, but does not drop while performing the above instruction, proceed to Section 5.2. If CEA(s) drop while performing the above instruction, proceed to Section 5.3.

5.2 One CEA missaligned by 15 inches or more but not a dropped CEA.

5.2.1 Immediate Automatic Action:

1. CEA motion inhibit.

5.2.2 Immediate Operator Action:

1. Place CEDS control panel in OFF.

2. Determine if any mismatch exists between reactor power and turbine power. If a mismatch exists, adjust turbine power to equal reactor power.

5.2.3 Subsequent Operator Actions:

1. Determine from symptoms and CEA position indications the cause of the inoperability or if the CEA is operable but misaligned, in accordance with Appendix "B".

2. Ensure automatic functions have initiated.

3. Refer to Plant Curve Book and obtain F{ value. /R1 4 Within15 minutes (25minutesifF{'<1.5),restorethe CEA (per Appendix A) to within 7.0 inches of all other CEAs in its group or reduce power to <70* of RATED THERMAL PO'JZR within one hour of misalignment. /R1 1

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Pags 5 of 12 ST. LUCIE UNIT 2 ,

OFF-NORMAL OPERATING PROCEDURE NO. 2-0110030, REVISION 1 CEA 0FF-NORMAL OPERATION AND REALIGNMENT q

y3 0

5.0 INSTRUCTIONS

(Cont.)

5.2 (Cont. ) j L'#

5.2.3 (Cont.)

5. Within one hour:

a) Restore to operable status within its specified alignment requirements (within 7.0 inches of other CEA's in its group) per Appendix A.

OR b) Declare CEA inoperable and assure Shutdown Margin requirement of T.S. 3.1.1.1 is satisfied. Operation in Modes 1 and 2 may continue pursuant to the requirements of T.S. 3.1.3.6 provided within one hour:

CAUTION: Prior to performing steps 7.6.1 and 2, reduce power to <70% of the THERMAL POWER level prior to misalignment I? THE PRE-MISALIGNMENT ASI WAS MORE NEGATIVE THAN -0.15.

1. Align the remainder of the CEA's in the group to within 7.0 inches of the inoperable CEA while maintaining the allowable CEA sequence and insertion limits shown in T.S. Figure 3.1-2.

2. The Shutdown Margin requirement of Specification 3.1.1.1 is determined at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

OR c) 3e in Hot Standby within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months . /R1

6. Determine Shutdown Margin within one hour af ter detection of an icoperable CEA to be greater than the Shutdown Margin specified in Technical Specification 3.1.1.1.

7. If excessive friction or mechanical interference prevents movement of the CEA, or the CEA is untrippable, be in Hot Standby in six hours. See OP J2-0030125, " Turbine Shutdown Full Load to Zero Load".

8. With more than one CEA inoperable or misaligned from any other CEA in its group by 15 inches (indicated position) or more, be in Hot Standby within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

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Psga 6 of 12 ST. LUCIE UNIT 2 / s OFF-NORMAL OPERATING PROCEDURE No. 2-0110030, REVISION 1 ? a l

CEA 0F?-NORMAL OPERATION AND REALIGNMENT in wa8 (

I A y

5.0 INSTRUCTIONS

(Cont.) #

5.3 Dropped CEA L_

5.3.1 Immediate Automatic Action:

1. CEA motion inhibit.

5.3.2 Immediate Operator Action:

1. Immediately reduce turbine load to match the reactor power and to return the plant conditions to within LCO's.

5.3.3 Subsequent Operator Action:

1. Determine from symptoms and CEA position indications the cause of the inoperability or if the CEA is operable but misaligned, in accordance with Appendix "B". During the determination of the cause of the dropped CIA the reactor power shall not be increased above the value present at the time the dropped CEA occurred.

2. Ensure automatic functions have initiated.

3. RefertoPlantCurveBookandobtainF{value. /R1 4 <1.5), restore the Within15 minutes CEA (per Appendix A) to(25minutesifF{inchesofallother within 7.0 CEA's in its group or reduce power to <70% of RATED THERMAL POWER within on hour of misalignment. /R1

5. Within one hour:

a) Restore to operable status within its specified alignment requirements (within 7.0 inches of other CEA's in its group) per Appendix A.

OR b) Declare CEA inoperable and assure Shutdown Margin requirements of T.S. 3.1.1.1 are satisfied.

Operation in Modes 1 and 2 may continue pursuant to the requirements of T.S. 3.1.3.6.

CAUTION: Prior to performing steps 5.6.1 and 2 reduce power to <70% of the THERMAL POWER level prior to misalignment IF THE PRE-MISALIGNMENT ASI 'JAS MORE NEGATIVE THAN -0.15.

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Pega 7 of 12 ST. LUCIE UNIT 2 0FF-NORMAL OPERATING PROCEDURE No. 2-0110030, REVISION 1 -

CEA 0FF-NORMAL OPERATION AVD REALIGNMENT s.

5.0 INSTRUCTIONS

(Cont.) [

5.3 (Cont.) f a

5.3.3 (Cont.)

5. (Cont.)

b) (Cont.)

1. Within one hour align the remainder of the CEA's in the group to within 7.0 inches of the inoperable CEA while maintaining the allowable CIA sequence and insertion limits shown in T.S. Figure 3.1-2.

2. The Shutdown Margin requirement of Specification 3.1.1.1 is determined at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

OR c) Be in Hot Standby within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months . /R1

6. Determine Shutdown Margin within one hour after detection .

of an inoperable CEA to be greater than Shutdown Margin specified in Technical Specification 3.1.1.1.

7. If excessive friction or mechanical interference prevents movement of the CEA, or the CEA is untrippable, be in Hot Standby in six hours. See OP #2-0030125. " Turbine Shutdown Full Load to Zero Load".

8. With more than one CEAs inoperable or misaligned from any other CEA in its group by 15 inches (indicated position) or more, be in Hot Standby within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

9. Upon ascertaining and correcting the cause for the dropped CEA recovery of the CEA may be made.

CAUTION: The CEA should be recovered by a slow, smooth withdrawal using small increments of movement. Preferably, the movement increments should be three steps or less. The period of time for recovering the CEA should be approximately 10 minutes. Appropriate changes in RCS boron concentration should be made during the withdrawal of the CEA.

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l Page 8 of 12 l ST. LUCIE UNIT 2 A 0FF-NORMAL OPERATING PRCCEDURE NO. 2-0110030, REVISION 1 f

, i CEA 0FF-NORMAL OPERATION ASTD REALIGNMENT ;' j om-e

5.0 INSTRUCTIONS

(Cont.)

r 5.3 (Cont.)

5.3.3 (Cont.)

9. ( Cont.)

NOTE: Following the return of the CEA to its group, operation should be maintained at the existing power level for at least one hour in order to allow assessment of resultant power distributions and/or azimuthal tilts.# Upon ascertaining that a normal power distribution is present and that the plant conditions are normal, power may then be raised to the desired operating power.

Notify Reactor Engineering Supervisor.

NOTE: It may be necessary to operate at this reduced power level for as long as 24 to 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months in order to reduce the azimuthal oscillation and the resultingvaluesofF[,T,F{y,andASI resultingfromadropped8EA.' .

6.0 REFERENCES

6.1 St. Lucie Unit 2 Technical Specifications 6.2 CEDMCS Tech Manual 7.0 RECORDS REOUIRED:

7.1 Normal log entries 9

9

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Page 9 of 12 ST. LUCIE UNIT 2 0FF-NORMAL OPERATING PROCEDURE No. 2-0110030, REVISION 1 CEA 0FF-NORMAL OPERATION AND REALIGNMENT U!O APPENDIX A - CEA REALIGNMENT

e 1.0 Limits and Precautions:

1.1 Regulating CEAs should be withdrawn in sequence and overlap between f' "

groups shall not exceed 40 percent.

1.2 Do not exceed a sustained SUR of 1.4 DPM (alarm 1.3 DPM).

1.3 Criticality shall be anticipated any time CIAs are being withdrawn.

1.4 If deviation between CEAs in any group approaches 3 inches, stop group withdrawal and realign CEAs.

1.5 Individual CEA positions within the group shall be determined at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months except when the CEA position deviation circuit is out of service, then verify CEA positions at least once every four hours.

1.6 CEAs shall be limited in physical insertion as shown by Technical Specification Figure 3.1-2 (insertion limit curves).

2.0 Ins t ructions:

2.1 Alignment of a CEA which is below its group, prior to criticality:

1. Utilising MANUAL SEQUENTIAL control, insert the misaligned group a minimum of 4 inches.

2. Utilizing MM1AUAL INDIVIDUAL control, withdraw the low CEA to the group position.

3. Monitor the position of all CEAs in the group for proper alignment.

2.2 Alignment of a CEA which is above its group, prior to criticality:

1. Utilize MANUAL INDIVIDUAL control, and insert the high CEA to the group position.

2. Monitor the position of all CEAs in the group for proper alignment.

1 end

Pags 10 of l' ST. LUCIE UNIT 2 - l OFF-NORMAL OPERATING PROCEDURE NO. 2-0110030 REVISION 1 t' l CEA 0F?-NOFF.AL OPERATION A'JD REALIGNMENT I :

)

APPENDIX A - CEA REALIGNMENT (Cont.)

r 2.0 (Cont.) .

2.3 Alignment of an above or below CEA with the reactor critical:

1. Utilize MANUAL INDIVIDUAL control to return the misaligned CEA to the group position.

2. If necessary, alternate between MMTUAL INDIVIDUAL control of the misaligned CEA and MANUAL SEQUENTIAL control of its associated group to maintain the desired reactor power level.

3. Monitor the position of all CEAs in the group for proper alignment.

4. Utilize MANUAL GROUP control as required to readjust the group positions for proper automatic sequencing.

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Paga 11 of C ..

ST. LUCIE UNIT 2 7 i

0FF-NORMAL OPERATING PROCEDURE No. 2-0110030 REVISION 1 CEA 0FF-NORMAL OPERATION AND REALIGNMENT U :)j s

5/*

APPENDIX 3 - DROPPED CEA INVESTICATION jf

, J 1.0 Determine that the dropped CEA is functional, select Manual Individual (MI) on the Mode Select switch, select the affected CEA on the Individual CEA Selection switches, and select the group of the affected CEA on the Group Select switch. Momentarily press the 3ypass Enable push button and press and hold the CMI Bypass push button. Withdraw the affected CIA until the Core Minic DRC light and the Lower Electric Limit light both deenergize. Insert and withdraw the affected CEA and check for scooth operation and normal indications. Reactor power shall not be increased above the value present at the time the dropped CEA occurred. If the affected CEA is determined to be functional realign the CEA per the dropped CEA procedure.

2.0 Guidelines for Investigating Dropped CEAs:

Drooped CEAs have occurred from:

A. Tripped CEA Disconnect B. Loss of CEA Subgroup logic function Svmotoms A. 1. CEA Disconnect in OFF, red light off. green light on.

2. CEA Disable lights red for affected CEA.

3. Timer Failure lights red for affected CEA.

Trouble Shooting A. Call I & C specialist in.

3. Connect visicorder to coil monitor of affected CEA.

C. Close/ check closed CEA disconnect of affected CEA and record trace of UG.

D. Check trace for proper SCR firing and proper coil current.

E. If D is not satisfactory, troubleshoot UG circuits.

F. If D is satisfactory, attempt to withdraw the CEA while recording Coil Monitor trace. Check traces for SCR firing, coil current, and timing. Troubleshoot as required.

Place Subgroup of af fected CEA on maintenance bus prior to troubleshooting that affects any of the other Subgroup CEAs.

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FLORIDA POWER & LIGHT COMPANY ! O, k ST. LUCIE UNIT 2 Wi 0FF-NORMAL OPERATING PROCEDURE No. 2-0250030 / f REVISION 1 / /

i

1.0 TITLE

_]

EMERGENCY BORATION

2.0 APPROVAL

Reviewed by Facility Review Croup Februarv 9 1982 Approved by C. M. Wechv Plant Manager Februarv 15 1982 Revision 1 Reviewed by FRG J 7.- 19 8 3 Approved by D //t. 6/.

[A h/t/ / W '/.M9.id V

3.0 PURPOSE AND DISCUSSION:

This procedure provides instructions for the injection of concentrated boric acid solution into the Reactor Coolant System (RCS) via the Charging Pumps.

In the event that normal charging flow is unavailabe, flow can be directed to the Auxiliary HPSI header from the discharge of the Charging Pumps.

The Boron Concentration Control System is lined up to automatically emergency borate the RCS on a Safety Injection Actuation Signal (SIAS).

When shutdown margin has been confirmed or the SIAS signal reset. it is desirable to restore the Boron Concentration Control System to the automatic make-up mode, or the Refueling Water Tank (RWT) to the suction of the Charging Pumps to prevent overborating. /R1

4.0 SYMPTOMS

Any one of the following conditions requires emergency boration:

4.1 Unanticipated or uncontrolled RCS cooldown following a reactor trip as indicated by:

1. Reactor Low Tave-Tref alarm

2. Decreasing reactor coolant wide range temperature indication

3. Uncontrolled decrease of Pressurizer level or pressure 4 Uncontrolled decrease in steam pressure

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EMERGENCY BORATION ? ,'.

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4.0 SYMPTOMS

(Cont.)

l iw.J I j 4.2 Unexplained or uncontrolled reactivity increase as indicated by: 4 / ./

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1. Abnormal Control Element Assembly insertion l !

2. Abnormal increase in reactor coolant temperature, Tave or reactor power

3. Abnormal increase in reactor power or count rate when shutdown 4.3. Loss of Shutdown Margin due to excessive Control Element Assembly insertion as indicated by:

1. Power dependent insertion (data processor) alarm

2. Power dependent insertion ( ADS) alarm /R1 e

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y Page 3 of A ST. LUCIE UNIT 2

/ OFF-NORMAL OPERATING PROCEDCRE No. 2-0250030 REVISION 1 gr - ~.

EMERGENCY BORATION ~

3 i j ,

5.0 INSTRUCTIONS L : , s J

/

5.1 Immediate Automatic Actions

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NONE I*

!b i 5.2 Immediate Operator Actions 5.2.1 Place Makeup Mode Select Switch in the MANUAL or BORATE position.

5.2.2 Verify V-2525 (Boron Load Control Valve) is closed.

, 5.2.3 Place either 2A or 23 Boric Acid Makeup Pump in the RUN position.

5.2.4 Place V-2514 (Emergency borac' e- valve) in the OPEN position.

5.2.! Close V-2650 (BAE 2A Recir) and V-2651 (3AMr 2B Recir).

5.2.6 If V-2514 fails to open, open either V-2509 (BAMT 2A gravity feed) or V-2508 (BAXI 2B gravity feed) and'close V-2501 (VCT outlet).

5.2.7 If emergency boration is warranted due to violation of Power Dependent insertion Limit, observe Tave, Tref; and reactor power while borating the Reactor Coolant System sufficiently to insure resto ation of shutdown margin and the clearing of PDIL alarms.

5.2.8 For other reactivity changes in Section 4.0 as boron is added, observe Tave, Tref, reactor power, and Control Element Assembly position until the reactivity excursion is under control.

5.3 Subsequent Actions

5. 3.1' After the boration, place V-2514 in the CLOSED position.

. Af ter verifying closure, position switch to the AUTO position.

A 5.3.2 Open V-2650/V-2651 B.A. Pump Recire Valve (s).

5.333 'If gravity fe ed us used, open V-2501 and close V-2508/V-2509.

5.3.4 Stop the BAM Pump and return the switch to the AUTO position.

r 5.3.5 Return Mode Selector Switch to the desired mode of operation.

5.3.6 Reopen V-2650 and V-2651.

5.3.7 Operation with 7-2525 may be resumed if necessary.

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Pagt i of 4 i ST. LUCIE U'IIT 2 l OFF-NOPJ'.AL OPE 1\ TING PROCEDURE NO. 2-0250030, REVISION 1 E'd.ERGENCY BOPATION ['.4 .

{ 73

6.0 REFERENCES

a a ,A i 6.1 St. Lucie Unit 2 FSAR, Chapter 9 6.2 C.E. Emergen'y Procedure F-EP-11 g

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Page 1 of 8

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FLORIDA POWER 5 LICHT CC;1PANY ST. LUCIE UNIT 2 b'3/j ;

l 01F NORMAL OPERATING PROCEDURE hUMBER 2-0310030 '

//'

REVISIOh 1 gl e e !

1.0 TITLE

COMPONENT COOLING WATER - CFF NORMAL OPERATION 2.0 REVIEk AhD APPROVAL:

Reviewed by Facility Review Group December 28 1982 Approved by J. H. Barrow (for) Plant Manager December 28 1982 Revision 1 Reviewed by FRG _ M JF 19D Approved by A /1/ (2 4_s /t [ d f.lant hanager /d / 3)-19 [3

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/

(/ i 3.0 PURPOSE AND DISCUSSION:

3.1 This procedure provides instructions to re-establish Component Cooling Water flow or isolate affected headers or components in the event of a malfunction in the Component Cooling kater (CCW) System.

3.2 Any indications that a possible malfunction is occurring in the CCW System must be thoroughly investigated immediately.

4.0 SYMPTOMS

4.1 Decrease in CCW Surge Tank level and/or Low CCW Tank Level alarm 4.2 Abnormal flows in headers as indicated by FIS-14-1A and FIS-14-1B 4.3 Low pressure in headers as indicated by PIS-14-8A and PIS-14-8B 4.4 High level in CCh Surge Tank 4.5 Increasing CCW temperature (s) 8 b6 . ,,' ] ' ' ' ' = 3r I

This document is not c;ng,gf,[. . ~ " ' t J_*ify informafien with a contro fed do

Page 2 of 8 ST. LUCIE UNIT 2 OFF h0RMAL GPERATING PROCEDURE NUMBER 2-0310030 REVISION 1 y

[%

COMPONEhT COOLING WATER - 0FF NORMAL OPERATION l aj 5

x ..

.I

5.0 IhSTRUCTIONS

l/ a

5.1 Immediate Automatic Actions b===q 5.1.1 CCW Surge Tank vent (RCV-14-1) diverts to chemical Drain Tank on high radioactivity in the CCh system.

5.1.2 hCV-14-8B and hCV-14-10 will auto close on low level in the CCh Surge Tank as sensed by LS-14-63. This will isolate the "B" header f rom the "N" header.

( 5.1.3 hCV-14-BA and MCV-14-9 will auto close on low level in the CCW Surge Tank as sensed by LS-14-6A. This will isolate the "A" header f rom the "N" header.

5.1.4 A Reactor trip will occur on 2/4 logic on low flow from the combined CCW return f rom the Reactor Coolant Pumps. There is a ten minute time delay on this trip.

5.2 Immediate Operator Actions hone 5.3 Subsequent Action i~ 5.3.1 Loss of 2A CCW Pump

1. tpen hV-14-1 (2C CCW Pump disch to "A" hdr) and MV-14-3 (2C CCW Pump suction f rom "A" hdr).

2. Close hV-14-2 (2C CCW Pump disch to "B" hdr) and MV-14-4 (2C CCW Pump suction f rom "B" hdr).

3. Realign 4.16KV 2AB bus to the 2A3 4.16KV bus. /R1

4. Start 2C CCW Pump.

5. Verify that pressures and flows return to normal.

6. Realign 480V Load Center 2AB to the ZA2 Load Center and realign 2AB DC bus to the 2A DC bus within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months .

The alignment of the discharge valves shall be verified to be consistent with the appropriate power supply at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . /R1 5.3.2 Loss of 23 CCW Pump

1. Verify that MV-14-2 (2C CCh Pump disch to "B" hdr) and MV-14-4 (2C CCW Pump suction from "B" hdr) are open.

2. Ensure 4.16KV bus 2AB is aligned to the 2B3 4.16KV bus. /R1

3. Start 2C CCW Pump.

4. Verify that pressures and flows return to normal.

l S. Ensure 480 Load Center 2AB is aligned to the 2B2 Load Center and ensure 2AB DC bus is aligned to the 23 CC bus. The alignment of the discharge valves shall be veritied to be consistent with the appropriate power supply at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . /R1 ,,,

Page 3 of 8 ST. LUCIE UNIT 2 0FF NORMAL OPERATING PROCEDURE SUMBER 2-0310030, REVISICN 1 [h COMPONENT COOLIhG kATER - 0FF NORMAL OPERATIOh j f=

1;: }

4 I, a : -,

1 i

5.0 IhSTRUCTIONS

(Cont.) j ,,j/

f 5.3 (Cont.) /

Loss of ZA CCW Beat Exchanger I I 5.3.3

1. Open MV-14-3 (2C CCW Pump suction f rom "A" hdr) .

2. Verify that MV-14-2 (2C CCW disch to "B" hdr) is open.

3. Verify that MV-14-1 (2C CCW Pump disch to "A" hdr) is closed and start 2C CCh Pump.

4. Stop 2A CCW Pump.

5. If plant is in process ot cooling down or heating up, isolate 2A SDC Heat Exchanger by closing MV-3517 (Primary side inlet) and BCV-14-3A on CCW side. Also close MV-1410 and MV-1412 which stops CCW flow through 2A and 2B Containment Fan Coolers.

h0TE: This step should reduce CC% flows to within licits of one heat exchanger.

6. If plant is at power or hot shutdown, proceed to isolate 2A CCW Beat Exchanger by closing V-14156 (Inlet valve) and V-14166 (Outlet valve). If heat exchanger cannot be repaired within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months be it at least Hot Standby ,

within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and Cold Shutdown within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

5.3.4 Loss of 2B CCW Heat Exchanger

1. Verify that MV-14-4 (2C CCW Pump suction f rom "B" hdr) is open.

2. Open MV-14-1 (2C CCW Pump disch to "A" hdr) .

3. Close MV-14-2 (2C CCW Pump disch to "B" hdr) and start 2C CCW Pump.

4. Stop 2B CCW Pump.

5. If plant is in process of cooling down or heating up, isolate 23 SDC Heat ' Exchanger by closing MV-3658 (Primary side inlet) and BCV-14-3B on CCW side. Also close MV-1414 and MV-1416 which stops CCW flow through 2C and 2D Containment Fan Coolers.

NOTE: This step should reduce CCW flows to within limits of one heat exchanger.

O

Page 4 of 3 ST. LLCIE UNIT 2 0FF h0RMAL CPERATI.% PRCCEDURE hthBER 2-0310030, REVISION 1 ,O, COMFONEhT COOLING kATER - 0FF NORMAL OPERATICN p *

5.0 IhSTRUCTIchS

(Cont.)

5.2$)3 g' f.

5.3 (Cont.) y

/ I 1 1 5.3.4 (Cont.) 1

6. If plant is at power or hot shutdown, proceed to isolate 2B CCW Heat Exchanger by closing V-14160 (Inlet valve) and V-14177 (Outlet valve). If heat exchanger cannot be repaired within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months , be in at least Hot Standby within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and Cold Shutdown within tne following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

5.3.5 Rupture of "A" Component Cooling Water Header

1. BCV-14-BA and HCV-14-9 ("A" hdr ties to non-essential hdr) will close automatically on low level (LS-14-6A) in the CCW Surge Tank. This isolates the ruptured header.

2. Stop 2A CCW Pump.

NOTE: CCW will be lost to:

2A hPSI Pump 2A and 2B Containment Fan Coolers

[ 2A SDC Heat Exchanger 3A and 3C Control Room A.C. Units

3. If the plant is in a cooldown or heacup condition, the primary side of 2A SDC Heat Exchanger must be isolated by closing MV-3517 (primary side inlet).

5.3.6 Rupture of "B" Component Cooling bater header

1. HCV-14-8B and ECV-14-10 ("B" hdr ties to non-essential hdr) will automatically close on low level (LS-14-6B) in the CCW Surge Tank. This isolates the ruptured header.

2. Stop 2B CCW Pump.

3. Close hv-14-17 and hv-14-19. Open MV-14-18 and MV-14-20.

This will feed the Fuel Pool Heat Exchanger from the "A" Header.

NOTE: If the "A" header begins to de-pressuri:e af ter this evolution, the rupture is on the header to or from the Fuel Pool Heat Exchanger.

NOTE: CCW will be lost to:

2B hPSI Pump

, 2C and 2D Containment Fan Coolers

. 2B SDC Heat Exchanger 3B Control Room A.C. Unit Fuel Fool Heat Exchanger l

l _.,

l l

Page 5 of 8 ST. LUCIE UNIT 2

^

0FF NOILW. OPERATlhG PROCEDURE athSER 2-0310030. REVISION 1 .- 3 CohPohENT C00LIhG kATER - CFF 50RMAL OPERATIch 4, jo i k iI>

5.0 IhSTRUCTIONS

(Cont.) /I

~

J 5.3 (Cont.)

5.3.6 (Cont.) ,,,,,,,,b

4. If the plant is in a cooldown or heat up condition, the primary side of 2B SDC heat Exchanger must be isolated by closing MV-3658 (Primary side inlet).

5.3.7 Loss of 2A Shutdown Cooling Heat Exchanger

1. Isolate the 2A SDC Beat Exchanger by closing:

A. MV-3517 B. MV-3456 C. V-7161 (2A hx outlet to spray hdr)

D. V-7145 (2A CS pump disch) ,

E. V-14348 (2A hx CCW supply from "A" hdr)

F. V-14365 (2A Ex CCW return f rom "A" hdr)

2. hith the spray additive system inoperable, restore the system to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or be in at least hot Standby within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ; restore the spray additive system to OPERABLE status within the next 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in Cold Shutdown within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

5.3.8 Loss of 2B Shutdown Cooling Heat Exchanger

1. Isolate the 2B SDC Heat Exchanger by closing:

A. MV-3658 B. MV-3457 C. V-7164 (2B Ex outlet to spray hdr)

D. V-7130 (2B CS pump disch)

E. V-14357 (2B Bx CCW supply from "B" hdr)

F. V-14487 ( 2B Ex CCW return to "B" hdr)

2. With the spray additive system inoperable, restore the system to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or be in at least Hot Standby within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ; restore the spray additive system to OPERABLE withis the next 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in Cold Shutdown within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

f 1

l s

"- Page 6 of 8 ST. LUCIE UNIT 2

OFF hORMAL OPERATING PROCEDURE SUMBER 2-0310030, REVISION 1 . I I '

COMPOSENT C00LIhG WATER - 0FF NORMAL OPERATION j

( ;

& )( /

1

5.0 INSTRUCTIONS

(Cont.) jf (Cont.) / *I 5.3

/ W 5.3.9 Loss of a Containm4nt Fan Cooler

1. Isolate the afrected Containment Fan Cooler by closing its associated inlet and outlet valves.

2A Containment Fan Cooler MV-14-9 (Inlet valve)

MV-14-10 (Outlet valve) 2B Containment Fan Cooler MV-14-11 (Inlet valve)

MV-14-12 (Outlet valve) 2C Containment Fan Cooler MV-14-13 (Inlet valve)

MV-14-14 (Outlet valve) 2D Containment Fan Cooler i

MV-14-15 (Inlet valve)

MV-14-16 (Outlet valve)

2. With one Containment Fan Cooler inoperable and both Containment Spray Systems operable, restore the inoperable Containment Fan Cooler to operable status in 30 days or be in hot Shutdown in the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

5.3.10 Rupture of Non-essential Component Cooling kater Header

1. hCV-14-8A and HCV-14-9 will close automatically on low level (LS-14-6A) in the CCW Surge tank. This isolates "A" header from "h" header.

2. HCV-14-8B and hCV-14-10 will close automatically on low level (LS-14-6B) in the CCW Surge tank. This isolates "B" header from "h" header.

3. A reactor trip will occur on 2 of 4 logic on low flow

, from the combined CCW return from the Reactor Coolant Pumps. There is a ten ainute time delay on this trip.

4. As Reactor Coolant Pump seal temperature approaches 25CoF or Reactor Coolant Pump bearing temperatures approaches 194oF, remove the RCPs frca service.

4

=-. -

Page 7 of 8 j ST. LUCIE UNIT 2 0FF h0RMAL OPERATIhG PROCEDURE hW BER 2-0310030, REVISIch 1 ,,s g COMP 0hEh! C00LIhG WATER - OFF h0RMAL OPEkATIOh / <

s ! <i~ 4 h

5.0 INSTRUCTIOhS

(Cont.) u ~[ j /

af j f 5.3 (Cont.) j/' ,/

O W 5.3.10 (Cont.) 1

5. Isolate letdown.

CAUTION: PRESSURIZER LEVEL WILL HAVE TO BE MONITORED CLOSELY.

1

6. Remove the following equipment from service:

A. 2A BA Concentrator B. 2B RA Concentrator C. Waste Concentrator D. 2A kaste Gas Compressor E. 2B Waste Gas Compressor F. Sample heat Exchangers 5.3.11 Righ Level in CCW Surge Tank

1. Check Surge Tank flow meter. If make up flow is indicated, close V-14100 (Make-up Isol) and check V-14101 (Alternate make-up supply) to be closed.

2. If high radiation is indicated in the CCW System, refer to Off-hormal OP #2-0210021 " Component Cooling kater - Excessive Activity".

5.3.12 Increasing CCW Temperature

1. Investigate and determine the cause of the increasing temperature. It may be either a component served by CCW or malfunction of ICW. If a problem with ICW is indicated, refer to Off-Normal OP #2-0640030, 'ICW System -.0ff hormal Operation".

t e dP

Page 8 of 8 ST. LUCIE UNIT 2

/D ,,

0FF NORhAL OPERATING PRCCEDURE hthBER 2-0310030, REVISION 1 COMP 0ht.hT COGLING WATER - 0FF SORMAL OPERATIOh ! p j 3

!j j

6.0 REFEREhCES

j #

j' 6.1 Ebasco P&ID 2998-G-083 /

6.2 . CE P&ID E-13172-310-130 <

7.0 RECORDS REOUIRED:

7.1 hormal log entries o

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Emergency Procedure h '.

2-0810040 M. S. L. 3.

Rev. I j_q 1, j 4

/y)./

m; FLORIDA PO'JER & LIGliT COMPAhT ST. LUCIE UNIT NO. 2 EMERGENCY PROCEDURE NUMBER 2-0810040 REVISION 1 MAIN STEAM LINE BREAK REV. ! FRG. 4 -LL -6)

Approval .70 0- u s b it.Mngr. P M 73

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TOTAL NO. OF PAGES 19

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Page 2 of 19f O

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$ f FLORIDA PC'4ER & LIGHT COMPA Tl f

.a ST. LUCIE PLANT UNIT 2 '

EMERGENCY PROCEDURE NUMBER 2-0810040 REVISION 1

1.0 SCOPE

Provide operator actions to be taken when an uncontrolled steam release occurs from a steam generator.

2.0 SYMPTOMS

/

NOTE: Figure 2.1, page 5, may assist in evaluatine this event.

2.1 Loud noise audible in the 2.1 Indications control room Steam break outside containment 2.2 Continuously decreasing Tgyg 2.2 Indications Excess steam demand from secondary system TR-illl, TR-ll21, TR-il20E /R1 2.2 Ala rms K-25 2.3 Abnormally low pressure 2.3 Indicat-tons in one or both steam PI-8023A,3,C,D generators. PI-8013A,3,C,D PR-8013D, 8023D s

2.3 Ala rms P-17,P-19 l

I

. es

Page 3 p ,

MSLB f

'g ST. LUCIE UNIT NO. 2 .n==dI 4 EMERGENCY PRCCEDURE NUMBER 2-0810040, REVISION 1 MAIN STEAM LINE BREAK j/

o

2.0 SYMPr0MS

(Cont.) , ,

_3 2.4 Rapid decrease in S/G level 2.4 Indications LR-9013D/9023D /R1 LR-9011, 9021 LIC-9013-A,B,C,D LIC-9023-A,B,C,D LI-9012-1, 9022-1 /R1 L1-9012, 9022 /R1 2.4 Alarms G-1, G-9 2.5 Reactor Trip 2.5 Indications Turbine Trip ADS Display (CEA's inserted)

RPS-Trip units No.1, 4, 7, or 9 RPS-TC3's Open Gen. Output = 0, WR-871, CEA Display (Core Mimic) /R1 2.5 Alarms D-8, L-3, L-5, L-9, L-11, L-13, L-17, L-36, L-44 /R1 2.6 A. Increased steam flow 2.6 Indications and/or feed flow U'dtil MSIS occurs B. Decreased generator output FRe8011,9011 FR-8021, 9021 FI-08-1A,13, FI-09-1A,1B, WR-871 /R1 2.6 Alarms G-17 2.7 Decreasing Pressurizer level and 2.7 Indications pressure LI-1110X,Y,LIC-1110X,Y PI-1102A,B,C,D PR-1100, LR-1110, LR1110X 2.7 Alarms R-1, H-2, H-3, H-4, E-9, H-10, H-17, H-18 /R1 2.8 Containment Radiation 2.8 Indications monitors are normal NO h1 radiation alarms from containment. Differentiates between LOCA and MSLB.

2.9 Hi Containment Pressure 2.9 Indications Break inside containment PIS-07-2A,23,2C,2D 2.9 Alarms . . ,

P-13,P-23

Page 4 of

MSL3 .

$ 1") b ST. LUCIE UNIT NO. 2 !;

EMERGENCY PROCEDURE NUMBER 2-0810040, REVISION 1 /t

f MAIN STEAM LINE BREAK af

.f

2.0 SYMPTOMS

(continued) L t 5 -J 2.10 Containment Reactor Cavity 2.10 Indications _-

Sump level increasing Breax inside containment LIS-07-6 , F R-0 7-3 2.10 Alarms N-21,N-29 2.11 MSIS Actuated 2.11 Indications Equipment isolates as per Table I /R1 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 Table III /R1 2.12 Alarms R-6 , R-16 , R-2 6 ,Q-3 , P-3 ,

P-13,P-23 2.13 CSAS Actuated 2.13 Indications Equipment operates per Table IV /R1 2.13 Ala rms S-7 , S-17 /R1

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Page 6 of 19 VSLB ST. LUCIE UNIT NO. 2 p o EMERCENCY PROCEDURE NUMBER 2-0810040, REVISION 1 y MAIN STEAM LINE BREAK d 3.0 IMMEDIATE AUTOMATIC ACTION:

/

AUTOHATIC ACTION INITIATING EVENT 3.1 Reactor Trip 3.1 S/G low press 626 psia decreasing /R1 3.2 Turbine trip 3.2 Reactor trip bus low voltage 3.3 Generator lock-out 3.3 Turbine trip /R1 3.4 Auxiliaries change to 3.4 Frcm gen. lock-out Start-up transformer 3.5 MSIS 3.5 600 psia S/G press.

decreasing or 5 psig cont.

press increasing 3.6 SIAS 3.6 1736 PSIA RCS press.

decreasing or 5 psig cont.

press increasing /R1 3.7 CIAS 3.7 5 PSIG cont. press.

increasing or Hi cont, radiation > 10 R/HR or from SIAS actuation.

3.8 CSAS 3.8 9.3 psig cont. press, concurrent with SIAS /R1 3.9 AFAS (feeds only the 3.9 S/G 1evel < 20.6% /R1 non-faulted S/G) e 1

t e

Page 7 of 19 f

MSL3 ST. LUCIE UNIT NO. 2 i EMERGENCY PROCEDURE NUM3ER 2-0810040, REVISION 1 MAIN STEAM LINE 3REAK J j o

4.0 IMMEDIATE OPERATOR ACTION:

/

ACTION NOTES

- , s

-J 4.1 Carry out standard immediate 4.1 If necessary, refer to operator actions for a reactor RX Trip Procedure trip 0F #2-0030130 /R1 4.2 Ensure SIAS actuates if 4.2 SIAS actuates on:

if conditions require. 1736 psia low RCS press. /R1 5 psig Hi cont. press.

If SIAS actuates on low RCS pressure, after verification of all rods inserted > 5 sec., /R1 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 Steam 4.4 Observe S/G pressures and Generator levels /R1 ,

4.5 Ensure AFAS is establishing flow only to the non-ef fected generator.

9 mM.

Pago 3 of 19 MSL3 f O s ST. LUCIE UNIT No. 2 j

e, j'

t EMERGENCY PROCEDURE NUMBER 2-0810040, REVISION 1 ~_ / j 3

MAIN STEAM LINE 3REAK J

5.0 SUBSEOUE!TT ACTIONS:

CHECK l j 5.1 Use all available indications to determine if the RCS is in a sub-cooled or saturated condition. If saturated conditions occur, the operator must ensure that the RCP's are turned off, the SIS is providing makeup to

. the RCS, and the operable steam generator is removing heat froa the RCS. /R1 NOTE: Information can be obtained from the QSPDS l Display, RCS hot leg temperature, RCS cold leg temperature, incore thermocouple temperature, and RCS pressure to determine if the RCS is sub-cooled or. saturated. An increase in temperature above the saturation temperature for the existing pressure is an indication of voiding in the RCS.

(P-T Nomograoh Available on RTG3-203) /R1 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 i 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-23-7,9.

5.5 When S/G level rises > 392, take control of aux.

feed to halt further feeding of relatively cold water until cooldown transient has terminated

~~

NOTE: Erroneous indications may be observed > 15 minutes af ter a break inside containment.

5.6 When the cooldown has stopp'd and RCS temperature is above 400 F, reinitiate aux. feed flow to the non-f aulted steam generator not exceeding 150 GPM for a period a

of 5 minu.es. Maintain RCS temp. stable with <

atmospheric dumps on the non-faulted steam generator /R1 l l

5.7 , Maintain hot leg temperature less than 520 F with

! auxiliary feed and steam dump to atmosphere'.

NOTE: Du not admit auxiliary feed flow to l

the faulted steam generator regardless of , , , I l location of break.

Page 9 of 19 MSLB 4

ST. LUCIE UNIT NO. 2 : ,

EMERGENCY PROCEDURE NUM3ER 2-0810040, REVISION 1 l j MAIN STEAM LINE BREAK a i

/ s 5.0 SUBSEOUENr ACTIONS: (Cont.) /

CHECK /

5.8 When pressuri=er level on control channels indicates 30% energize all pressurizer heaters f

e k~

a 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 < 520 F verify that pressurizer pressure stabilizes at approximately 1250 PSIA (shut off head of HPSI) /R1 NOTE: Ensuring hot leg temperature less than 520 F and pressurizer pressure greater than 1250 psia ensures a margin of 50 F l subcooled.

5.11 Stop emergency diesel generators if of fsite power is available and feeding the emergency buses.

5.12 When containment pressure is < 9.3 PSIG /R1

\'

a) Reset CSAS b) Stop CS pumps c) Close FCV-07-1A, 1B 5.13 OPEN ICW to TCW Heat Exchangers MV-21-3 and MV-21-2 5.14 CLOSE CCW outlet from SDC Heat Exchangers, HCV-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-8 A, HCV-9 (A side)

"0VERRIDE" HCV-83, HCV-10 (3 side)

(Taking these valves to "0VERRIDE" position will open valves with a SIAS signal present.) /R1 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)

L

Page 10 of 19 MSL3

~.

ST. LUCIE UNIT NO. 2 ,

EMERCENCY PROCEDURE NUu.3ER 2-0810040, REVISION 1 I MAIN STEAM LINE BREAK 5.0 SUBSEOUENT ACTIONS: (continued) ][.:

5.15 (continued) f CHECK L 5.15.3 Restore CCW to individual RCP's seal coolers by opening valves:

Open HCV-14-11A1 Open HCV-14-11A2 Open HCV-14-1131 Open HCV-14-11B2 /R1 NOTE: It may be necessary to cycle l these valves to restore flow. l 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 the transient has been gained with normal pressure control, the safety injection signal may be reset by first key-blocking the ESFAS SIAS signal, then manually resetting the SIAS signal present by taking the channel control switches to the reset position. /R1 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 valves.

5.19 When CIAS has been reset, open the letdown isolation valves, and re-establish charging and letdown per OP OP 2-0210030, " Charging and I.atdown Off-Normal Procedure."

5.20 Resume forced cooling as soon as conditions permit.

5.21 Notify Chem. 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 system will contain Hydrazine. !

i Page 11 of 19 MSLS ST. LUCIE UNIT NO. 2 4 g EMERGENCY PROCEDURE NUMBER 2-0810040, REVISION 1 (* :

MAIN STEAM LINE BREAK ]69)e i

l .

TABLE I MAIN STEAM ISOLATION SIGNAL (MSIS) f i 3 CONDITION CHECK W One (1) Main Steam Line A ISOL.

Valve HCV-08-1A closed One (1) Main Steam ISOL. Valve A bypass MV-08-1A c1csed Two (2) FW. DISCH. to S/G 2A HCV-09-1 A, HCV-09-1B closed Two (2) FW. DISCH. to S/G 2B HCV-09-2A, HCV-09-2B closed One (1) Main Steam ISOL. Line B ISOL. Valve HCV-08-1B closed One (1) Main Steam ISOL. Valve B bypass MV-08-1B closed k

9 I

i 1

. .e l 1

Page 12 of 19 MSLB fg '

I ST. LUCIE UNIT NO. 2 EMERGENCY PROCEDURE NUMBER 2-0810040, REVISION 1 Wl} )

MAIN STEAM LINE BREAK ' ,/

TABLE II e

SAFETY INJECTION ACTUATION SIGNAL (SIAS) ,

g ,-

CONDITION CHECK RTGB 206, Left to Right Two (2) CCW PPS (2A, 2B, or 2C) On /R1 Two (2) CCW to Fuel Pool HX Isolation Valves (MV-14-18, MV-14-17) Closed /R1 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) Ooe n' Two (2) LPSI PPS On Two (2) HPSI PPS On Four (4) LPSI Header Valves to Loops (HCV-3615, HCV-3625, HCV-3635, HCV-3645) Open /R1 Eight (8) HPSI Header Valves to Loops (HCV-3617, HCV-3627, HCV-3637, HCV-3647 - Header A)

(HCV-3616, HCV-3626, HCV-3636, HCV-3646 - Header B) Open /R1 Two (2) Hot Leg Injection Check Viv.

Leakage Valves. (V3572, V3571) Closed Two (2) to RWT/VCT (I-SE-03-2A, 1-SE-03-2B) 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-03-1D) Closed Four (4) SI Check Leakage Test (HCV-3618, HCV-3628, HCV-3638. HCV-3648) Closed Four (4) CCI To/From RCP's ]

(HCV-14-1,'HCV-14-2, HCV-14-7, HCV-14-6) Closed I l Two (2) Intake Cooling Water, Lube Water to i Cire. Water Pumps, Isolation Valves (MV-21-4A, MV-21-4B) Closed /R1- -

l I

Page 13 of 19 MSL3 h

ST. LUCIE UNIT NO. 2 j$ i EMERGENCY PROCEDURE NUMBER 2-0810040, REVISION 1 3 MAIN STEAM LINE BREAK f TABLE II ,[f SAFETY INJECTION ACTUATION SIGNAL (SIAS) /

(continued) 9 CONDITION CHECK i RTUB 205 Two (2) Boric Acid Make-up Pumps 2A and 2B Start Two (2) Boric Acid Make-up Tank Recire Vlv'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) Ooen 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-07-11A, LCV-07-11B)

RTUB 202 Two (2) Intake Cooling Wtr Pumps On Two (2) Intake Cooling Wtr Isolation Valves (MV-21-3, MV-21-2) Closed RTCB 201 Two (2) Diesel Generators On 4

I

Page 16 of 19 MSLB ST. LUCIE UNIT NO. 2 3 EMERGENCY PROCEDURE NUMBER 2-0810040, REVISION 1 8 MAIN STEAM LINE BREAX ilj TABLE II

.7

[ ,5 SAFETY INJECTION ACTUATION SIGNAL (SIAS)

(continued)

CONDITION CHECK -

]

HVAC PANEL LEFT TO RIGHT Four (4) RAB Main Supply and ECCS Exhaust Fans (2-HVS-4 A, 2-HVE-9 A, 2-HVS-4B , 2-HVE-9B) on Four (4) Containment Fan Coolers On slow (2-HVS-1 A, 2-HVS-1B , 2-HVS-1C, 2-HVS-1D) Soeed Sixteen (16) ECCS Isolation Dampers (DI, D2, D3, D4, D5A, D6A D7A, D8A, D9A, D12A, DSB, D6B, D7B, D8B, D9B and D123) Closed /R1 NOTE Any spare equipment that is running and not needed for controlling this incident should be STOPPED.

l 9

Page 15 of 19 MSLB f e==%s ST. LUCIE UNIT NO. 2 3 fi EMERGENCY PROCEDURE NUMBER 2-0810040, REVISION 1 OI ;

MAIN STEAM LINE BREAK TABLE III j r

/

CONTAINMENT ISOLATION ACTUATION SIGNAL (CIAS) -

CONDITION CHECK RTGB 206, Left to Right Two (2) to RWT/VCT (I-SE-03-2A, I-SE-03-28) Closed /R1 Five (5) SI Tank Sample Isolation Valves (ISE-05-1 A, ISE-05-1B , ISE-05-1C, ISE-05-1D, ISE-05-1E) 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, 9) Closed /R1 Six (6) Containment Sample Isolation Valves (FCV-26-2, FCV-26-4, FCV-26-6, FCV-26-1, FCV-26-3, FCV-26-5) Closed /R1 RTGB 205 /R1 Two (2) Containment Sump Isolation Valves (LCV-07-11A, LCV-07-11B) Closed Six (6) RCS and pressurizer Sample Isolation valves (V5200, V5201, V5202, V5203, V5204, 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 Three (3) Letdown Isolation Valves (V2516, v2522, V2515) Closed RTGB 201 ,

Two (2) Diesel Generators on

Page 16 of 19 MSLB 4

I ST, LUCIE UNIT NO. 2 %

fl EMERGENCY PROCEDURE NUMBER 2-0810040 REVISION 1 .,di HAIN STEAM LINE BREAK I y

.?

TABLE III y [

CONTAINMEYT ISOLATION ACTUATION SIGNAL (CIAS) [ b 'I I

(continued) 3 CONDITION CHECX HVAC Panel, Lef t to Right One (1) Shield Exhaust Fan and One (1) Control Room Emergency Filter Fan (2-KVE-13 A, 2-HVE-6A) On /R1 Four (4) Control Room Isolation Valves (FCV-25-24, FCV-25-17, FCV-25-18, FCV-25-16) Closed She (6) Containment Purge Isolation Valves (FCV-25-1, FCV-25-3, FCV-25-5, FCV-25-6, FCV-25-4, FCV-25-2) Closed /R1 Three (3) Continuous Containment Purge Valves (FCV-25-20 FCV-25-26, FCV-25-21) Closed /R1 Two (2) SBVS Isolation Valves (FCV-25-32, FCV-25-33) Ooen /R1 Two (2) Fuel Handling Emergency Vent Valves (FCV-25-30, FCV-2S-31) Closed /R1 One (1) Shield Exhaust Fan and One (1) Control Room Emergency Filter Fan (2-HVE-13B, 2-HVE-6B) On /R1 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 I

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Page 17 of 19 MSLB d""N ST. LUCIE UNIT NO. 2 EMERGENCY PROCEDURE NUMBER 2-0810040 REVISION 1 MAIN STEAM LINE BREAK ,.; ,

TABLE IV

/ CONTAINME?rf SPRAY ACTUATION SIGNAL (CSAS)

CONDITION CHECK ,

Two (2) Containment Spray PPS. 2A, 23 On Two (2) Containment Spray EDR. ISOL.

Valves FCV-07-1 A,1B Coen Two (2) Hydrazine PP's 2A, 2B on /R1 Two (2) Hydrazine Pump Discharge Valves I-SE-07-3A, 3B open

.l NOTE: Verifv Flow on FI-07-1 A, 1B l e

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Page la of 19 MSL3 g,m==g a s ST. LUCIE UNIT NO. 2 j f ;

EMERGENCY PROCEDURE NUMBER 2-0810040, REVISION 1 MAIN STEAM LINE BREAK y )}a i

6.0 PRECAUTIONS

A rupture of a steam line is assumed to include any accident which n 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 calfunction 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 f alls. 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 1736 PSIA pressurizer pressure or 5 PSIG containment pressure (break inside containment). /R1 All available indications should be used to aid in diagnosing the event since the accident may cause irregularities in a particular instrument reading. Critical parameters must be verified when one or more confirmatory indications are available. With the 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 h, pressurizer pressure, and incore thermocouples to determine the margin to saturation. Subccoling margin can also be determined 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 of f, the SIS is providing makeup to the RCS, and that the operable steam generator is removing heat from the RCS.

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Page 19 of 19 MSL3 ST. LUCIE UNIT NO. 2 f ~*

EMERGENCY PROCEDURE NUMBER 2-0810040, REVISION 1 i I MAIN STEAM LINE BREAK .I

7.0 REFERENCES

,j FSAR Sect. 6, 7, 15 l .

Operating Procedure 0810040 (Unit #1)

C. E. Guidelines (CEN-152)

Draft of Nureg - 0799 8.0 RECORDS REOUIRED:

Nor:nal log entry Recorders covering transient conditions

9.0 APPROVAL

Reviewed by Facility Review Group OC E. ~2 lo 19 8 2.

Approved by J. H. Barrow ( for) Plant Manager cc:t. t(, 19 8 %

Revision 1 Reveiwed by FRG docil L L 196 3

, Approved by d hba wu [91 ant Manager V - 31 19 -

U LAST PAGE E:nergency Procedure 2-0810040 Rev. 1 TOTAL NO. OF PAGES 19

. ed

ML20079R307

Text

4.0 Symptoms

5.0 Instruction

5.0 Instruction

5.0 Instructions

5.0 Instructions

5.0 Instructicas

5.0 Instructions

5.0 Instructions

References:

1.0 SCOPE

2.0 SYMPTOMS

==

6.0 DISCUSSION

6.0 DISCUSSION

7.0 REFERENCES

9.0 APPROVAL

1.0 SCOPE

2.0 SYMPTOMS

6.0 DISCUSSION

7.0 REFERENCES

9.0 APPROVAL

1.0 TITLE

2.0 APPROVAL

3.1 Purpose

3.2 Discussion

5.0 INSTRUCTIONS

5.0 INSTRUCTIONS

5.0 INSTRUCTIONS

5.0 INSTRUCTIONS

5.0 INSTRUCTIONS

5.0 INSTRUCTIONS

6.0 REFERENCES

1.0 TITLE

2.0 APPROVAL

4.0 SYMPTOMS

4.0 SYMPTOMS

6.0 REFERENCES

1.0 TITLE

4.0 SYMPTOMS

5.0 IhSTRUCTIONS

5.0 IhSTRUCTIONS

5.0 IhSTRUCTIchS

5.0 IhSTRUCTIONS

5.0 INSTRUCTIONS

5.0 INSTRUCTIOhS

6.0 REFEREhCES

1.0 SCOPE

2.0 SYMPTOMS

2.0 SYMPr0MS

2.0 SYMPTOMS

6.0 PRECAUTIONS

7.0 REFERENCES

9.0 APPROVAL

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