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Public Version of Revised Offnormal & Emergency Operating Procedures,Including Procedures 2-0030140 Re Blackout operation,2-0030141 Re Control Room Inaccesibility & 2-0910030 Re start-up Transformer
	ML20024A607
Person / Time
Site:	Saint Lucie
Issue date:	05/09/1983
From:	Hallen; FLORIDA POWER & LIGHT CO.
To:	; NRC OFFICE OF INSPECTION & ENFORCEMENT (IE)
Shared Package
ML17214A242	List: ML17214A243; ML20024A607;
References
	PROC-830509, NUDOCS 8306210392
	Download: ML20024A607 (200)
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FLORIDA POWER & LIGHT COMPANY / ST. LUCIE UNIT NO. 2 0FF-NORMAL OPERATING PROCEDURE NO. 2-0910030 REVISION 0 j

1.0 Title

hDIAUIC'f! O!!LY ? This documen, i, n 3, c,.m ;,;; .., Start-Up Transformer Off-Normal Operation verify information with a e, "'%

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2.0 Review and Approval: _

Reviewed by Facility Review Group /b bl9h Approved by L , oi ,, k D at. Manager f - 9 19 Revision v Reviewed by F R G 19 _ Approved by Plant Manager 19 _ 3.0 Purpose and Discussion: 3.1 This procedure provides instructions to follow in case of a malfunction or loss of start-up transformers 2A and/or 2B in order to minimize possible damage and outage time. 3.2 Since failure of the start-up transformer may cause a loss of power not only in the plant but the 240 KV switchyard as well, it is important that prompt action be taken to determine the cause of any malfunction and/or alarm and its solution. 3.3 In order to minimize the possibility of damage and/or injury, no mechanical or electrical interlock should ever be intentionally overridden nor should any feeder breaker that has tripped due to an automatic protective feacture be reclosed until the cause has been determined and corrected or isolated. A 4.0 Synptoms: Indications of a malfunction and/or loss of a start-up transformer can be

         ,.                    any one or more of the following:
         .c                    4.1   Start-Up transformer 2A differential current trip, window B-1.

4.2 Start-Up transformer 2A fault pressure trip, window B-ll.

             .                 4.3 Start-Up transformer 2A alarm panel, window B-21, i

4.4 Start-Up transformer 2A 4 KV ground, window B-31. 4.5 4 KV switchgear (SWGR) 2A2 feeders overload trip, window B-41. . 4.6 Start-Up transformer 2A 240 KV ground trip, window B-2. i I l

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Page 2 of 8 ST. LUCIE UNIT NO. 2 OFF-NORMAL OPERATING PROCEDURE NO. 2-0910030, REVISION 0

o START-UP TRANSFORMER OFF-NORMAL OPERATION j

4.0 Symptoms

(continued) 4.7 Start-Up transformer 2A lockout relay failure , window B-12. 4.8 Start-Up transformer 2A 6.9 KV ground, window B-32. '

4.9 6.9 KV SWGR 2Al feeders overload trip , window B-42. 4.10 6.9 KV SWGR 2Al differential current trip, window B-3. 4.11 4 KV SWGR 2A2 differential current trip, window B-13. 4.12 6.9 KV SWGR 2Al/ 4 KV SWGR 2A2 undervoltage, window B-23. 4.13 6.9 KV SWGR 2Al/2A2/2A3/2AB differential lockout relays failure, window B-4 4.14 Start-Up transformer 23 dif ferential current trip, window A-1. 4.15 Start-Up transformer 2B f ault pressure trip, window A-ll. 4.16 Start-Up transformer 2B alarm panel, window A-21. 4.17 Start-Up transformer 2B 4 KV ground, window A-31. 4.18 4 KV SWGR 2B2 feeders overload trip, window A-41. 4.19 Start-Up transformer 23 240 KV ground trip, window A-2. 4.20 Start-Up transformer 2B lockout relay failure, window A-12. 4.21 Start-Up transf ormer 2B 6.9 KV ground, window A-32. 4.22 6.9 KV SWGR 231 feeders overload trip, window A-42. 4.23 6.9 KV SWGR 2B1 differential current trip, window A-3. 4.24 4 KV SWGR 2B2 dif ferential current trip, window A-13. 4.25 6.9 KV SWGR 2Bl/4 KV SWGR 2B2 undervoltage, window A-23.

e. 4.26 6.9 KV/4 KV SWGR 2Bl/2B2/2B3 differential lockout relays failure,

    .                            window A-4 N                      4.27 Fire Pump 1A/1B running, window F-8.

th 21 4.28 Transformer Deluge operating, window F-16.

  "M                      4.29 Automatic starting of one or both diesel generators.
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' fl 4.30 various Control Room electrical metering and switch indicating

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Page 3 of 8 ST. LUCIE UNIT NO. 2 0FF-NORMAL OPERATING PROCEDURE NO. 2-0910030, REVISION 0 START-UP TRANSFORMER OFF-NORMAL OPERATIOh If,g % i

5.0 Instructions

5.1 Start-Up transformer lockout 5.1.1 Indications - the following are some of the indications that will accompany a transformer lockout: I A. Loss of power to the associated 6.9 KV and 4 KV SWGR. B. Various alarms f rom section 4.0. C. Loss of power to switchyard east or west hus . 5.1.2 Causes - any one of the following can cause a lockout of the Start-Up transformer: A. Transformer 2A (23) differential current B. Transformer 2A (2B) fault pressure C. Transformer 2A (2B) 240 KV ground 5.1.3 Automatic Actions:

    .                             A. Start-Up transformer 2A:

1. Transformer cooling equipment cut off

2. 4 KV breaker 2-20605 (1W88) to SWGR 2A4 and 6.9 KV breaker 2-30102 to SWGR 2A1 trip B. Start-Up transformer 23:

1. Transformer cooling equipment cut off 2, 4 KV breaker 2-20705 (1W82) to SWGR 2B4 and 6.9 KV

        ,                                  breaker 2-30202 open.

C. Start-Up transformer 2A and/or 2B: d 1. Diesel generator (s) 2A and/or 2B start, come up to [.

      ,s speed and voltage.

2. Bus stripping has cleared 4 KV SWGR 2A3 and/or 2B3 and/or 2AB.

,( 3. Diesel Generator (s) 2A and/or 2B close in on their y respective buses and are sequentially loaded.

~2(                        5.1.4  Operator Actions:

A. If any automatic action has not occurred, the operator should manually execute the required steps. B. Determine the cause of the lockout from step 5.1.2 and take necessary steps to correct. NOTE: If fault pressure has malfunction, the circuit may be de-energized by placing the fault pressure toggle switch to 0FF with the permission of the Nuclear Plant Supervisor. C. Notify the load dispatcher of the lockout and plant conditions. I 1 l

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j ' f- i 0FF-NORMAL OPERATING PROCEDURE NO. 2-0910030, REVISION 0 ; START-UP TRANSFORMER OFF-NORMAL OPERATION j - 5.0 Instructions : (continued) 5.2 Loss of Start-Up Transformer Feeder Breaker - 5.2.1 Indications - the following are some of the indications that - will accompany a loss of a Start-Up transformer breaker: A. Loss of power to the associated 6.9 KV or 4 KV SWGR. B. Various alarms from section 4.0 C. Possible loss of power to the switchyard east or west bus 5.2.2 Causes - any one of the following could cause an automatic protective trip of a Start-Up transformer breaker: A. Current overload B. Associated bus lockout due to current differential ! C. Associated transformer lockout (section 5.1) D. Switchyard backup lockout 5.2.3 Automatic Action: A. 6.9 KV and 4.16 KV feeder breakers will trip. B. None of the other trips of a 6.9 KV breaker initiate automatic features, although by loss of the operating equipment on the bus, protective features concerned with those systems will actuate. C. 4 KV SWGR 2A2 or 2B2

1. Any other trip of a 4 KV Start-Up transformer breaker will only affect its associated bus resulting in actuation of protection features of the systems supplied.

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2. A loss of a 4 KV bus (section 5.2.3.A only) will start one or both diesel generators and initiate load shedding of the appropriate bus (es), close in the

  ,j                                                     diesel (s) to their bus (es) and selectively load the
    .;                                                   diesel (s).

5.2.4 Operator Actions: rI A. If any automatic action has not occurred, the operator .. should manually execute the required steps. B. Determine the cause of the trip from section 5.2.2 and take necessary steps to correct. C. Notify the load dispatcher of the plant conditions. J' 5.3 Bus Differential Lockout of 6.9 KV 2A1 (231) or 4 KV SWGR 2A2 (2B2) 5.3.1 Indications - the following are some of the indications that will accompany a lockout of the 6.9 KV or 4 KV SWGR: A. loss of power to the associated bus.

       .                                   B.        Various alarms from section 4.0.
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Pago 5 of 8 ST. LUCIE UNIT NO. 2 ( r 3 0FF-NORMAL OPERATING PROCEDURE NO. 2-0910030, REVISION 0 d ,j I START-UP TRANSFORMER OFF-NORMAL OPERATION f

5.0 Instructions

(continued ) 5.3 (continued) 5.3.2 Causes - a lockout of the 6.9 KV 2A1 (2B1) or 4 KV 2A2 (232)

                 .                         SWGR is caused by a fault on the bus.

5.3.3 Automatic Actions: A. The differential also causes the Start-Up and auxiliary transformer breakers to open on the associated bus. In addition, breakers to the 480 VAC Load Center 2A1 (2B1) and 4 KV SWGR 2A3 (2B3) are opened. 5.3.4 Operator Actions: A. If any automatic action has not occurred, the operator should manually execute the required steps. B. Determine the cause of the lockout from section 5.3.2 and take necessary actions to correct. g C. Notify the load dispatcher of the plant .:onditions . D. Check the status of other systems J5upplied by these switchgear and insure any required onyttions are performed. 5.4 Transformer Fire: 5.4.1 Indications - the following are some of the indications that could accompany a transformer fire: A. Possible loss of power to associated buses. B. Various alarms from sedtion 4.0. 5.4.2 Causes for a transformer fire are numerous; a few are: A. Shorts

       ,                                  B. Grounds C. Oil leak D. Cooling equipment failure a_

'. 5.4.3 Automatic Actions: L*. A. If a loss of power and/or lockout have occurred, see the appropriate section. 5.4.4 Operator Actions: [ A. Sound fire alarm. {^ l E. Notify plant personnel over the page systen of the nature i and location of the fire. l C. Insure fire pumps are running. D. Insure transformer deluge system is operating. i I l d

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Pcge 6 of 8 l ST. LUCIE UNIT NO. 2 0FF-NORMAL OPERATING PROCEDURE NO. 2-0910030, REVISION 0 l h START-UP TRANSFORMER OFF-NORMAL OPERATION #

5.0 Instructions

(continued) 5.4 (continued) 1 5.4.4 (continued) E. Start diesel generator on affected side (s). F. Trip Start-Up transformer breakers to 6.9 KV and 4 KV switchgear on affected side. G. Open switchyard OCB's to bus supplying affected transformer. H. Open af fected transformer "J" switch. I. Ensure diesel generator (s) is/are loaded carrying vital

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buses. J. Notify local fire department. K. Nctify load dispatcher of plant conditions. L. Determine if fire is internal or external to the transformer or both, if possible. M. Open power to transformer cooling equipment. 5.5 Lockout Relay Failure: 5.5.1 Indications - audible alarm in Control Room.

         ,             5.5.2     Causes - may be one of the following:

A. Blown fust. B. Open relay 5.5.3 Automatic Actions:

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NONE jf 5.5.4 Operator Actions: j'j lt A. Replace fuses as necessary. 'f B. Notify maintenance supervisor if relays are inoperative. e4 5.6 6.9 KV or 4 KV Ground 5.6.1 Indications - Audible alarm in Control Room. 5.6.2 Causes - one or more of the following:

      ,-                         A. Grounded 4 KV winding on the Start-Up transformer.
;                                B. Grounded 6.9 KV winding on the Start-Up transformer.

5.6.3 Automatic Actions: NONE

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            .                                                                                  Pago 7 of 8 r                                                                                                                    /"N I

ST. LUCIE UNIT NO. 2 [ ,

0FF-NORMAL OPERATING PROCEDURE NO. 2-0910030, REVISION O l"!j START-UP TRANSFORMER OFF-NORMAL OPERATION

5.0 Instructions

(continued) 5.6 (continued) 5.6.4 Operator Actions: A. Start diesel generator (s) on affected side. B. If time allows, synchronize the diesel generator with the vital bus and supply the vital bus with the diesel generator. C. Isolate the affected transformer. D. Determine the cause of the ground. E. Notify the load dispatcher of plant conditions. 5.7 Transformer Alara Panel Malfunction 5.7.1 Indications - audible alarm in Control Room. 5.7.2 Causes - listed in section 5.7.4 5.7.3 Automatic Actions: A. Fault pressure operates the transformer lockout (section 5.1). All other features do not cause initiation of automatic protective features.

                        ,5.7.4 Operator Actions:

A. Investigation of the alarm to determine the cause and correction as necessary of the following conditions:

1. Ioss of 125 V DC transformer alars power - check the f4 DC supply breaker and bus voltage.

b) 2. Pressure relief device - isolate the transformer as

 ;;;.;                                   per section 5.6.4
    ;,                               3. Iow oil flow - check oil flow gauge and pump
    ;-                                   operation.

4 Atmoseal tank low oil level - inspect liquid level gauge mounted on transformer. If level is low, reduce load on transformer and inspect for leaks. If any oil leaks are found, isolate the transformer per section 5.6.4 Top oil temperature (90'C) or thermal relay (hot 5. spot) (1200 C) - Shift fans and pump to manual. If alars persists, isolate the transformer per section 3.6.4

6. Cas Detector - isolate the transformer as per section 5.6.4 I

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Page 8 of 8 ST. LUCIE UNIT NO. 2 . OFF-NORMAL OPERATING PROCEDURE NO. 2-0910030, REVISION O g START-UP TRANSFORMER OFF-NORMAL OPERATION l 5.0 Instructions 5.7 (continued) 5.7.4 (continued) A. (continued)

7. Loss of cooling power (a) Check circuit breakers to pump and fans ON (b) Check circuit breaker to fans ON (c) Insure 480 V AC nor:nal and/or alternate power is available and supplying the ccoling equipment.

(d) If fans and pump cannot be re-started , reduce transformer load. If high temperature alarm is reached, isolate the transformer per section 5.6.4.

8. loss of Control power (a) Check fans and pump (b) Check control circuit breaker ON.

(c) Check control fuse, replace if necessary. (d) If f ans and pump cannot be re-started, reduce transformer load. If high temperature alarm is reached, isolate transformer per section 5.6.4.

9. Loss of Source #1 or Source #2 and/or transfer to i standby po.Ner - check controls, f ans, and pump operating. Then check 480 V MCC breakers:

S/U Transformer 2A - Preferred Supply MCC 2A1 BER 2-40857 Standby Supply MCC 2B1 BKR 2-41654 S/U Transformer 2B - Preferred Supply MCC 2B1 BKR 2-41651 Standby Supply M;C 2A1 BKR 2-40858 NOTE: 2A is alternate (source #2) for transformer 2B and 2B is alternate for transformer 2A. 4 e m. 4 l l

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6 1 4 FLORIDA POWER & LIGHT COMPANY ST. LUCIE UNIT 2 6 EMERGENCY PROCEDURE NUMBER 2-0030140 REVISION 3 BIACROUT OPERATION (E)

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Pcgs 2 af 14 7 I b p ' FLORIDA POWER & LIGHT COMPANY l ST. LUCIE UNIT 2 3 EMERGENCY PROCEDURE NUMBER 2-0030140 REVISION 3 [ f

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 SYMFr0MS

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. AITr0MATIC ACTION INITIATING EVENT 3.1 Reactor Trip 3.1 RCS Low Flow 195% 3.2 Turbine Trip 3.2 Reactor trip bus low voltage 3 3.3 Generator lock-out 3.3 Turbine trip /Bkrs closed 4 3.4 Generator breakers open 3.4 Turbine Trip *S 3.5 Incoming feeder 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 232 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 non-essential sections of 480V MCCs emergency 480V MCCs open l

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Paga 3 of 14 ST. LUCIE UNIT 2 B9. g

h . l EMERGENCY PROCEDURE NUM3ER 2-0030140, REVISION 3 ; I" h l BLACKOUT OPERATION "[ l 4 3.0 IMMEDIATE AUTOMATIC ACTION: (Cont.) AUTOHATIC ACTION INITIATING EVENT f l 3.8 Breakers open for the following 3.8 Diesel load shedding sequence non-safety related loads which are normally fed froct emergency buses NOTE: These loads can be manually reconnected to the emergency buses as needed. CEDM MG Sets 2A and 23 Reactor cavity sump pump 2A and 2B Containment building elevator Electrical equipment room hoist 120/208 Power Panel 121 transformer Lighting panel transformers 110, 112, 114, 117, 125, 126 Incoming feeder from 2A2 and 2B2 4160V buses RCP oil lift pumps (B pumps only - A pumps running) Pressurizer relief isol valves (1476 and 1477) 480V Lighting panel 2A, 23 and 2C (required at night for security) Waste management heat tracing transformers 2A and 2B Air conditioner HVA-4, ACC-4

     .           Power panel 120 Lighting panels 113, 116, 109, 115, 130 g            Refueling equipment

? .

s Refueling water to charging pumps (V-2504) Boric Acid batching tank heaters Fire siren NOTE: Thumb rule: Starting KVA = 6 x HP rating.

                                                   *** CAUTION ***

These loads could create overload conditions if proper care is not taken to ensure there is adequate margin on the D/G for them. It should be l determined there is sufficient starting KVA available prior to energizing these loads, then only energize one at a time and re-evaluate the D/G load. I l

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ST. LUCIE JNIT 2 EMERGENCY PROCEDURE NUMBER 2-0030140, REVISION 3 l O BLACKOUT OPERATION Y 3.0 IMMEDIATE AUTOMATIC ACTION: (Cont.) AUTCHATIC ACTION INITIATING EVENT l 3.9 All loads on e:nergency buses 3.9 Diesel load shedding sequence 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 2B Diesel Generators 3.10 Undervoltage on 2A3 and 233 start and energize 4160V 4160V buses e:sergency buses 2A3, 233, 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, Energency Diesel Generator Loading Sequence) . 3.12 Auxiliary Feedwater auto start 3.12 2A or 2B Steam Generator initiates level decreases to 20.6%

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Pega 5 of 14 Bo ST. LUCIE UNIT 2 EMERGENCY PROCEDURE NUMBER 2-0030140, REVISION 3 ; BLACK 0tTT OPERATION !9 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 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 buses 4.7 Open Startup Transformer 4.7 RTGB-201 breakers 4.8 to reference 4.8 RTGB-203 Reduce setpoint T*h manual operation i of the steam dump valves to atmosphere 4.9 Isolate Steam Generator 4.9 RTGB-206 blowdown 4.10 Verify 2C steaa-driven AFW 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 drit en pumps may be secured, if desired i l

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Ptga 6 of 14 ST. LUCIE UNIT 2 EMERGENCY PROCEDURE NUMBER 2-0030140, REVISION 3 BLACK 0tTr OPERATION y ; y, , j Y 5.0 SUBSEOUEYr ACTIONS: 5.1 Implement the Emergency Plan as necessary in accordance with I EPIP 3100021E, " Duties of the Energency 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 g T should be

                      <49'F (&T for full power).

1. If the above conditions are not established:

A. Check RCS temperature and pressure to ensure that the RCS is l I,' subcooled. B. Ensure AFW flow to the Steam Generators has been initiated and the steam dumps to atmosphere are in operation. C. Refer to EOP 2-0120043, " Inadequate Core Cooling".. j

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.

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 trip ped.

3. If the overspeed trip levers are latched, the Normal / Isolate i

switches on the local control p'anel 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-10-1B). Locally close MSR main steam block valves (MV-08-4, MV-08-6, MV-08-8, and MV-08-10). l 5.6 Check MSR warm-up valves (MV-08-5, MV-08-7, MV-08-9, and MV-08-11) to be closed or close manually. l l I

                                                                                           . _ . _ . _ , . , . . ,._,. m

l Pago 7 of 14

B0 ST. LUCIE UNIT 2 - EMERGENCY PROCEDURE NUMBER 2-0030140, REVISION 3 ,. BLACKOUT OPERATION .I {t 5.0 SUBSEQUEYr 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).

CADTION: Do not overload the Diesel Generators when starting additional equipment (3685KW maximum continuous rating).

5.8 When Diesel Generator power is available, energize 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.

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 Priming ejector Auxiliary priming ejector

      ;;                              Auxiliary steam to RAB m                                 Gland seal system 7,                        5.10 Start 2A and 25 CEDM cooling fans.

l 5.11 Start 2A and 2B 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). e G

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Ptge 8 of 14 ST. LUCIE UNIT 2 EMERGENCY PROCEDURE NUMBER 2-0030140, REVISION 3 g' BLACKOUT OPERA

TON

                                                                                                                            ,a 5.0 SUBSEQUENT ACPIONS: (Cont.)

5.12 Manually close breakers for Preasurizer heater buses on 4160V buses 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 011 Lift Pump starts automatically when Turbina speed decreases to approximately 600 rpm. 5.14 Start oil reservoir vapor extractor and generator oil vapor extractor. 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 che turbine lube oil and the air side and hydrogen side oil coolers between 95 - 100oF. 4 .; 5.17 Isolate cooling water supply to the Generator hydrogen coolers. M 5.18 If additional Condensate Storage Tank water is required, have

_ ~_ Unit 1 personnel place the Water Treatment Plant in service.

M.j .

 -Q                               5.19 Place et.e 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 1                                                   five hours without cooling before reaching the boiling
     ;                                                point.

E j'.' ,1 , 5.20 Periodically check fuel oil levels in the Diesel Generator day tanks to confirm proper operation of the fuel oil transfer system l? 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. l 1

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l l Ptga 9 of 14 ST. LUCIE UNIT 2 EMERGENCY PROCEDURE NUMBER 2-0030140, REVISION 3 4 - BLACKOUT OPERATION l 5.0 SUBSEQUENT ACTIONS: (Cont.) 5.23 If the outage will exceed four hours and the R'iT is available, proceed to Cold Shutdown conditions utilizing natural circulation, f J L atmospheric steam dump and feedwater addition. Refer to EOF 2-0120040, " Natural Circulation /Cooldown". Place Shutdown

Cooling in service when appropriate temperatures and pressures are reached. NOTE: Do not begin plant cooldown until Cold Shutdown baron 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.

3. Place the switch for either Power Operated Relief Valve (V-1474 or V-1475) in the OFF position and vent the Pressurizer to the Quench Tank. Return the switch to OVERRIDE to close valve.

4 Control the rate of cooldown and depressurization by selective operation of the Power Operated Relief Valves in this mode until cooldown via the auxiliary spray valves can be initiated.

          }               5.25 When normal AC power is available:
        .j                           1. Restore bus sections to their normal supplies.

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

3. Restore all plant systems to normal.

    ~ ~'

6.0 DISCUSSION

1 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 acuatate to augment the steam flow and to help control Steam Generator pressure immediately after the trip. 1

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           .                                                                          Pag 2 10 of 14 B0 ST. LUCIE UNIT 2 EMERGENCY PROCEDURE NUMBER 2-0030140, REVISION 3                    ,       t BLACKOUT OPERATION                                 g fl

6.0 DISCUSSION

(Cont.) 6.3 On-site power will be supplied by the Emergency Diesel Generators. L J 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 af ter nor:nal feedwater flow stops. Auxiliary feedwater flow will automatically initiate after the first Steam Generator level reaches 20.6% (2/4 logic). 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 loss of power condition since the Steam Generators are maAntained as a heat sink and RCS pressure and inventory control are available. 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 emergercy loads vill be automatically started. 1 9 e 4 5 1

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1 Page 1I of 14 ST. LUCIE UNIT 2 EMERCENCY OPERATING PROCEDURE 2-0030140, REVISION 3 BLACK 0!JT OPERATION TABLE 1 s DIESEL CENERATOR LOA 1)ING SEQIIENCE RIDNitM IIMD (KW)

    !                                                 Ihr         Nominal                                              tirA
    !                                                Diesel       Inal or                        blaclom With    (Recirmlation)           hin Steam Lirm Autoastic Startirg                   Generator heplate Startlig Tiining             Ims of WP-     With Ims of GY-         Break With loss of
    ;  TDM       Egidpnert (4)                     Omutity             IF       KVA     Sagenm Site Ihr (IM)     Site Ibwer (Ill0P)     Offsite ihr (IJYF)
    }

1 High Pressure Safety Iq). l\mp 1 400 2422.0 0 Sec. - 324 324

 ')      2 titor Operatal Valves                      tot           -             -

0 Sec. 6.7 27.2 33.1 3 En:ripney Lightirg lot - - 0 Sec. 125 125 125 4 the Panels lot - - 0 Sec. 195 195 195 { 5 Diesel 011 'Dransfer lisaps 1 3 21.5 0 Sec. 3 3 3 6 BCP Oil Lift lisaps 4 10 66.85 0 Sec. 40 20 20 l 7 thintermptible Ihr Supply 1 0 Sec. 55 55 55

    ;    8 If/AC Dmagers                              tot           -             -

0 Sec. 4 4 4 1 4 9 HVAC Valvm Iot - - 0 Sec. 1.5 1.5 1.5 f 10 low Presure Safety Inj. lisap I 400 2183.3 3 Sec. 274 321 274 l 11 Omtainent Fan Ox>1ers 2 125/83 828.4 3 Sec. 134 % % i 12 Elec. Eqtdp. Moon Supply 1 100 584.12 3 Sec. 95 95 95 13 Camponent Ox>1ing unter 1 450 2491.2 6 Sec. 351 351 351 14 Shield Buildi:q Exluaist 1 60 340.6 6 Sec. - 40.2 40.2 j 15 sitehl Buildirg thatern lot - - 6 Sec. -

                                                                                                              ,         31.5                    31.5          ,
]       16 Intae Qx)11rg Water Puip                    1           600        3709.0      9 Sec. 453              453                      453 Qlb 53 y
,I .                                        .

t.. . Page 12 of 14 i ST. LUCIE UNIT 2 j EMERGENCY OPERATING PROCEDURE 2-0030140, REVISION 3 ISLACK0lTr OPERATION

    '                                                                                  TABLE I L
    !                                                               DIESEL CENERATOR LOADING SEQUENCE I

4 lufNIfC IIMD (nJ) ihr 14aminal III%

   }                                                       Diesel    lost or                        htdom With        (Rectrollation)       tialn Steas Line ij               Autauntic Startieg                  Generator Newplate Startirg Timirg           loss of WP-      With Ima of WP-      Break With Ims of TnH       Fepdpert (4)                      Qtentity         IF        KVA     Sequence Site ther (ll10P) Site Ibwer (if0P)   QUd ite Itxa'r (IIl0P) 17 Qintairmat Sgray lisap                       1         SCO       2892.6     12 Sir.      -

405 405 18 ltydrazine lisap 1 3 21.5 12 Sec. - 1 1 19 kactor Supports On11rg 1 40 234.76 18 Sec. 22 - - 20 14eactor Cavity Supply Fan 1 20 124.15 18 Sec. 15 - -

    )        21 Intake Ikiildirg Onlirg Fan                  1         7.5         44.0     21 Sec.        7.5                7.13                   7.5
 ]           22 Battery Rxas Itoof Ventilator 2-RV-1         1        0.75          8.5     21 Sec.          .75                .75                    .75 5         23 Elec. Equip. Iloon Ibdisust, 2-RV-3          1           5         34.22    21 Sec.        5                  5                      5 1

24 IKXS Area Exluasst Fan 1 60 358 24 Sec. 45 45 45 25 Omtml Rxmi ihr. Filter Fan i 10 62.0 24 Sec. - 10 10 g 26 Qxitrol Iban Air Qxditioniss 2 55 - 24 Sec. 68 68 68 27 Boric Acid hat Trace lot lot - 27 Sec. 30 30 30 28 Battery Ovirger 1 6mW - 27 Sec. 60 60 60 29 Auxiliary Feedwater limp 1 350 1951.4 30 Sec. 255 255 255 q ,

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Page 13 of 14 yl l) }, ST. LUCIE UNIT 2 J EMERGENCY OPERATING PROCEDURE 2-0030140, REVISION 3 / T HLACKDUT OPERATION TABLE I DIESEL CENERATOR I.OADING SEQllENCE I

#(

RIPNIPC IDAD (KW) Ihr thatnal IDCA Diesel Iswal or Sutdown With (Reciraalation) thin Steas Line Automatic Startirg Grwrator Nameplate Startity Tijairg Ima of WP- With Ima of GV- Break With Ims of T11H Egidpast ()nntity IF KVA Salience Site Ihr (IDDP) Site lwr (InP) Offsite Ihr (IDDP) 30 RAB Supply Fan 1 150 900.1 33 Sec. 111 111 111 31 Elec. Equip. Iban Exhamt, 241VE-11 1 50 244.7 3tl Sec. 3fl 38 38 32 Ourgits Raupe 2 125 16 % .8 5 Min. 60 60 60 33 Boric Acid Makeup Ramp (2) 2 25 124.1 5 Min. 24 24 24

     ,      M     Isutnsnent Air Camprema>r             ,1           60       340.6    Muual loa!         60              60                  60 35    Re1 Ibol moliig Ramp                    I          40       234.6    hant loal          26              -

26 36 Hydroepn it.w=hiner 1 75W - Muual loal - 75 75 37 Pressurimer Ikaters 1 20*W - h ani loal 200 - - (after 2 hours IDOP) i i lbtes: (1) Actustal on RAS (2) Both Boric Acid Mdeup Ihaps are loslal orto Diesel Cenerator A a 3 s e I

I Piga 14 o ST. LUCIE UNIT 2 .h, EMERGENCY OPERATING PROCEDURE NO. 2-0030140, REVISION 3 ' t BLACK 0tTP OPERATION

7.0 REFERENCES

1 7.1 St. Lucie Unit 2 FSAR, Sections 8 and 15 7.2 Off-Nor.nal 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 Operation" 7.5 Of f-Normal OP 2-0250031, " Boron Concentration Control, Off-Nor:nal" 7.6 Off-Normal OP 2-1010040, " Loss of Instrument 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, "Coinponent Cycles and Transients"

9.0 APPROVAL

Reviewed by Facility Review Group October 26 1982 Approved by J. H. Barrow ( for) _ Plant Manager October 26 1982 Revision 3 Reviewed FRG f/719 8J

    >U         Approved by                           rfAA A blant Manager                         f /[ 19 / 3 u
                                                        "LAST PAGE" t

i i EP 2-0030140 l~ Rev. 3 Total No. of Pages 14

l l

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Page 1 of 42 EMERGENCY PROCEDURE 2-0030141 Rev. 3 CRI 1 l i i

d' FLORIDA POWER & LIGHT COMPANY -w ST. LUCIE UNIT 2 < ". EMERGENCY OPERATING PROCEDURE 2-0030141

                                                                                                                                                                                'Y " "'"'"

REVISION 3 i l i + l l CONTROL ROOM INACCESSIBILITY (CRI) r J j n,r , .) g- :: . ~ c TOTAL NO. OF PAGES 42 r . l F0l1 INFORMATION ONLY 15 coce M9f is not controffed, gefore use verify i.SfCrmafien with a Controlled document.

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l l ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE 2-0030141 REVISION 3 1

1.0 TITLE

CONTROL ROOM INACCESSIBILITY

2.0 SYMPTOMS

Conditions exit.t such that the Control koom becomes uninhabitable and must be evacuated. 3.0 IMMEDIATE AUTOMATIC ACTION: None 4.0 IMMEDIATE OPERATOR ACTION: ACTION NOTES 4.1 Manually trip the reactor and 4.1 Push buttons on RTGB-201 Turbine prior to leaving the and 204 /R3 Control Room, if possible. 4.2 Announce evacuation of the Control Room over the P.A. system. 4.3 Implement the Emergency Plan, as necessary, in accordance

         .                      with EPIP 3100021E, " Duties e'                         of the Emergency Coordinator".

w 4.4 Obtain the Remote Shutdown Room 4.4 Key dumber 130 /R3

       ;                        Keybox Master Key from the

' [( Control Room Key Locker.

 =.i; 4.5 Evacuate all personnel from the Control Room.

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ST. LUCIE UNIT 2 i EMERGENCY OPERATING PROCEDURE NUMBER 2-0030141, REVISION 3 - ' CONTROL ROOM INACCESSIBILITY 5.0 SUBSEQUENT ACTIONS: _ 5.1 Man and take control of stations as follows: CHELA

1. Reactor Control Operator "A" - Remote Shutdown Panel.

A. Establish communications on the Sound Power Phone System. B. Monitor available plant parameters on the Remote Shutdown Panel. C. Start motor or steam-driven Auxiliary Feedwater Pumps and feed the Steam Generators as required. D. Control Pressurizer pressure and level by manual control of Pressurizer heaters, auxiliary spray valves, and letdown valves. NOTE: Only the "P" Letdown level and pressure valves are controllable from the Remote Shutdown Panel.

2. Nuclear Plant Supervisor - Electrical Equipment Room, Reactor Auxiliary Building - 43' Elev.

A. Open or check open Reactor Trip Breakers TCB-1 through 8. B. Place isolation switches in the ISOLATE position on the following switchgear in the order listed: (See Appendix A). 480V Load Center 2A3 480V Load Center 2B3 480V Lead Center 2A2 4160V SWGR 2A3

    ^)                               480V MCC 2A5 480V MCC 2A6 G

480V Load Center 2B2 4160V SWGR 2B3 r-480V MCC 2B6 480V MCC 2B5 480V MCC 2AB Isolation Panel 2AB Isolation Panel 2A Isolation Panel 2B Communications Isolation Panel gh 4 - ,pye .-sur- 4 m *-N se # 614sM$ N #94p g'*

            .                                                                 Pcga 4 of 42 CRI ST. LUCIE UNIT 2 e       g EMERGENCY OPERATING PROCEDURE NUMBER 2-0030141, REVISION 3 CONTROL ROOM INACCESSIBILITY                               ]1           g 5.0 SUBSEQUENT ACTIONS: (continued)

I . 5.1 (continued) w -===

2. (continued) CHECK C. Assist Reactor Control Operator "A" in monitoring unit parameters from the Remote Shutdown Panel.

D. Open or check open: 480V Load Center 2A3 P-1 HTR Feed 2-40305 480V Load Center 2B3 P-2 RTR Feed 2-40602

3. Reactor Control Operator "B" - Turbine Operating Level.

A. Locally trip or verify tripped Unic No. 2 Turbine. B. Verify Turbine Stop Valves and Control Valves are shut; if not, initiate Turbine trip from Turbine front standard. C. At the AFW Pump area, place the isolate switches fo r MV-08-19B , MV-08-18B , MV-08-18A, and MV-08-19A in ISOLATE. D. Proceed to Turbine Building Switchgear Room and establish communications on the Sound Powered Phone circuit. E. Place isolation switches in the ISOLATE position for bus feeder breakers as follows (See Appendix A): 4160V SWGR 2A2 4160V SWGR 2B2 6900V SWGR 2A1 6900V SWGR 2B1

   , '~;'

F. Stop 2A and 23 Main Feedwater Pumps, 2A and 2B Heater Drain Pumps, and one Condensate Pump by opening their respective breakers. CAUTION: Ensure that one Condensate Pump remains in service. 1

4. Nuclear Operator - Reactor Auxiliary Building. )

A. Place isolate switches in ISOLATE / LOCAL position on the following switchgear (see Appendix A): 4160V SWGR 2A3 480V Load Center 2AB B. Proceed to the Diesel Generator Building and place isolation switches on 2A and 2B Diesel Control Panels in ISOLATE position (See Appendix A).

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P:ga 5 of 42 i ST. LUCIE UNIT 2 I EMERGENCY OPERATING PROCEDURE NUMBER 2-0030141, REVISION 3 ' 9 CONTROL ROOM INACCESSIBILITY . m-m 5.0 INTTRUCTIONS : (continued) 5.1 (continued)

4. (continued)

CHECK C. Open or check open isolation valves for Letdown pressure and level control valves (V-2110P and V-2201P). Isolate V-2110Q and V-2201Q. D. Proceed to the Charging Pump area and establish communications on the Sound Powered Phone circuit. ____ 5.2 Maintain Pressurizer level at approximately 33% indicated level. ___ 5.3 Maintain Pressurizer pressure at approximately 2100 psia. 5.4 Maintain Reactor Coolant System teuperature at or below 532*F (2A cold leg temperature) by use of atmospheric steam dump and/or selective shutdown of Reactor Coolant Pumps. NOTE: Stop Reactor Coolant Pumps as required by opening the Reactor Coolant Pump breakers in the Turbine Building Switchgear Room. 5.5 Maintain Steam Generator levels at approximately 65% indicated level by operation of the Auxiliary Feedwater Pumps and discharge valves to the Steam Generators. 5.6 Isolate Steam Generator blowdown by manually closing isolation valves at the Closed Blowdown Heat Exchangers. 5.7 When Turbine speed decreases to "0" RPM, verify that the Turning Gear Oil Pump and the turning gear are in operation

    .        5.8  Periodically check the habitability of the Control Room and when conditions permit, reoccupy the Control                                              l Room. Return isolation switches to NORMAL for switches and controls that are operational and maintain the Unit at Hot Standby until a complete evaluation has been made.

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Pega 6 of 42 ST. LUCIE UNIT 2 f, T EMERGENCY OPERATING PROCEDURE NUMBER 2-0030141, REVISION 3 g CONTROL ROOM INACCESSIBILITY { w y

5.0 INSTRUCTIONS

(continued) CHECK . 5.9 If Control Room accessibility is not possible, place the unit in a Cold Shutdown condition as follows:

1. Commence boration to Cold Shutdown conditions by manual valve lineup. Borate to 1900 ppm as shown below.

Carry out boron sampling as required during cooldown. /R3 NOTE: This concentration will ensure >5% Shutdown Margin at 201*F at any time in core life, assuming the most teactive CEA stuck full out. Use both the local boron flow meters vs. time and BAM Tank level change to decenaine how many gallons of boron have been added. Do not interpolate values shown, always round critical boron concentration DOWN to next lower value on table. NOTE: If plant curves are available, they may be used to determine shutdown boron concentration requirements instead of this Table. Boron Concentration Number of Gallons BAM Tank Prior to Control of Boron needed level change Room Inaccessibility to reach 1900 ppm (1 BAM Tank) l 50 PPM l 7223 Gal l 75% l l 100 PPM l 7039 Gal l 73% l l 200 ?PM i 6668 Gal ! 70% l l 300 PPM l 6295 Gal I 66% l l 400 PPM ! 5919 Gal I 62% l j ; l 500 PPM I 5442 Gal l 57% l

.)

i3 l 600 PPM l 5162 Cal I 54% l .

^ ?! l 700 PPM l 4779 Cal I 50% l 4395 Gal

 .x l 800 PPM                 i                    I           46%          l l 900 PPM                 l         4008 Cal   l           42%          l l1000 PPM                 i         3618 Gal    l          38%          l y                      l 1100 PPM                l         3226 Gal   I           34%          l l1200 PPM                 l         2832 Gal    I          30%          l l 1300 PPM                l         2435 Gal   1           25%          I l 1400 PPM                i         2036 Gal    l          21%          l l 1500 PPM                l          1634 Gal  l           17%          l

2. Ensure Steam Generator level is being maintained at approximately 65% by the Auxiliary Feedwater Pumps.

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                         ,                                                                    Ptga 7 of 42          l ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE NUMBER 2-0030141, REVISION 3                        l CONTROL ROOM INACCESSIBILITY                               }*     l

5.0 INSTRUCTIONS

(continued) 5.9 (continued) CHECK

3. Stop at least one Reactor Coolant Pump prior to reaching 500*F by tripping its breaker at the 2A1 or 231 switchgear. Additional RCPs may be stopped as desired to control cooldown rate. After pump coastdown, stop the lif t pumps by opening the associated breakers in the electrical switchgear room. Re-close lif t pump breakers af ter one minute elapses.

4. Place all Pressurizer heater switches at the Remote Shutdown Panel to 0FF. Heaters may be energized to control RCS pressure as needed.

~

        .                             5. The highest RCS cold leg temperature (highest one with RCP running) shall be plotted every 30 minutes. The copy of the graph (Figure 1) shall be kept with this procedure. The RCS temperature and pressure shall be decerained to be within the limits of Figure 3.4-3 at least once per 30 minutes during cooldown.

NOTE: Cooldown of the RCS shall be limited to 1 750F in any one hour period with RCS temperature >97 0F. /R3

6. The Pressurizer water phase temperature shall be plotted every 30 minutes using the Saturated Temperature vs. Pressure curve of this procedure 1 (Figure 2). If possible, maximize letdown and

       .,                                 minimize charging when using auxiliary spray to

[ s, 1 minimize thermal stress on spray nozzle. l' NOTE: Cooldown of the Pressurizer shall be

      .                                            limited to < 190*F in any one hour period.

9 7 When the quanity of boron calculated in Step 5.9.1

   ,M has been added. cooldown may proceed. Verify by
        }                             chemistry sample (if possible) that desired boron concentration has been obtained. Commence taking p                                data on cooldown curve. Have the "B" Reactor Control Operator break Condenser vacuum by manually opening vacuum breaker MOVs.

CAUTION: MSIS will occur at about 475'F, and sealing steam will be lost. Condenser vacuum must be broken prior to 475'F to prevent seal damage. l [.

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Pega 8 of 42 ST. LUCIE UNIT 2 g EMERGENCY OPERATING PROCEDURE NUM3ER 2-0030141, REVISION 3 i i CONTROL ROOM INACCESSIBILITY =--- f

5.0 INTERUCTIONS

(continued) 5.9 (continued) ] CHECK

8. Rave I & C personnel install temporary VCT level monitoring equipment. While locally monitoring and controlling VCT level, slowly open the atmospheric steam dumps and establish the desired cooldown rate.

NOTE: A makeup blend ratio to the VCT of about 9:1 is sufficient to maintain 1900 PPM boron in the RCS. NOTE: A temperature dif ferential of approximately 100 F between the RCS and Pressurizer should be maintained during cooldown. Cooldown of the Pressurizer must be accomplished by use of auxiliary spray and heater control.

9. When the SIAS amber permissive lights come on (1836 psia), block SIAS by turning the key operated switch on the Remote Shutdown Panel for both A and B channels. /R3

10. At 1750 psia, isolate and bypass the following transmitters:

A. Charging header flow: close valve marked "HIGH SIDE", open valve marked " BYPASS", and close valve marked " LOW SIDE". B. Charging header pressure: close its isolation valve. /R3

11. Commence venting all four SITS from remote valve stations in the Electrical Penetration Room.

10: (valves 3733, 3734, 3735, 3736, 3737, 3738, 3739 and 3740). r , ;. . NOTE: Do not vent more than one SIT to <235 psig. /R3 4; 12. Maintain at least two Reactor Coolant Pumps operating. If possible, two RCPS in the same loop should be left running. I

13. Periodically adjust the steam dump controllers and auxiliary spray control to maintain the desired cooldown and de pressurization rate. Verify that the Steam Generators are being maintained at

 '-                                               approximately 65% level.

14. With RCS pressure < 1700 psia, but prior to commencing l , SDC operations, rack out 2A and 23 Containment Spray
Punp breakers (2-20203 and 2-20407).

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                                                     .                                                                                         Paga 9 of 4                l CRI                       l ST. LUCIE UNIT 2                                 g   p EMERGENCY OPERATING PROCEDURE NUMBER 2-0030141, REVISION 3 COWROL ROOM INACCESSIBILITY                                  Ll   j
                                                                                                                                                                 }l

5.0 INSTRUCTIONS

(continued) 5.9 * (continued) CHECK

15. When RCS temperature is < 500*F and RCS pressure is

                                                                      < 1500 psia, perform the following:

A, Close 2-V-07145 and 2-V-07130 (Containment spray pump disch valves) B. Close the following containment spray header manual isolation valves. 2-V-07161 (A hdr FCV upstream isol)

     .                                                                         2-V-07164 (B hdr FCV upstream isol) 2-V-07162 ( A hdr FCV downstream isol) 2-V-07165 (B hdr FCV downstream isol)

16. When RCS pressure is < 275 psia, rack in the breakers for and then close the SIT discharge valves by placing the local control switch in the CLOSE position.

MV-3614: Bkr 2-41219 MV-3624: Bkr 2-41311 MV-3634: Bkr 2-42117 MV-3644: Bkr 2-42048

17. Rack out the SIT discharge valve breakers.

CAUTION: Prior to lowering RCS pressure below (LATER) psia, two RCPs in the same loop must be operating.

18. Lower RCS temperature to 325'F and RCS pressure to 275 psia. '

      'i                                                        19. Rack out one HPSI Pump prior to 280 F.                0 Ensure the other HPSI pump remains operable.

CAUTION: With SDC in service, an increase in RCS pressure > 350 psia will result in rapid RCS inventory loss due to lifting of relief valves in Hot Leg suction lines

     -                                                                                      (Total capacity 4,600 gpm).

NOTE: Minimum pressure for RCP operatiot. is (LATER), so it is necessary to proceed quickly to Shutdown Cooling.

20. Stop the operating RCPs prior to lowering pressure to (LATER) by tripping the breakers on 2A1 and 2B1 switchgear. After pump coastdown, stop the oil lif t pumps by opening the breaker for each pump for 1 minute, then re-closing the breaker.

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l l Pega 10 of 42 ST. LUCIE UNIT 2 k ' EMERGENCY OPERATING PROCEDURE NUMBER 2-0030141, REVISION 3 CONTROL ROOM INACCESSIBILITY f

5.0 INSTRUCTIONS

(continued) 5.9 (continued) CHECK

21. Reduce RCS pressure to < 275 psia, then open the following valves from their local controllers:

A. Hot Leg Suction Valves: V-3651, V-3652, V-3665, V-3480, V-3481, V-3664 NOTE: V-3664 and V-3665 local controllers are in Pipe Penetration Room, all others are in the Cable Spreading Room. NOTE: V-3545 (Hot Leg Suction Cross-Tie) is normally closed. It may be used to provide flow during off-normal conditions and cust be open if both trains of SDC are in service. /R3 B. Open CCW from SDC Heat Exchangers: HCV-14-3A and HCV-14-3B by isolating instrument air to the HVC's and bleeding off air pressure. C. SDC Heat Exchanger Discharge Valves: MV-3456 and MV-3457. D. LPSI Header Isolation Valves: MV-3615, MV-3625, MV-3635 and MV-3645.

22. Close the following valves:

A. RWT recirculation stop valves: V-3459, V-3463, and V-3597. B. Miniflow header stop valves: V-3659, V-3660, V-3495 and V-3496. C. v-3432 and V-3444 LPSI suction from RWT. /R3

23. Have the Nuclear Operator establish communications on the Sound Power Phone System in the 2A LPSI Pump Room.

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             .                                                                            Prgs 11 of 42 ST. LUCIE UNIT 2 P

EMERGENCY OPERATING PROCEDURE NUMBER 2-0030141 REVISION 3 CONTROL ROOM INACCESSIBILITY .J 5.0 INSTRUCTIONS : (continued) 1 5.9 (continued) L CRECK

24. Establish SDC as follows:

A. Insert keys for MV-3306 and MV-3657 (controllers located in A LPSI Room) and place switches to MODULATE position. B. Using key switches at local controllers, open MV-3517 and MV-3658. C. Give MV-3306 a 3 second open signal, then allow switch to return to NORMAL. D. Start the 2A LPSI Pump, then open MV-3306 to obtain 3000 gpm flow as indicated on FI-3306 at the Remote Shutdown Panel. E. While observing SDC outlet temperature and flow on the Remote Shutdown Panel, alternately open MV-3657 and close MV-3306 to achieve desired cooldown rate and maintain 3000 gpm.

25. At 200*F RCS temperature, remove the trip and close fuses on the remaining RPSI Pump. Open the breaker for one Charging Pump so that no more than two Charging Pumps are operable.

26. Stabilize RCS temperature at approximately 100 F and RCS pressure at approximately 250 psia. Control pressure by use of Pressurizer heaters and auxiliary spray. Do not take the Pressurizer solid until Control ,

Room access has been re-established.

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Pag 2 12 of

CRI f ST. LUCIE UNIT 2 l r ,

EMERGENCY OPERATING PROCEDURE NUMBER 2-0030141, REVISION 3 CONTROL ROCM INACCESSIBILITY Q' i 1

6.0 PURPOSE & DISCUSSION: 6.1 This procedure provide- instructions for placing the plant in a sai_ 1 condition when operations cannot safely be conducted from the Control Room. 6.2 The reactor and turbine are manually tripped prior to leaving the Control Room, if possible, or locally from the Reactor Trip Switchgear and the Turbine front standard. 6.3 A heat sink is provided by automatic steam dump to the Condenser and/or to atmosphere.

i 6.4 Level is maintained in the Steam Generators by manual control of , auxiliary feedwater valves with flow furnished by the Auxiliary Feedwater Pumps. 6.5 Pressurizer level and pressure are maintained by manual control of Pressurizer heaters, auxiliary spray valves, and letdown valves, and are monitored at the Remote Shutdown Panel. 6.6 Isolation switches located in the Reactor Auxiliary Building Electrical Equipment Room, Turbine Building Switchgear Room, Diesel Generator Rooms, and Reactor Auxiliary Building are manually selected to the ISOLATE position to prevent inadvertant operation of vital equipment due to possible electrical malfunction in the unattended Control Room. 6.7 A copy of this procedure will be posted at each manned operating station required for plant shutdown from outside the Control Room. 6.8 A listing of isolation switches will be posted on each of the following panels, MCCs, and distribution buses.

      )               1. Load Centers _2A, 2B, 2AB u                  2. Isolation Switch Panels 2A, 2B, 2AB
    .[j              3. MCC 2AS, 2A6, 2B5, 2B6 4    4160V Buses 2A3, 2B3, 2AB
  -t.

y 5. 4160V Buses 2A2, 2B2

6. 6900V Buses 2A1, 2B1

 .                   7. Diesel Generator 2A and 2B Control Panels                    .

8. Auxiliary Feedwater Pump Area 6.9 The Nuclear Plant Supervisor will utilize additional personnel as available to assist in required subsequent actions.

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                 .                                                                                                                                                                                      Pcg2 13 of 42 t

ST. LUCIE UNIT 2 CRI 1 [% ' 3 EMERGENCY OPERATING PROCEDURE NUMBER 2-0030141, REVISION 3 6 CONTROL ROOM INACCESSIBILITY b

7.0 REFERENCES

J 7.1 Emergency Operating Procedure #1-0030141. t I 7.2 St. Lucie Unit 2 Technical Specifications.

8.0 RECORDS

8.1 A completed, initialled copy of this procedure shall be racained in the plant file.

9.0 APPROVAL

Reviewed by Facility Review Group: October 26,19g Approved by J. H. Barrow (for) Plant Manager October 26,1981 Revision 3 Reviewed by F R G A 2- 19[> Approved by 88Md__ Plant Manager S 19Q W EP 2-0030141 Rev. 3 Total No. of pages R 4 9'

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                    .                                                                 P:gs 14 of 42 CRI ST. LUCIE UNIT 2 EME EENCY CPERATING PROCEDURE NUMBER 2-0030141 REVISION 3 CONTROL ROOM INACCESSIBILITY APPENDIX         "A" J

ISOLATION SWITCHES 1 l 480V Load Center 2A3 - Pressurizer Heater Bus, Auxiliary Building Electrical Equipment Room

1. Pressurizer Backup Heater Bank B-1

2. Pressurizer Backup Heater Bank B-2

3. Pressurizer Backup Heater Bank B-3

                                                                                                      /R3 i

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Ptga 15 of 42 CRI ST. LUCIE UNIT 2 EMEPSENCY OPERATING PROCEDURE NUMBER 2-0030141, REVISION 3 CONTROL ROOM INACCESSIBILITY l F l w 1 APPENDIX "A" (continued) l ISOLATION SWITCHES l 480V Load Center 2B3 - Pressurizer Heater Bus, Auxiliary Building . Electrical Equipment Room

1. Pressurizer Backup Heater Bank B-4

2. Pressurizer Backup Heater Bank B-5

3. Pressurizer Backup Heater Bank B-6

/R3

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l Page 16 of 42 CRI ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE NLHBER 2-0030141, REVISION 3 +p. i CONTROL ROOM INACCESSIBILITY f i' APPENDIX "A" (continued) IS01ATION SWITCHES l N i h-i 480V Load Center 2A2 - Auxiliary Building Electrical Equipment Room '

l. Station Service Transf 2A2 Main Breaker

2. Bus Tie to 480V L.C. 2AB

3. Containment Fan Cooler 2-HVS-1A 4 Charging Pump 2A

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Pags 17 of ' CRI ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE NUMBER 2-0030141 REVISION 3 ;J O l; ( C0fffROL ROOM INACCESSIBILITY APPENDIX "A" (continued) f ISOLATION SWITCHES 480 V Load Center 2A5 - Auxiliary Building Electrical Equipment Room

1. Containment Fan Cooler 2-HVS-1B 4

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             .                                                                                         CRI ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE NUM3ER 2-0030141, REVISION 3                          []

r m l CONTROL ROOM INACCESSIBILITY APPENDIX "A" (continued)

                                                     , ISOLATION SWITCHES f

4160V SWGR 2A3 - Auxiliary Building Electrical Equipment Room

1. HP Safety Injection Pump No. 2A

2. LP Safety Injection Pump No. 2A

3. Containment Spray Pump No. 2A

4. Pressurizer Heater Transf No. 2A3

5. CEDM Cooling Fan 2HVE-21A

6. Component Cooling Water Pump No. 2A

7. Intake Cooling Water Pump No. 2A

8. Feeder to 4.16KV Bus No. 2AB

9. Feeder from 4.16KV Bus No. 2A2

10. Peed to 480V SS Transformer 2A2/2A5

11. Emergency Diesel Generator No. 2A

12. Auxiliary Feedwater Pump No. 2A

       . -,                                                                                                            /R3 2

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Prga 19 of 42 I

                .                                                                                       CRI                           !

ST. LUCIE UNIT 2 l EMERGENCY OPERATING PROCEDURE NUMBER 2-0030141, REVISION 3 g CONTROL ROOM INACCESSIBILITY 1 . P C , N APPENDIX "A" (continued) ISOLATION SWITCHES

l L 3 480V MCC 2A5 - Auxiliary Building Electrical Equipment Room

1. Makeup Bypass to Charging Pumps V-2514 (Emergency Borate)

2. Aux. F.W. Pump 2A Discharge Valve to S/G 2A (MV-09-9 and I-SE-09-2)

3. S/G #2B to ArdP-2C Turbin MV-08-12

4. Comp Cool Wtr to Cont Cool Unit 2A Valve MV-14-9

5. Comp Cool Wtr from Cont Cool Unit 2A MV-14-10

6. Comp Cool Wtr Cont Cool Unit 2B MV-14-11
7. Coup Cool Wtr from Cont Cool Unit 2P Valve MV-14-12
NOTE: Switch 1, 6 and 7 must be in ISOLATE to have remote control of 2A charging pump.

                                                                                                                               /R3 9
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                          -                                                                                     CRI ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE NUMBER 2-0030141, REVISION 3                                         ,

CONTROL ROOM INACCESSIBILITY ' e ] 6 APPENDIX "A" (continued) ISOLATION SWITCRES 480V MCC 2A6 - Auxiliary Building Electrical Equipment Room

1. Boric Acid Makeup Pump 2A

2. Boric Acid Makeup Pump 2B

3. Control Room Air Cond Unit 2HVA/ACC 3A

  *t 4     Shield Bldg. Vent Exhaust Fan 2HVE-6A

5. Control Room Emerg. Filtration Fan 2HVE-13A

6. Containment Spray Isolation Valve MV-07-161

7. 2A LPSI Pump Suction Valve V-3444

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APPENDIX "A" (continued) ISOLATION SWITCHES .

                                      .                                                                          i            ]

480V Load Center 2B2 - Auxiliary Building Electrical Equipment Room

1. Station Service Transf. 2B-2 Main Breaker

2. Bus Tie to 480V L.C. 2AB

        .                        3. Containment Fan Cooler 2HVS-lC

4. Charging Pump 2B

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h Page 22 of 42 ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE NUMBER 2-0030141, REVISION 3 j

                                                                                                                                              " ) 1 CONTROL ROOM INACCESSIBILITY                                   ,

l APPENDIX "A" (continued) ISOLATION SWITCHES 480V Load Center 2B5 - Auxiliary Building Electrical Equipment Room

1. Containment Fan Cooler 2-HVS-ID.

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                          .                                                                                              CRI ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE NUMBER 2-0030141, REVISION 3                              's CONTROL ROOM INACCESSIBILITY                                  m J

APPENDLT "A" (continued) ISOLATION SWITCHES I 4160V SWCR 2B3 - Auxiliary Building Electrical Equipment Room

1. Emergency Diesel Generator No. 2B

2. Feed to 480V SS Transformer 2B2/2B5

3. Pressurizer Heater Transf No. 2B3 4 Component Cooling Water Pump No. 2B

5. HP Safety Injection Pump No. 2B

6. LP Safety Injection Pump No. 2B

7. Contain:nent Spray Pump No. 2B

8. CEDM Cooling Fan 2HVE-21B

9. Feeder to 4160V Bus No. 2AB

10. Intake Cooling Water Pump No. 2B

11. Incoming Feeder from 4.16KV Bus 2B2 1

l 12. Auxiliary Feedwater Pump No. 23 n. ee; jg3

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            .             1. 2HVE-13B - Control Room Boo, ster Fan f

2. Control Ra Air Cond 2HVA-3B 4

3. Containment Spray Isolation valve (MV-07-164) 4 Shield Bld Vent Exh Fan 2HVE-63

5. 23 LPSI Pump Suction valve (V-3432)

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                                                                                                                    .        1       .

480V MCC 2B5 - Auxiliary Building Electrical Equipment Room "

1. CCW to Containr.ent Fan Cooler 2HVS-1C (MV-14-13)

2. CCW from containment Fan Cooler 2HVS-1D (MV-14-14)

3. Boric Acid Gravity Feed Valve (V-2508)

4. Boric Acid Gravity Feed valve (V-2509)

                *   . 5. CCW to Containment Fan Cooler 2HVS-1D (MV-14-15)

6. CCW from Contairwent Fan Cooler 2HVS-1D (MV-14-16)

7. 23 AFW Pump Discharge to 2B Steam Generator (MV-09-10 and I-SE-09-3)

(Back of MCC 235)

8. 2A Steam Generator to 2C AFW Pump Turbine (MV-08-13)

(Back of MCC 2BS)

NOTE: Switch 3 and 5 must be in ISOLATE to have remote control of 2B charging pump.

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         .                                                                                                                CRI ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE NUMBER 2-0030141, REVISION 3 CONTROL ROOM INACCESSIBILIT'.

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APPENDIX "A" (continued) ISOLATION SWITCHES ,

)-

480V MCC 2A3 - Auxiliary Building Electrical Equipment Room

1. Component Cooling Water Suction Valve Rdr. A (MV-14-3)

2. Component Cooling Water Suction Valve Hdr. B (MV-14-4)

3. Component Cooling Water Discharge Valve Udr. A (MV-14-1)

4 Component Cooling Water Discharge Valve Hdr. B (MV-14-2)
5. Control Room Air Cond Unit 2-HVA/ACC 3C
NOTE: Switch 4 and 5 must be in ISOLATE to have remote control of 2C charging pump.

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Paga 27 of 42 CRI ST. LUCIE UNIT 2 ,r h EMERGENCY OPERATING PROCEDURE NUMBER 2-0030141, REVISION 3 CONTROL ROOM INACCESSIBILITY L{,i

                                                                                                        'l APPENDIX  "A" (continued)                                  /           '

a ._ , ISOLATION SWITCHES j ]

                                                                                                                  .   . . .n .

Transfer Panel 2AB - Auxiliary Building Electrical Equipment Room (2AB Battery Room) .f

1. 2C Aux Feed Pump Stop Valve MV-08-3 /R3 il 4

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Ptg2 28 of 42 CRI f %, j

ST. LUCIE UNIT 2 f ,, EMERGENCY OPERATING PROCEDURE NUMBER 2-0030141, REVISION 3 CONTROL ROOM INACCESSIBILITY w} ! i l s/ APPENDIX "A" (continued) .? Y w

                                               - ISOLATION SWITCHES                                             I Transfer Panel 2A - Auxiliary Building Electrical Equipment Room

1. 2A Steam Gen Acms Steam Dump PIC-08-1A1

2. 2A Steam Gen Atas Steam Dump PIC-08-1A1

3. SS-1-157 - Letdown cont Isol Valve (V-2516) 4 SS-1-189 - Aux Spray Valve (I-SE-02-3)

5. SS-194 - Charging Line Isol Valve (V-2523)

6. 2A Diesel Gen Watt / Volt Meter -

7. SS-1-176 - Charging to Loop 2A2 (I-SE-02-02)

8. 2C AW Pmp Diseg to 23 Steam Gen (MV-09-12 and I-SE-09-5)

9. 23 Steam Generator Atas Steam Dump PIC-08-3Al

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Prgo 29 of 42 CRI ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEQCRE NLHBER 2-0030141, REVISION 3 y CONTROL ROOM INACCE3S!BILITY g I i APPENDIX "A" (continued)

j j f, ISOLATION SWITCHES , j i; ,. - d '

                       ' /                                                                            j.

{

                                                                                                                                                                                              } . -

Tr'arsfer Pde.el 23 - Auxiliary Building EIectrical Equipment Room 1 .,

1. ' 2A Stica; Gen Atms Steam Dump PIC'08-131 ' . <,

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                                    , . I,                ' 2.
                                          .                                 ,  2A,-Ste p Gen Atas Steam Dump PIC-08-131 i                                           3. ~lh                  -L57 - Letdown Stop Valve (V-2515) 1*                                "

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4. SS-2-189 ,Iux Shray valve (I-SE-02-04) y(

5. SS-1-194 - Letdown . Cont Isol Valve (V-2522) e

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                                            ,,.                6. , 2B Die el Gen Watt / Volt meter                                                                                 1
                                                                                                            "                     r

7. SS-2-176 - Charging to Loop 2B1 (1-SE-02-01) 7

8. 2C AFW Pumh Disch to 2A Steam Gen (MV-09-11 and I-SE-09-4)

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                                                                                                                                                                                                                             .\.                                                                                         CRI I             \                                                             l                                                ST. LUCIE UNIT 2
                                                                                                                \                                                                                                                                                                                                                             .

EMERGENCY OPERATING PROCEDURE NUMBER 2-0030141, REVISION 3 C MTROL ROOM INACCESSIBILITY I-) .'. ; f (( 5B (o t ' s., . APPENDIX "A" (costinued) g#

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                                                                      - ' -                                                                                      J                            ~ ISOLATION SWITCHES
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                                                                                                                                                                                                                                     .Griliary Building Communications Room Communications. is\olation Panel  --                                    --

t Fire Aha. /h;i > < -, k Eva'cuar'boh\-> Control Console, Isolation Switch s

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                ,                                                                   Paga 31 of 42 CRI ST. LUCIE UNIT 2 j

t O,

EMERGENCY OPERATING PROCEDURE NLMBER 2-0030141, REVISION 3 y z .,

CONTROL ROOM INACCESSIBILITY Q APPENDIX "A" (continued) , ISot.ATION SWITCHES 4160V SWGR 2A2 - Turbine Building Switchgear Room

1. Feeder to 480V SWGR No. 2Al

2. Feeder to 4.16KV Bus No. 2A3 a- 1

3. Incoming Feeder from 4.16KV SWGR 2A4

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CRI l ST. LUCIE UNIT 2 .; . l EMERGENCY OPERATING PROCEDURE NUM3ER 2-0030141, REVISION 3 ? m CONTROL ROOM INACCESSIBILITY .! $' f sJ Y APPENDIX "A" (continued) y _, 7

                                                                                       ;l ISOLATION SWITCHES                           4 i

4160V SWCR 2B2 - Turbine Building Switchgear Room

1. Feeder to 480V SWGR No. 2B1

2. Feeder to 4.16KV Bus No. 2B3

3. Incoming Feeder from 4.16KV SWGR 2B4

                                                                                                   /R3' f

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P.tga 33 of 42 )

                     -                                                                                                   CRI ST. LUCIE UNIT 2                                               y EMERGENCY OPERATING PROCEDURE NUMBER 2-0030141, REVISION 3                                           M    }

CONTROL ROOM INACCESSIBILITY ly < A l APPENDIX "A" (continued) ISOLATION SWITCHES o 6900V SWGR 2A1 - Turbine Building Switchgear Room

1. Incoming Feeder from S/U Transf No. 2A

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Pega 34 of 42 ;

               -                                                                                                                            CRI                                              l ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE NUMBER 2-0030141, REVISION 3 CONTROL ROOM INACCESSIBILITY _

w I

APPENDIX "A" (continued) . 1 ISOLATION SWITCHES - 6900V SWGR 2B1 - Turbine Building Switchgear Room

1. -Incoming Feeder from S/U Tranaf No. 2B

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1 Paga 35 of 42

                    -                                                                                   CRI ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE NUMBER 2-0030141, REVISION 3 CONTROL ROOM INACCESSIBILITY I#N)

, APPENDIX "A" (continued)

                                    .                ISOLATION SWITCHES                                          lI L

AFW PUMP AREA i

1. MV-08-19B (Atmospheric Dump Valve)

2. MV-08-18B (Atmospheric Dump Valve 4

3. MV-08-18A (Atmospheric Dump Valve)

4. MV-08-19A (Atmospheric Dump Valve) i t

1 i

                                                                                                          ,..__,-n.,.n,.,., . _.n e                                                   *'f                                     @

Paga 36 of 42 CRI i

    .                                         ST. LUCIE UNIT 2                                                 '

EMERGENCY CPERATING PROCEDURE NUMBER 2-0030141, REVISION 3 g i CONTROL ROOH INACCESSIBILITY ; ,

APPENDIX "A" (continued) # ISOLATION SWITCHES _ i 4160V SWCR 2AB - Auxiliary Building Ground Floor

1. Component Cooling Water Pump No. 2C

2. Intake Cooling Water Pump No. 2C

3. Incoming Feeder from 4.16KV Bus 2A3

. 4 Incoming Feeder from 4.16KV Bus 2B3

                                                                                                                        /R3 1

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             -                                                                    Paga 37 of 42 CRI ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE NUMBER 2-0030141, REVISION 3               /

CONTROL ROOM INACCESSIBILITY

                                                                                            <                       l APPENDIX  "A" (continued)

ISOLATION SWITCHES f l 480V Load Center 2AB - Auxiliary Building Ground Floor

1. Bus Tie to 480V L.C. 2A2 (Left End of Panel) /R3

2. 2C Charging Pump

3. Bus Tie to 480V L.C. 2B2 j

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Page 38 of 42 CRI ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE NLHBER 2-0030141, REVISION 3 CONTROL ROOM INACCESSIBILITY

APPENDIX "A" (continued) ISOLATION SWITCHES y

                                                                                               /
                                                                        .                      l                                  }

2A Diesel Generator Control Panel

1. Voltage Control

2. Frequency Control

3. Start Circuit i

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Page 39 ef 42

CRI ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE NUMBER 2-0030141, LEVISION 3

                                                                                               ,I CONTROL ROOM INACCESSIBILITY                            !      e
                                                                                              !      l w         '              ,

APPENDIX "A" (continued) .

ISOLATION SWITCHES ! 1 2B Diesel Generator Control Pan'al

1. Voltage Control

2. Frequency Control

3. Start circuit i

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P:g3 1 of 42 EMERGENCY PROCEDURE 2-0030141 REV. 4 E f (" FLORIDA POWER & LIGHT COMPANY ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE 2-0030141 REVISION 4 CONTROL ROOM INACCESSIBILITY (CRI) _ ' s.

  ' :,                                                       TOTAL NO. OF PAGES 42 S'

FOR ICF00?.1AT!0!! ONLY This document h not contrs!!ed. Before use verify informatic, wiih a centrolled docu ment. J l I l l

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                                                                                                         ,R    1 FLORIDA POWER & LIGHT COMPANY l

ST. LUCIE UNIT 2 " l EMERGENCY OPERATING PROCEDURE 2-0030141 REVISION 4

1.0 TITLE

CONTROL ROOM INACCESSIBILITY

2.0 SYMPTOMS

Conditions exist such that the Control Room becomes uninhabitable and must be evacuated. 3.0 IMMEDIATE AUTOMATIC ACTION: None 4.0 IMMEDIATE OPERATOR ACTION: ACTION NOTES 4.1 Manually trip the reactor and 4.1 Push buttons on RTGB-201 Turbine prior to leaving the and 204. Control Room, if possible. 4.2 Announce evacuation of the Control Room over the P.A. system. 4.3 Implement the Emergency Plan, as necessary, in accordance with EPIP 3100021E, ' Duties of the Emergency Coordinator". 4.4 Obtain the Remote Shutdown Room 4.4 Key Number 2 Keybox Master Key from the l Control Room Key Locker.

~~

4.5 Evacuate all personnel from the Control Room. 2 o". 9 I 1 i l l

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Pzga 3 of 42 l ST. LUCIE UNIT 2 , EMERGENCY OPERATING PROCEDURE 2-0030141, REVISION 4 CONTROL ROOM INACCESSIBILITY 5.0 SUBSEOUENT dCTIONS: 5.1 Man and take control of stations as follows: CHECK 1

1. Reactor Control Operator "A" - Remote Shutdown Panel A. Establish communications on the Sound Power Phone System.

B. Monitor available plant parameters on the Remote Shutdown Panel. C. Start motor or steam-driven Auxiliary Feedwater Pumps and feed the Steam Generators as required. D. Control Pressurizer pressure and level by manual control of Pressurizer heaters, auxiliary spray valves, and letdown valves. NOTE: Only the "P" Letdown level and pressure valves are controllable from the Remote Shutdown Panel.

2. Nuclear Plant Supervisor - Electrical Equipment Room, Reactor Auxiliary Building - 43' Elev.

A. Open or check open Reactor Trip 3reakers TCB-1 through 8. B. Place isolation switches in the ISOLATE position on the following switchgear in the order listed: (See Appendix A) 480V Load Center 2A3 0- 480V Load Center 2B3

    ;                       480V Load Center 2A2 4160V Swgr. 2A3 430V MCC 2A5 480V MCC 2A6                                                    +

480V Load Center 2B2 __ 4160V Swgr. 2B3 480V MCC 2B6 480V MCC 2B5 480V MCC 2AB Isolation Panel 2AB Isolation Panel 2A Isolation Panel 2B Communications Isolation Panel

                                                                   -.     ..-.-.    ,.~-..n

l P:ga 4 cf 4 i ST. LUCIE UNIT 2 l EMERGENCY OPERATING PROCEDURE 2-0030141, REVISION 4 CONTROL ROOM INACCESSIBILITY

                                                                                                                                              '[ 7  '

[ 5.0 SUBSEQUENT ACTIONS: (continued) 5.1 (continued) _

2. (continued) CHECK C. Assist Reactor Control Operator "A" in monitoring unit parameters from the Remote Shutdown Panel.

D. Open or check open: 480V Load Center 2A3 P-1 HTR Feed 2-40305 480V Load Center 2B3 P-2 RTR Feed 2-40602

3. Reactor Control Operator "B" - Turbine Operating Level A. Locally trip or verify tripped Unit 2 Turbine, B. Verify Turbine Stop Valves and Control Valves are shut. If not, initiate Turbine trip from Turbine front standard.

I C. At the AFW Pump area, place the isolate switches for MV-08-19B, MV-08-18B, MV-08-18A, and MV-08-19A in ISOLATE. D. Proceed to Turbine Building Switchgear Room and establish communications on the Sound Powered Phone circuit. E. Place isolation switches in the ISOLATE position for bus feeder breakers as follows r (See Appendix A): k 4160V Swgr. 2A2 4160V Swgr. 2B2 6900V Swgr. 2Al 6900V Swgr. 2B1 l F. Stop 2A and 2B Main Feedwater Pumps, 2A and 23 Heater Drain Pumps, and one Condensate Pump by opening their respective breakers. [: CAUTION: Ensure that one Condensate Pump remains in service. l l l I

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                                            ,                                                                                   Pega 5 of 42 ST. LUCIE UNIT 2 l'

) EMERGENCY OPERATING PROCEDURE 2-0030141, REVISION 4 CONTROL ROOM INACCESSIBILITY I 5.0 SUBSEQUENT ACTIONS: (continued) 5.1 (continued) CHECK

4. Nuclear Operator - Reactor Auxiliary Building A. Place isolate switches in ISOLATE / LOCAL position on the following switchgear (see Appendix A):

4160V Swgr. 2AB 480V Load Center 2AB B. Proceed to the Diesel Generator Building and place isolation switches on 2A and 2B Diesel Control Panels in ISOLATE position (see Appendix A). C. Open or check open isolation valves for Letdown pressure and level control valves (V-2110P and V-2201P). Isolate V-2110Q and V-2201Q. D. Proceed to the Charging Pump area and establish communications on the Sound Powered Phone circuit. 5.2 Maintain Pressurizer level at approximately 33% indicated level. 5.3 Maintain Pressurizer pressure at approximately 2100 psia. 5.4 Maintain Reactor Coolant System temperature at or below 5320F (2A cold leg temperature) by use of atmospheric steam dump and/or selective shutdown

                  ;                           of Reactor Coolant Pumps.

NOTE Stop Reactor Coolant Pumps as required by opening the Reactor Coolant Pump breakers

                   '.                                    in the Turbine Building Switchgear Room.                                                    l
                   ,                    ).5 Maintain Steam Generator levels at approximately 65%                                      '

indicated level by operation of the Auxiliary Feedwater

                 ,                            Pumps and discharge valves to the Steam Generators.

5.6 Isolate Steam Generator blowdown by manually closing isolation valves at the Closed Blowdown Heat Exchangers. 5.7 When Turbine speed decreases to "0" RPM, verify that the l Turning Gear Oil Pump and the turning gear are in operation. 5.8 Periodically check the habitability of the Control Room and when conditions permit, reoccupy the Control Room. Return isolation switches to NORMAL for switches and controls that are operational and maintain the Unit at Hot Standby until a complete evaluation has been made.

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Paga 6 of 42 ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE 2-0030141, REVISION 4 l CONTROL RCOM INACCESSIBILITY 5.0 SUBSEQUENT ACTIONS: (continued) CHECK f 5.9 If Control Room accessibility is not possible, place the unit in a Cold Shutdown condition as follows: i

1. Commence boratica to Cold Shutdown conditions by i

manual valve lineup. Berate to 1900 ppm as shown below. Carry out boron sampling as required during cooldown. NOTE: This concentration will ensure >5% Shutdown Margin at 201 F at any time in core life, assuming the most , reactive CEA stuck full cut. Use both the local boron flow meters vs. time and BAM Tank level change to determine how many gallons of boron have been added. Do not interpolate , values shown, always round critical boron concentration DOWN to next lower value on table. NOTE: If plant curves are available, they may be used to determine shutdown boron concentration requirements instead of this Table. Boron Concentration Number of Gallons BAM Tank Prior to Control of Boron needed level change Room Inaccessibility i to reach 1900 ppm (1 BAM Tank) l 50 PPM l 7223 Gallons l 75% l l 100 PPM l 7039 Gallons l 73% l l 200 PPM l 6668 Gallons l 70% l j l 300 PPM l 6295 Gallons l 66% l l 400 PPM l 5919 Gallons l 62% l , l 500 PPM l 5442 Gallons i 57% l ! l 600 PPM i 5162 Gallons l 54% l l 700 PPM l 4779 Gallons l 50% l ', l 800 PPM l 4395 Gallons I 46% l

 -; t l                   900 PPM                   l            4008 Gallons             l          42%           l l                  1000 PPM                   l             3618 Gallons            l          38%           l l                  1100 PPM                   l            3226 Gallons             l          34%           l l                  1200 PPM                   l             2832 Gallons            l          30%           l                        l l                  1300 PPM                   l            2635 Gallons             1          25%           l l                  1400 PPM                   l            2036 Gallons             1          21%           l l                  1500 PPM                   l             1634 Gallons            l          17%           l

2. Ensure Steam Generator level is being maintained at approximately 65% by the Auxiliary Feedwater Pumps.

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                   ,                                                                  Pcga 7 cf 42 g ST. LUCIE UNIT 2                                r EMERGENCY OPERATING PROCEDURE 2-0030141, REVISION 4 CONTROL ROOM INACCESSIBILITY p

5.0 SUBSEOUENT ACTIONS: (continued) 5.9 (continued) CHECK 1 W

3. Stop at least one Reactor Coolant Pump prior to reaching 500 F by tripping its breaker at the 2A1 or 231 switchgear. Additional RCPs may be stopped as desired to control cooldown rate. After pump coastdown, stop the lift pumps by opening the associated breakers in the electrical switchgear room. Re-close lif t pump breakers af ter one minute elapses.

4. Place all Pressurizer heater switches at the Remote Shutdown Panel to 0FF. Heaters may be energized to control RCS pressure as needed.

5. The hiShest RCS cold leg temperature (highest one with RCP running) shall be plotted every 30 minutes. The copy of the graph (Figure 1) shall be kept with this pcocedure. The RCS temperature and pressure shall be determined to be within the limits of Figure 3.4-3 at least once per 30 minutes during cooldown.

NOTE: Cooldown of the RCS shall be limited to g5 F in any one hour period with RCS

                 .                temperature >97 F.

6. The Pressurizer water phase temperature shall be plotted every 30 minutes using the Saturated Temperature vs. Pressure curve of this procedure (Figure 2). If possible, maximize letdown and minimize charging when using auxiliary spray to minimize thermal stress on spray nozzle.

    '                     NOTE: Cooldown of the Pressurizer shall be limited to f,190 F in any one hour period.

7. When the quantity of boron calculated in Step 5.9.1 '

has been added, cooldown may proceed. Verify by chemistry sample (if possible) that desired boron concentration has been obtained. Commence taking data on cooldown curve. Have the "B" Reactor Control Operator break Condenser vacuum by manually opening vacuum breaker MOVs. CAUTION: MSIS will occur at about 475 F, and sealing steam will be lost. Ccndenser vacuum must be broken prior to 475 F to prevent seal damage. i

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PIge 8 cf 42 ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE 2-0030141, REVISION 4 CONTROL ROOM INACCESSIBILITY A s__! 5.0 SUBSEQUENT ACTIONS: (continued) > 5.9 (continued) CHECK /

                                                                                                                                            // g,
                                                                                                                                          !      1

8. Have I & C personnel install temporary VCT level "

monitoring equipment. While locally monitoring and controlling VCT level, slowly open the atmospheric steam dumps and establish the desired cooldown rate. NOTE: A makeup blend ratio to the VCT of about 9:1 is sufficient to maintain 1900 PPM boron in the RCS. NOTE: A temperature differential of approximately 1000F between the RCS and Pressurizer should be maintained during cooldown. Cooldown of the Pressurizer must be accomplished by use of auxiliary spray and heater control. i 9. When the SIAS amber permissive lights come on (1836 psia), block SIAS by turning the key operated switch on the Remote Shutdown Panel for both A and B channels.

10. At 1750 psia, isolate and bypass the following transmitters:

A. Charging header flow: close valve marked "HIGH SIDE", open valve marked " BYPASS", and close valve marked " LOW SIDE". B. Charging header pressure: close its isolation valve. o

11. Commence ven'ing all four SITS from remote valve stations in the Electrical Penetration Room.

(Valves 3733, 3734, 3735, 3736, 3737, 3738, 3739 and 3740). NOTE: Do not vent more than one SIT to <235 psig. H 12. Maintain at least two Reactor Coolant Pumps operating. If. possible, two RCPs in the same loop should be ' I left running.

13. Periodically adjust the steam dump controllers and auxiliary spray control to maintain the desired cooldown and de pressurization rate. Verify that the Steam Generators are being maintained at approximately 65% level.

14 With RCS pressure <1700 psia, but prior to commencing SDC operations, rack out 2A and 2B Containment Spray l . Pump breakers (2-20203 and 2-20407). l l i l

                                                    -                       _           _                      _ . _ . _    . - ~ . _ - _ , .    ,

P2gs 9 of 42 l ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE 2-0030141, REVISION 4 CONTROL ROOM INACCESSIBILITY 5.0 SUBSEQUENT ACTIONS: (continued) 5.9 (continued) CHECK

15. When RCS tempeiature is <500 F and RCS pressure is

                            <1500 psia, perform the following:

A. Close 2-V-07145 and 2-V-07130 (Containment spray pump disch valves). B. Close the following containment spray header manual isolation valves: 2-V-07161 (A hdr FCV upstream isol) 2-V-07164 (B hdr FCV upstream isol) 2-V-07162 ( A hdr FCV downstream isol) 2-V-07165 (B hdr FCV downstream isol)

16. When RCS pressure is <275 psia, rack in the breakers and then close the SIT discharge valves by placing the local control switch in the CLOSE position.

MV-3614: Bkr. 2-41219 MV-3624: Bkr. 2-41311 MV-3634: Bkr. 2-42117 MV-3644: Bkr. 2-42048

17. Rack out the SIT discharge valve breakers.

CAUTION: Prior to lowering RCS pressure below (later) psia, two RCPs in the same loop

         ,                              must be operating.

Lower RCS temperature to 3250 F and RCS pressure to 18. 275 psia.

 ,                     19. Rack out one RPSI Pump prior to 280 F.          Ensure the

. ,, other HPSI pump remains operable. ' CAUTION: With SDC in service, an increase in RCS pressure >350 psia will result in rapid RCS inventory loss due to lifting of relief valves in Hot Leg suction lines (Total capacity 4,600 gpm). NOTE: Minimum pressure for RCP operation is (later), so it is necessary to proceed quickly to Shutdown Cooling.

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Pzga 10 cf ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE 2-0030141, REVISION 4 6 CONTROL ROOM INACCESSIBILITY 5.0 SUBSEQUENT ACTIONS: (continued) ! 5.9 (continued) CHEC

20. Stop the operating RCPs prior to lowering pressure to (later) by tripping the breakers on 2A1 and 2B1 switchgear. After pump coastdown, stop the oil lift pumps by opening the breaker for each pump for one minute, then re-closing the breaker. I

21. Reduce RCS pressure to <275 psia, then open the following valves from their local controllers:

A. Hot Leg Suction Valves: V-3651, V-3652, V-3665, V-3480, V-3481, V-3664. NOTE: V-3664 and V-3665 local controllers are in Pipe Penetration Room; all others are in the Cable Spreading Room. NOTE: V-3545 (Hot Leg Suction Cross-Tie) is normally closed. It may be used to provide flow during off-normal conditions and must be open if both trains of SDC are in service. B. Open CCW from SDC Heat Exchangers: HCV-14-3A and RCV-14-3B by isolating instrument air to the HCVs and bleeding off air pressure. C. SDC Heat Exchanger Discharge Valves: MV-3456 and MV-3457. D. LPSI Header Isolation Valves: MV-3615, MV-3625, MV-3635 and MV-3645.

   ,          22. Close the following valves:

l ( A. RWT recirculation stop valves: V-3459, i V-3463, and V-3597

B. Miniflow header stop valves: V-3659, V-3660, V-3495 and V-3496.

L C. V-3432 and V-3444 LPSI suction from RWT.

23. Have the Nuclear Operator establish communications on the Sound Power Phone System in the 2A LPSI Pump Room.

P:ga 11 of 42 ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE 2-0030141, REVISION 4 m CONTROL ROOM INACCESSIBILITT i w ,

5.0 SUBSEQUENT ACTIONS: (conrinued) 5.9 (continued) CHECK 24 Establish SDC as follows: A. Insert keys for MV-3306 and MV-3657 (controllers located in A LPSI Room) and place switches to MODULATE position. B. Using Key switches at local controllers, open MV-3517 and MV-3658. C. Give MV-3306 a three second open signal, then allow switch to return to NORMX . D. Start the 2A LPSI Pump, then open MV-3306 to obtain 3000 gpm flow as indicated on FI-3306 at the Remote Shutdown Panel. E. While observing SDC outlet temperature and flow on the Remote Shutdown Panel, alternately open MV-3657 and close MV-3306 to achieve desired cooldown rate and maintain 3000 gpm.

25. At 2000F RCS temperature, remove the trip and close fuses on the remaining HPSI Pump. Open the breaker for one Charging Pump so that no more than two Charging Pumps are operable.

26. Stabilize RCS temperature at approximately 1000F and RCS pressure at approximately 250 psia. Control pressure by use of Pressurizer heaters and auxiliary spray. Do not take the Pressurizer solid until Control Room access has been re-established.

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l Piga 12 of 42 ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE 2-0030141, REVISION 4 CONTROL ROOM INACCESSIBILITY N l 6.0 PURPOSE AND DISCUSSION: jM l I i 6.1 This procedure provides instructions for placing the plant in a safe l condition when operatiens cannot safely be conducted from the Control Room. 6.2 The reactor and turbine are manually tripped prior to leaving the i Control Room, if possible, or locally from the Reactor Trip. Switchgear and the Turbine front standard. 6.3 A heat sink is provided by automatic steam dump to the Condenser and/or to atmosphere. 6.4 Level is maintained in the Steam Generators by manual control of auxiliary feedwater valves with flow furnished by the Auxiliary Feedwater Pumps. 6.5 Pressurizer level and pressure are maintained by manual control of Pressurizer heaters, auxiliary spray valves, and letdown valves, and are monitored at the Remote Shutdown Panel. 6.6 Isolation switches located in the Reactor Auxiliary Building Electrical Equipment Room, Turbine Building Switchgear Room, Diesel Generator Rooms, and Reactor Auxiliary Building are manually selected to the ISOLATE position to prevent inadvertant operation of vital equipment due to possible electrical malfunction in the unattended Control Room. 6.7 A copy of this procedure will be posted at each manned operating station required for plant shutdown from outside the Control Room. 6.8 A listing of isolation switches will be posted on each of the following panels, MCCs, and distribution buses.

1. Load Centers 2A, 2B, 2AB

2. Transfer Panels 2A, 2B, 2AB

3. MCC 2A5, 2A6, 2B5, 2B6

4. 4160V Buses 2A3, 2B3, 2AB ,

5. 4160V Buses 2A2, 2B2

6. 6900V Buses 2A1, 2B1

7. Diesel Generator 2A and 2B Control Panels 6.9 The Nuclear Plant Supervisor will utilize additional personnel as available to assist in required subsequent actions.

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                  ,                                                                                        P2ga 13 cf 42                            l ST. LUCIE UNIT 2                                                                                  j EMERGENCY OPERATING PROCEDURE 2-0030141, REVISION 4                                                             t CONTROL ROOM INACCESSIBILITY                                                                          I

7.0 REFERENCES

c [ 7.1 Emergency Operating Procedure 1-0030141 [ 7.2 St. Lucie Unit 2 Technical Specifications

8.0 RECORDS

8.1 A completed, initialed copy of this procedure shall be retained in' the plant file.

9.0 APPROVAL

Reviewed by Facility Review Group October 26 1982 Approved by J. H. Barrow ( for) Plant Manager October 26 1982 Revision 4 Reviewed by FRG - _ 19[3 Approved by []! 0 4 ( ./1 / h Manager J[6 19 [ 3 (/ i - EP 2-0030141 I Revision 4 Total No. of Pageo 42 '. N x t-he' l - '.(' I e^ n

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                                                                                                     'ST. LUCIE UNIT 2

r. ', ' l DfERGENCY OP3 EATING '#ROCEDLIRE,29030141, REVISION 4

                                      /                                                 ,.~CONTROL ROOM INACCTSSIBILITY' i - .,        '

1

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                                                                      /               'I'                APPENDIX ,"A"                                                              l
                                                           .,       /

o. r ISOLATION SWITCHES

                                                        ' ;.' ' /

i 4dOV Il,ad Center 2A3 - Pressurizer Heater Bus, Auxiliary Building 1

                                                                                   /          Electrical Equipment Room

1. Pressurizer Backup Heater Bank B-1

2. Pressurizer Backup Heater Bank B-2

3. Pressurizar Backup Heatcr Bank B-3

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t ,ST. LUCIE UNIT 2 ' 1- 1 lp i , EMERGENCY OPERATING PROCEDURE 2-0'1301C1, REVISION 4 CO'4 TROL ROOM INACCESSIBILITY g ! .- 1 I i 1 9 APPENDIX "A" (continued)

ISOLATION SWITCHES 430V L2ad Center 2B3 - Pressurizer Heatar Bus, Auxiliary Building Flectrical Equipreent Room: 1. : Pressurizer Eacktsp Heater Bank B-4; 2. Pressu-izer Backup Heater Bank B-5; 3. Pressurizer. Backup Heater Bank B-6 l

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Pego 16 cf 42 ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE 2-0030141, REVISION 4 CONTROL ROOM INACCESSIBILITY F. APPENDIX "A" (continued) ISOLATION SWITCHES g' l

                                                      -                                                                                           t l

480V Load Center 2A2 - Auxiliary Building Electrical Equipment Room

1. Station Service Transf 2A2 Main Breaker

2. Bus Tie to 480V L.C. 2AB

3. Containment Fan Cooler 2-HVS-1A ,

4 Charging Pump 2A

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P:g3 17 cf 42 ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE 2-0030141, REVISION 4 CONTROL ROOM INACCESSIBILITY APPENDIX "A" (continued) ISOLATION SWITCHES 480V Load Center 2A5 - Auxiliary Building Electrical Equipment Room

1. Containment Fan Cooler 2-HVS-1B

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l Peg 3 18 of 42 ST. LUCIE UNIT 2 l EMERGENCY OPERATING PROCEDURE 2-0030141, REVISION 4 I CONTROL ROOM INACCESSIBILITY n APPENDIX 'A" (continued) ISOLATION SWITCHES 4160V SWGR 2A3 - Auxiliary Building Electrical Equipment Room

1. HP Safety Injection Pump No. 2A

2. LP Safety Injection Pump No. 2A

3. Containment Spray Pump No. 2A

4. Pressurizer Heater Transf No. 2A3

5. CEDM Cooling Fan 2HVE-21A

6. Component Cooling Water Pump No. 2A

7. Intake Cooling Water Pump No. 2A

8. Feeder to 4.16KV Bus No. 2AB

9. Feeder from 4.16KV Bus No. 2A2

10. Feed to 480V SS Transformer 2A2/2A5

11. Emergency Diesel Generator No. 2A

12. Auxiliary Feedwater Pump No. 2A 5,

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Pega 19 cf 42 ST. LUCIE UNIT 2 . EMERGENCY OPERATING PROCEDURE 2-0030141, REVISION 4 CONTROL ROOM INACCESSIBILITY .R m 1 APPENDIX "A" (continued) ISOLATION SWITCHES 480V MCC 2AS - Auxiliary Building Electrical Equipment Room

1. Makeup Bypass to Charging Pumps V-2514 (Emergency Borate)

2. Aux. F.W. Pump 2A Discharge Valve to S/G 2A (MV-09-9 and I-SE-09-2)

3. S/G #2B to AFWP-2C Turbin MV4 8-12 4 Comp Cool Wtr to Cont Cool Unit 2A Valve MV-14-9

5. Comp Cool Wtr from Cont Cool Unit 2A MV-14-10

6. Comp Cool Wtr Cont Cool Unit 2B MV-14-11
7. Comp Cool Wtr from Cont Cool Unit 2B Valve MV-14-12
NOTE: Switch 1, 6, and 7 must be in ISOLATE to have remote control of 2A charging pump.

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P:g3 20 cf 42 ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE 2-0030141, REVISION 4 CONTROL ROOM INACCESSIBILITY APPENDIX "A" (continued) ISOLATION SWITCHES I 480V MCC 2A6 - Auxiliary Building Electrical Equipment Room

1. Boric Acid Makeup Pump 2A

2. Boric Acid Makeup Pump 23

3. Control Room Air Cond Unit 2HVA/ACC 3A

4. Shield Bldg. Vent Exhaust Fan 2HVE-6A

5. Control Room E:nerg. Filtration Fan 2HVE-13A

6. Containment Spray Isolation Valve MV-07-161

7. 2A LPSI Pump Suction Valve V-3444 4

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P:ga 21 of 42 ST. LUCIE UNIT 2 , EMERGENCY OPERATING PROCEDURE 2-0030141, REVISION 4 CONTROL ROOM INACCESSIBILITY F APPENDIX "A" (continued) ISOLATION SWITCHES 480V Load Center 232 - Auxiliary Buildiug Electrical Equipment Room

1. Station Service Transf. 2B-2 Main Breaker

2. Bus Tie to 480V L.C. 2AB

3. Containment Fan Cooler 2HVS-1C j

4. Charging Pump 2B .

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P:ga 22 cf 42 ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE 2-0030141, REVISION 4 CONTROL ROCH INACCESSIBILITY i APPENDIX "A" (continued) ISOIATION SWITCHES j 480V Load Center ?BS - Auxiliary Building Electrical Equipment Room

1. Containment Fan Cooler 2-HVS-1D 1

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l l , P:ga 23 of 42 l ST. LUCIE UNIT 2 l EMERGENCY OPERATING PROCEDURE 2-0030141, REVISION 4 CONTROL ROOM INACCESSIBILITY l ! APPENDIX "A" (continued) l ISOLATION SWITCHES I 4160V SWGR 2B3 - Auxiliary Building Electrical Equipment Room

1. Emergency Diesel Generator No. 2B

2. Feed to 480V SS Transformer 2B2/2B5

3. Pressurizer Heater Transf No. 2B3

4. Component Cooling Water Pump No. 2B

5. HP Safety Injection Pump No. 2B

6. LP Safety InjERron Pump No. 2B

7. Containment Spray Pump No. 2B

8. CEDM Cooling Fan 2HVE-21B

9. Feeder to 4160V Bus No. 2AB

10. Intake Cooling Water Pump No. 2B

11. Incoming Feeder from 4.16KV Bus 232

12. Auxiliary Feedwater Pump No. 2B s

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Pego 24 cf 42 ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE 2-0030141, REVISION 4 CONTROL ROOM INACCESSIBILITY APPENDIX "A"

f (continued) /

ISOLATION SWITCHES 1 __ 480V MCC 2B6 - Auxiliary Building Electrical Equipment Room

1. 2HVE-13B - Control Room Booster Fan

2. Control Room Air Cond 2HVA-3B

   ,               3. Containment Spray Isolation Valve (MV-07-164) 4     Shield Bld Vent Exh Fan 2HVE-6B

5. 2B LPSI Pump Suction Valve (V-3432)

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Pega 25 cf 42 ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE 2-0030141, REVISION 4 i CONTROL ROOM INACCESSIBILITY , APPENDIX "A" (continued) ISOLATION SWITCHES 480V MCC 2B5 - Auxiliary Building Electrical Equipment Room

1. CCW to Containment Fan Cooler 2HVS-1C (MV-14-13)

2. CCW from Containment Fan Cooler 2HVS-1D (MV-14-14)

3. Boric Acid Gravity Feed Valve (V-2508) '

4. Boric Acid Gravity Feed valve (V-2509)

5. CCW to Containment Fan Cooler 2HVS-ID (MV-14-15)

6. CCW from Containment Fan Cooler 2HVS-ID (MV-14-16)

7. 2B AFW Pump Discharge to 2B Steam Generator (MV-09-10 and I-SE-09-3)

(Back of MCC 2BS)

8. 2A Steam Generator to 2C AFW Pump Turbine (MV-08-13)

(Back of MCC 2BS)

NOTE: Switch 3 and 5 must be in ISOLATE to have remote control of 2B charging pump.

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Pega 26 of 42 ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE 2-0030141, REVISION 4 CONTROL ROOM INACCESSIBILITY 9 1 APPENDIX "A" (continued) ISOLATION SWITCHES l

         . 480V MCC 2AB - Auxiliary Building Electrical Equipment Room

1. Component Cooling Water Suction Valve Rdr. A (MV-14-3)

2. Component Cooling Water Suction Valve Hdr. B (MV-14-4)

3. Component Cooling Water Discharge Valve Hdr. A (MV-14-1)

4. Component Cooling Water Discharge Valve Hdr. B (MV-14-2)
5. Control Room Air Cond Unit 2-HVA/ACC 3C

NOTE: Switch 4 and 5 must be in ISOLATE to have remote control of 2C charging pump.

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Pzga 27 of 44 ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE 2-0030141, REVISION 4 i CONTROL ROOM INACCESSIBILITY l APPENDIX "A" (continued) ISOLATION SWITCHES 69 11 l 4 Transfer Panel 2AB - Auxiliary Building Electrical Equipment Room (2AB Battery Room)

1. 2C Aux Feed Pump Stop Valve MV-08-3 L

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Paga 28 of 42 ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE 2-0030141, REVISION 4 - CONTROL ROOM INACCESSIBILITY APPINDIX "A" (continued)

                          ,                                                  ISOLATION SWITCHES                            I-r       --,

Transfer Panel 2A - Auxiliary Building Electrical Equipment Room

1. 2A Steam Gen Atas Steam Dump PIC-08-1A1

2. 2A Steam Gen Atas Steam Dump PIC-08-1A1

3. SS-1-157 - Letdown cont Isol Valve (V-2516)

4. SS-1-189 - Aux Spray Valve (I-SE-02-3)

5. SS-194 - Chargi'ng Line Isol Valve (V-2523)

6. 2A Diesel Gen Watt / Volt Meter 7 SS-1-176 - Charging to Loop 2A2 (I-SE-02-02)

8. 2C AFW Pap Diseg to 2B Steam Gen (MV-09-12 and I-SE-09-5)

9. 2B Steam Generator Atas Steau Dump PIC-08-3Al 5 .g b

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Pega 29 cf 42 ST. LUCIE UNIT 2 . EMERGENCY OPERATING PROCEDURE 2-0030141, REVISION 4 CONTROL ROOH INACCESSIBILITY APPENDIX "A" (cortinued) ISOLATION SWITCHES 1, Transfer Panel 2B - Auxiliary Building Electrical Equipment Room

1. 2B Ste m Gen Atas Steam Dump PIC-08-131 /R4

2. 2B Steam Gen Atms Steam Dump PIC-08-131 /R4

3. SS-2-157 - Letdown Stop Valve (V-2515)

4. SS-2-189 - Aux Spray Valve (I-SE-02-04)

5. SS-1-194 - Letdown Cont Isol Valve (V-2522)

6. 2B Diesel Gen Watt / Volt meter

7. SS-2-176 - Charging to Loop 2B1 (I-SE-02-01)

8. 2C AFW Pump Disch to 2A Steam Gen (MV-09-11 and I-SE-09-4)

9. 2A Steam Gen Atas Steam Dump PIC-08-3B1

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Pega 30 cf 42 ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE 2-0030141, REVISION 4 CONTROL ROOM INACCESSIBILITY APPENDIX "A" (continued) ISOLATION SWITCHES 1 Consnunications Isolation Panel - Auxiliary Building Communications Room

1. Pire Alarm / Site Evacuation - (Control Console, Isolation Switch) e 0

1

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Pcgs 31 cf 42 l ST. LUCIE UNIT 2 l EMERGENCY OPERATING PROCEDURE 2-0030141, REVISION 4 l CONTROL ROOM INACCESSIBILITY APPENDIX "A" ! (continued) ! ISOLATION SWITCHES l 4160 SWGR 2A2 - Turbine Building Switchgear Room

1. Feeder to 480V SWGR No. 2Al

2. Feeder to 4.16KV Bus No. 2A3

3. Incoming Feeder from 4.16KV SWGR 2A4 I

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P::ga 32 of 42 ST. LUCIE UNIT 2

EMERGENCY OPERATING PROCEDURE 2-0030141, REVISION 4 CONTROL ROOM INACCESSIBILITY APPENDIX "A" r 1 (continued)

ISOLATION SWITCHES I 4160V SWGR 2B2 - Turbine Building Switchgear Room

1. Feeder to 480V SWGR No. 2B1

2. Feeder to 4.16KV Bus No. 2B3

3. Incoming ^ Feeder from 4.16KV SWGR 2B4 t

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P2ga 33 of 42 ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE 2-0030141, REVISION 4 1 CONTROL R00ti INACCESSIBILITY , APPENDIX "A" / (continued) ISOLATION SWITCHES I J 6900V SWGR 2A1 - Turbine Building Switchgear Room ,

1. Incoming Feeder frota S/U Transf No. 2A l

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P:gn 34 of 42 ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE 2-0030141, REVISION 4 CONTROL ROOM INACCESSIBILITY r APPENDIX "A" (continued) ISOLATION SWITCHES 1. 6900V SWGR 2B1 - Turbine Building Switchgear Room

1. Incoming Feeder from S/U Transf No. 2B

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l , P:gn 35 cf 42 ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE 2-0030141, REVISION 4 CONTROL ROOM INACCESSIBILITY I e w, APPENDIX "A" , (continued) ISOLATION SWITCHES AFW PUMP AREA

1. MV-08-19B (Atmospheric Dump Valve)

2. MV-08-18B ( Atmospheric Dump Valve)

3. MV-08-18A (Atmospheric Dump Valve) 4 MV-08-19A (A::mospheric Dump Valve) p

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Pega 36 cf 42 ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE 2-0030141, REVISION 4 - CONTROL RO M INACCESSIBILITY l APPENDIX "A" J (continued) ISOLATION SWITCHES b 4160V SWGR 2AB - Auxiliary Building Ground Floor

1. Component Cooling Water Pump No. 2C

2. Intake Cooling Water Pump No. 2C

3. Incoming Feeder from 4.16KV Bus 2A3

4. Incoming Feeder from 4.16KV Bus 233 1 #

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Paga 37 of 42 ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE 2-0030141, REVISION 4 CONTROL ROOM INACCESSIBILITY APPENDIX "A"

r

                                                 .(continued)

ISOLATION SWITCHES I 480V Load Center 2AB - Auxiliary Building Ground Ploor

1. Bus Tie to 480V L.C. 2A2 (Left End of Panel)

2. 2C Charging Pump

3. Bus Tie to 480V L.C. 2B2 o

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i l l Prga 38 of 42 ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE 2-0030141, REVISION 4 CONTROL ROOM INACCESSIBILITY q\ tw ! APPENDIX "A" (continued) ISOLATION SWITCHES , 2A Diesel Generator Control Panel

1. Voltage Control

2. Frequency Control

3. Start circuit t

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1. Voltage Control

2. Prequency Control

3. Start Circuit i

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Page 1 of 12 i FLORIDA POWER & LIGHT COMPANY - . i ST. LUCIE UNIT 2 ' ! 0FF-NORMAL OPERATING PROCEDURE NO. 2-0110030 REVISION 2

h i

1.0 TITLE

L. , L CEA 0FF-NORMAL OPERATION AND REALIGNMEtif

2.0 APPROVAL

Reviewed by Facility Review Group March 10 1983 Approved by C. M. Wethy Plant Manager March 10 1983 Revision _2_ Reviewed by FRG NE 1963 Approved by d /el duo Plant Manager dYd 19[ (/ 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

(>15 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 hour 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. FOR IMF0DM.F.TiO!! ONLY lbis document is r.ot contro!!ed. Before use, verify information with a controlled decument.

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Ptga 2 of 12 ST. LUCIE UNIT 2 0FF-NORMAL OPERATING PROCEDURE NO. 2-0110030, REVISION 2 OEA 0FF-NORMAL OPERATION AND REALICNMENT , I 3.0 PURPOSE AND DISCUSSION: (Cont.) 3.1 (Cont.)

3. Overpower margin is provided to protect the core in the event of a large misalignment (>15 inches) of a CEA. However, this misalignment would cause distortion of the core power distribution. This distribution may, in turn, have a significant effect 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 CEAs 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.

 'E 4.3 CEA motion inhibit alarm.

O

~~ j 4.4 Dropped CEA alarm. 4.5 AWF alarm. 4.6 PDIL and PPDIL alarms. _ 4.7 Croup out of sequence alarm. 4.8 Short term, steady state insertion alarm. l

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Ptgs 3 of 12 ST. LUCIE UNIT 2 0FF-NORMAL OPERATING PROCEDURE NO. 2-0110030, REVISION 2 / ** CEA 0FF-NORMAL OPERATION AND REALIGNMENT

5.0 INSTRUCTIONS

l 5.1 CEA inoperable or misalignment of greater than 7.0 inches but less than 15.0 inches. 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 hours thereafter.

l 4. If excessive friction or mechanical interference prevents

  ]                                                                         movement of the CEA or the CEA is untrippable, be in Hot a                                                                     Standby in six hours. See OP #2-0030125, " Turbine

(;} Shutdown Full Load to Zero Load". d 5. If one or more CEAs are inoperable due to other reasons fi/

"?                                                                          than stated in Step 5.1.3.4, declare inoperable within one hour and realign remainder of operable CEAs in group
   'i within 7.0 inches of inoperable CEAs, without violating

[ CEA sequence and insertion limits, within one hour (or be in Hot Standby within 6 hours). Operation in Modes 1 and

  ;7                                                                        2 may continue provided the thermal power level is restricted pursuant to Technical Specification 3.1.3.6 A'.  - '

during subsequent operation and the Shutdown Margin requirement of Technical Specification 3.1.1.1 is determined at least once per 12 hours. 1. s

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Pcga 4 of 12 ST. LUCIE UNIT 2 0FF-NORMAL OPERATING PROCEDURE NO. 2-0110030, REVISION 2 CEA 0FF-NORMAL OPERATION AND REALIGNMENT g! j i w

5.0 INSTRUCTIONS

(Cont.) 5.1 (Cont.) '

                                                                                                                                      &==-]

a 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: q 1. Determine from symptoms and CEA position indications the

             ,                                   cause of the inoperability or if the CEA is operable but 1                                        misaligned, in accordance with Appendix "B".
         ^i                                2. Ensure automatic f unctions have initiated.

' }]- 3. RefertoPlantCurveBookandobtainF{value.

4. Within 15 minutes (25 minutes if FR <1.5), restore the CEA (per Appendix A) to within 7.0 inches of all other CEAs in its group or reduce power to <70% of RATED THERMAL POWER within one hour of misalignment, r

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Pcgn 5 of 12 ST. LUCIE UNIT 2 0FF-NORMAL OPERATING PROCEDURE No. 2-0110030, REVISION 2 CEA 0FF-NORMAL OPERATION AND REALIGNMENT ?

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LP .

5.0 INSTRUCTIONS

(Cont.) 5.2 (Cont.) / t 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:

CAUIION: Prior to realigning the CEA, reduce power to <70% of the THERMAL POWER level prior to misalignment IF THE PRE-MISALIGNMENT ASI WAS MORE NEGATIVE THAN -0.15. /R2

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 lisits 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 hours.
  ,                                                                          OR c) Se in Hot Standby within 6 hours.

6. 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.; 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 CEA inoperable or misaligned from any other CEA in its group by 15 inches (indicated position)
or more, be in Hot Standby within 6 hours.

1 l 1

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Page 6 of 12 ST. LUCIE UNIT 2 0FF-NORMAL OPERATING PROCEDURE NO. 2-0110030, REVISION 2 CEA 0FF-NORMAL OPERATION AND REALIGNMENT

r

5.0 INSTRUCTIONS

( Cont. ) ,/

5.3 Dropped CEA . [ ] 5.3.1 Immediate Automatic Action: '

1. CEA action 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 aisaligned, in accordance with Appendix "B". During the determination of the cause of the dropped CEA 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.

4. Within15 minutes (25minutesifFj<1.5),restorethe CEA (per Appendix A) to within 7.0 inches of all other CEA's in its group or reduce power to <70% of RATED THERMAL POWER within on hour of misalignment.

5. Within one hour:

i

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7 a) Restore to operable status within its specified alignment requirements (within 7.0 inches of other j 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 realigning the CEA, reduce power to <70% of the THERMAL POWER level prior to

   ,                                                                               misalignment IF THE PRE-MISALIGNMENT ASI WAS MORE NEGATIVE THAN -0.15.                               /R2
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Pega 7 of 12 ST. LUCIE UNIT 2 , OFF-NORMAL OPERATING PROCEDURE No. 2-0110030, REVISION 2 CEA 0FF-NORMAL OPERATION AND REALIGNMENT [

                                                                                                          }      l t

3 6- u !

5.0 INSTRUCTIONS

(Cont.) / 5.3 (Cont.) [ I 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 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 hours.

OR c) Be in Hot Standby within 6 hours.

6. Determine Shutdown Margin within one hour af ter 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 Rot Standby in six hours. See OP #2-0030125, "Turbino 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 hours.
 ~  ~. l

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. l l l

Paga 3 of 12 ST. LUCIE UNIT 2 #m OFF-NORMAL OPERATING PROCEDURE NO. 2-0110030, REVISION 2 $ CEA 0FF-NORMAL OPERATION AND REALIGN'ENT o

5.0 INSTRUCTIONS

(Cont.) t [ 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 hours in order to reduce the azimuthal oscillation and the resultingvaluesofF,T,Fh,andASI R resultingfromadroppedbEA.

6.0 REFERENCES

6.1 St. Lucie Unit 2 Technical Specifications 6.2 CEDMCS Tech Manual 7.0 RECORDS REQUIRED: 7.1 Normal log entries f 1

t i

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Paga 9 of 12 ST. LUCIE UNIT 2 ' 0FF-NORMAL OPERATING PROCEDURE NO. 2-0110030, REVISION 2 p - CEA 0FF-NORMAL OPERATION AND REALIGNMENT y APPENDIX A - CEA REALIGNMENT 1.0 Limits and Precautions: , 1.1 Regulating CEAs should be withdrawn in sequence and overlap between 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 CEAs 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 decerained at least once per 12 hours 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 lirait curves).

2.0 Instructions

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

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

2. Utilizing MANAUAL 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 9                           alignment.

l-

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i Ptga 10 of 12 ' ST. LUCIE UNIT 2 i 0FF-NORMAL OPERATING PROCEDURE NO. 2-0110030, REVISION 2 ' CEA 0FF-NO UlL OPERATION AND REALIGNMENT y, { ; APPENDIX A - CEA REALIGNMENT (Cont.) f

E 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 MANUAL 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. 4

.a.

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Page 11 of 12 ST. LUCIE UNIT 2 0FF-NORMAL OPERATING PROCEDURE NO. 2-0110030, REVISION 2 CEA 0FF-NORMAL OPERATION AND REALIGNMENT l 1 km 1 APPENDIX B - DROPPED CEA INVESTIGATION 1.0 Determine that the dropped CEA is functional, select Manual Individual (MI) on the Mode Select switch, select the affected CEA on the Individuall [ l CEA Selection switches, and select the group of the affected CEA on the Group Select switch. Momentarily press the Bypass Enable push button and press and hold the CMI Bypass push button, Withdraw the affected CEA until the Core Mimic DRC light and the Lower Electric Limit light both deenergize. Insert and withdraw the affected CEA and check for smooth 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: Dropped CEAs have occurred from: A. Tripped CEA Disconnect B. Loss of CEA Subgroup logic function Symptoms A. 1. CEA Disconnect in OFF, red light of f, green light on.

2. CEA Disable lights red for affected CEA.

B. Timer Failure lights red for affected CEA. i Trouble Shooting A. Call I & C specialist in. B. 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. I~ -

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.

l l

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

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0FF NORMAL & EMERGENCY OPER. PROCEDURN l r CCCMM TITLEPRESSut/2tk PRESSu tc,, i* l S v E L , a *

            ,     CCCUMENT FILE NUtiBER  J - 6 /.2 00.f4"                                               l CCCUZENT REVISIOU NUMBER                M                                         .

OCCGENT DISTRI3CTED CM [- [ "[ 3

                                                  .        DATE DCCCM SINT TO:                                                               $

wi COPY TRANSMI"*AL COPY No. TRANSMI*TAL DCCOM.T HOLDER RE ve.acu NO. DCCOMEN* EOLDER RE""JRNED

(

MASTER UNCONTROLLED COPIES 1 D. A. Sager 2 3 NRC - Region II 4 Actn: EPPS Branch C hief H. Paduano - GO 5 N. G. Roos A. W. Bailey 6 TSC 7 G. Anglehart - CE 8 9 l t 10 c.,m o/eO*A II 11 G. Regal (- 12 Ugelow, Al ~Backfit 13 Tra ming - Larry Bak er 14 15 Training J. Spodick T. Vogan - GO G. J. Boissy R. R. Jennings H. M. Mercer R. J. Frechette

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P2g2 1 of 6 FLORIDA POWER & LIGHT COMPANY ST. LUCIE UNIT 2 y'-F. i OFF-NORMAL OPERATING PROCEDURE NO. 2-0120035 REVISION 2

1.0 TITLE

2 PRESSURIZER PRESSURE AND LEVEL-OFF-NORMAL OPERATION 2.0 REVIEW AND APPROVAL: Reviewed by Facility Review Group March 1 1983 Approved by J. H. Barrow ( for) Plant Manager March 1 1983 Revision 2 Reviewed by FRG %d 1983 Approved by M8/8MM Plant Manager ///4v# 7- 19 R3

3.0 PURPOSE

This procedure provides instructions for operator actio's in the event of malfunction of Pressurizer pressure and level control systems, or pressure transient caused by inadvertant operation of the auxiliary spray valves.

4.0 SYMPTOMS

4.1 Pressurizer High-Low Pressure alarm, Channel X or Y. 4.2 Pressurizer High-Low Level alarm, Channels X or Y. 4.3 Pressurizer Low-Low Level alarm Channels X or Y. 4.4 Pressurizer Proportional Heaters Low Level trip. 4.5 Pressurizer Back-up Heaters Low Level Trip Control Switch isolated. 4.6 Safety or Relief Valve (s) open alarm. 2 2 I- F0R INF00Elri!0"! O fl!.Y This docurnent is -,1 c:ni ehe % 3r, . us , l I verify inferrnation wi:h a contreilad decurnent.

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Pcg3 2 cf 6 ST. LUCIE UNIT 2 0FF-NORMAL OPERATING PROCEDURE NO. 2-0120035, REVISION 2 PRESSURIZER PRESSURE AND LEVEL-OFF-NORMAL OPERATION l l

5.0 INSTRUCTIONS

5.1 Immediate Automatic Actions: 5.1.1 Abnormal Pressurizer Pressure Condition

1. Pressurizer safety valves open at 2500 psia.

2. High pressure reactor trip and power operated relief s open at 2375 psia.

3. High pressure alarm actuates at 2340 psia and a back-up signal will de-energize all heaters. /R2

4. Proportional heaters cycle from minimum output at 25 psi above setpoint to maximum output at 25 psi below set point.

5. Spray valves cycle from full cleaed at 25 psi above setpoint to full open 75 psi ahove setpoint. /R2

6. Back-up heaters energize at <2200 psia and de-energize at

                                  >2200 psia.

7. Low pressure alarm actuates at 2100 psia.

8. TM/LP reactor trip initiates at 1887 psia minimum pressure.

9. SIAS initiates at 1708 psia.

      ,            5.1.2       Abnormal Pressurizer Level Condition
      ,                        1. All Pressurizer heaters de-energize at 27% indicated
  's                              level, and respective Pressurizer Heater Transformer

a

   ,1 Feeder Breaker opens.                                                      /R2

a 2. Low level alarm actuates and signal to start the back-up Charging Pump is received at 5% below RRS setpoint. /R2 NOTE: Only one back-up Charging Pump is in the level control system.; 3. The back-up Charging Pump receives a signal to start at 3% below RRS setpoint, decreasing. /R2 4 The back-up Charging Pump receives a signal to stop at 1%

below RRS setpoint, increasing, and minimum letdown (29 gpm). /R2 n.,.g 3, y-

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         .                                         ST. LUCIE UNIT 2 0FF-NORMAL OPERATING PROCEDURE NO. 2-0120035, REVISION 2 PRESSURIZER PRESSURE AND LEVEL-OFF-NORMAL OPERATION

5.0 INSTRUCTIONS

(Cont.) J 5.1 (Cont.) 5.1.1 (Cont.) k I

5. All back-up heaters energize and a back-up stop signal to the back-up Charging Pump is received at 4.0% above RRS setpoint. /R2

6. Maximum letdown is 128 gpm at 9% above RRS setpoint. /R2

7. High level alarm actuates at 10% above RRS setpoint.

5.2 Immediate Operator Actions: 5.2.1 Abnormal Pressurizer Pressure

1. Ensure Pressurizer spray, and Proportional and Back-up heaters are operating properly in automatic. If not, shift spray valve controller to MANUAL and energize or de-energize heaters, whichever is applicable.

2. Ensure power operated relief valves are closed. If open, isolate by closing V-1476 and/or V-1477 (power operated relief isolation valves). Refer to OP 2-0120036,

                                       " Pressurizer Relief / Safety Valve-Off-Normal Operation".

3. Ensure SE-02-03 and SE-02-04 ( Auxiliary spray valves) are closed. If open, attempt to close using key switch. If still open, stop all Charging Pumps and isolate letdown. Refer to OP 2-0210030, " Charging and Letdown Off-Normal Operation".

4. Ensure pressure anomaly is not caused by a large rate of change of T,y,. /R2 CAUTION: During blackout conditions with the Diesel Generators supplying power, the control L bistables for the back-up heaters are not <

energized and must be bypassed. l~ . Therefore, in a blackout, the control [. ' switches on RTGB-203 must be reset and the l- Key Switch selected to PRESSURE OVERRIDE to i regain heater control. Note, however, this will only energize B1 and B4 banks of back up

heaters.

l l 1

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 ,                                           ST. LUCIE UNIT 2 0FF-NORMAL OPERATING PROCEDURE NO. 2-0120035, REVISION 2 PRESSURIZER PRESSURE AND LEVEL-OFF-NORMAL OPERATION l              i 1
                                                                                                                                .          G

5.0 INSTRUCTIONS

(Cont.) ) 5.2 (Cont.) 5.2.2 Abnormal Pressurizer Level t

1. Ensure selected RRS channel is operating properly. If~

not, shift to operable channel.

2. Ensure the back-up Charging Pump starts and letdown flow is decreasing, or the back-up Charging Pump stops and letdown flow is increasing, whichever is applicable.

3. Ensure level anomaly is not caused by a large rate of change in T ave.

5.3 Subsequent Actions 5.3.1 Check that Pressurizer Safety Valves are not leaking or have actuated by observing downstream header temperature indication and Quench Tank indications. 5.3.2 Ensure A0V-2515, A0V-2516, and A0V-2522 (Letdown Isol) are open. , 5.3.3 Ensure SE-02-01 and SE-02-02 (Charging Isol) are open. 5.3.4 Ensure LCV-2110P and LCV-2110Q (Pressurizer Level Control) are operating properly. 5.3.5 Ensure PCV-2201P and PCV-2201Q (Letdown Pressure Control) are operating properly. ^ 5.3.6 Manually start the third Charging Pump, if <onditions require. 5.3.7 Ensure Letdown Valve Limiter Bypass switch is in the NORMAL position. /R2 _,s,.e .-.m. w n.,,y,-. -~ e.+. ,- m www ~ ~ ~ . ?x. _;_-.,:,, yp,s p~qm

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ST. LUCIE UNIT 2 0FF-NORMAL OPi: RATING PROCEDURE NO. 2-0120035, REVISION 2 PRESSURIZER PRESSURE AND LEVEL-OFF-NORMAL OPERATION - l 6- 3

5.0 INSTRUCTIONS

(Cont.) 5.3 (Cont.)' 5.3.8 Compare letdown flow, charging flow, charging pump header pressure, and VCT level for indications of leaks or lifting relief valves in the CVCS system. Refer to OP 2-0120035,

                           " Charging and Letdown-Off-Normal Operation".

5.3.9 Ensure that Power Operated Relief Valve (V-1474 and 1475) hand switches are in the proper mode for existing plant conditions. NOTE: (1) Switch in NORMAL RANGE: RCS Temperature >3200F RCS Pressure >490 psia (2) Switch in LTOP: o RCS Temperature <2800F /R2 RCS Pressure <460 psia. 5.3.10 If Pressurizer level decrease cannot be immediately explained, refer to OP 2-0120035, " Excessive Reactor Coolant System Leakage". 5.3.11 With <27% level on Channel X, the 'A' Pressurizer Heater Transformer feeder breaker trips and the 'B' side 480V breakers trip. With <27% level on Channel Y, the 'B' Pressurizer Tranformer feeder breaker trips and the ' A' side 480V breakers trip. The key operated override switch placed

    ;                       in the LEVEL OVERRIDE position will reset the 480V breakers.
   ;{                       NOTE: (1) With Channel                         'X' selected, and if Channel 'X' M                                              fails low, all heaters trip. The operator must then select Channel Y and LEVEL OVERRIDE to get

_ power to the 'B' side heaters (i.e., P2, B4, B5,

f. 4 and B6). /R2 (2) With Channel 'X' selected, and if channel 'Y' fails low, all heaters trip. The operator must then select LEVEL OVERRIDE to get power to the

                                                  'A'  side heaters (i.e., P1, B1, B2, B3).

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     ,                                    ST. LUCIE UNIT 2          .

OFF-NORMAL OPERATING PROCEDURE NO. 2-0120035, REVISION 2 PRESSURIZER PRESSURE AND LEVEL-OFF-NORMAL OPERATION ( l l l

6.0 REFERENCES

.: ,7 6.1 St. Lucie Unit 2 FSAR 6.2 C-E Setpoint Guidelines 6.3 F.P.L. Training Lesson Outline #91 7.0 RECORDS REQUIRED: 7.1 Normal log entries 7.2 Applicable chart recorders 7.3 If pressure transient was caused by inadvertant auxiliary spray valve actuation, document transient per AP 2-0010134, " Component Cyclic and Transient Limits Records".

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Page 1 of 27 s EMERGENCY OPERATING PROCEDURE 2-0120040 REVISION 2 NC/C , e i w ' l l FLORIDA POWER & LIGHT COMPANY ST. LUCIE PLANT UNIT 2 EMERGENCY OPERATING PROCEDURE 2-0120040 REVISION 2 NATURAL CIRCULATION /COOLDOWN (NC/C) 1 0%d gygg.WDf3,cte o usa- .

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h ga 2 of 27 FLORIDA POWER & LIGHT COMPANY , ST. LUCIE UNIT 2 I EMERGENCY OPERATING PROCEDURE 2-0120040 REVISION 2

1.0 SCOPE

This procedure provides instructions to the operator for two conditions: A. Total loss of Reactor Coolant Pump (RCP) flow to the reactor core. B. Plant Cooldown using natural circulation flow.

2.0 SYMPTOMS

2.1 Loss of of f-site power. 2.1 Indications Start-up Transformer breakers open 2.2 Loss of or low voltage on 2.2 Indications 6.9 KV buses. 6.9 KV switchgear 2A1, 2B1 differential current trip. 6.9 KV switchgear 2A1, 2B1 UNDERVOLTAGE alarm. 2.3 RCP Overload 2.3 Indications Alarm 2.4 REACTOR COOLANT LOW FLOW channel 2.4 Indications pre-trip. Alarm 2.5 REACTOR COOLANT LOW FLOW CHANNEL 2.5 Indications trip TCBs open. CEAs inserted. i

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1 i l Page 3 of 27 NC/C

                     ,                                  ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE NUMBER 2-0120040, REVISION 2                                    m NATURAL CIRCULATION /COOLDOWN                                               i
                                                                                                                           .w 4     l

2.0 SYMPTOMS

(Cont.) 2.6 Loss of Component Cooling Water 2.6 Indications (CCW) flow to RCPs for > 10 Reactor Trip froat' loss of minutes, requiring manual trip CCW flow of all four pumps. FIA-1158, FIA-1168

     .                                                                           FIA-1178, FIA-1188 2.7  Valid SIAS-CIAS caused by low RCS        2.7   Indications pressure requiring all RCPs to be              SLAS-CLAS actuation tripped after all Control Element              Low RCS pressure Assemblies have been inserted for              CEAs inserted
     .                            5 seconds.            .

3.0 AUTOMATIC ACTION: INITIATING EVENT 3.1 Reactor coolant low flow reactor 3.1 95% of full RCS flow trip. 4.0 IMMEDIATE OPERATOR ACTION: LOCATION 4.1 Carry out immediate operator 4.1 RTGB-201, RTGB-202, RTGB-204 actions for reactor trip in accordance with Off-Normal OP 2-0030130, " Reactor Trip / Turbine Trip". bl.

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l . \ i i Paga 4 of 27 [' NC/C l ST. LUCIE UNIT 2 l EMERGENCY OPERATING PROCEDURE NUMBER 2-0120040, REVISION 2 l NATURAL CIRCULATION /COOLDOWN f' l 5.0 SUBSEQUENT ACTIONS: CHECK l L 5.1 Implement the Emergency Plan as necessary in accordance with EPIP 3100021E, " Duties of the Emergency Coordinator", l 5.2 Establish and maintain hot leg temperature (Th) at least 20*F below the saturation temperature corresponding to RCS pressure (refer to Figure 1) by doing the following:

1. Operate Pressurizer heaters or auxiliary

 .                                  spray to increase or maintain Pressurizer pressure and to provide subcooling margin.                   _

Note: If natural circulation was caused by a loss of Off-Site Power, the Backup heaters must be reset and the Backup Interlock B/P key switch must be placed in the PRESSURE position. This will allow operation of B-1 and B-4 banks of the Backup ( heaters. /R2 (

2. Increase turbine bypass or atmospheric steam dump flow to reduce or maintain RCS temperature and prevent lif, ting secondary safeties.

5.3 Verify that the Pressurizer level control system is functioning to maintain Pressurizer level. If necessary, manually operate charging and letdown to restore and maintain normal Pressurizer

    ,_                        level. If operable Charging Pumps cannot restore i                    RCS inventory and Pressurizer level, observe RCS j,

and Containment parameters for indications of a LOCA. 5.4 Restore and maintain Steam Generator levels at

         ,                    approximately 65%. When feeding the Steam Generators, use caution to avoid excessively r.?                            cooling the RCS.

t

                                ' CAUTION: Do not exceed a cooldown rate of 75'F/hr.

l A l-i I l l

Pega 5 of 27 NC/C ST. LUCIE UNIT 2 - EMERGENCY OPERATING PROCEDURE NUMBER 2-0120040, REVISION 2 NATURAL CIRCULATION /COOLDOWN (a- l n 5.0 SUBSEQUENT ACTIONS: (Cont.) CHECK / i L, y 5.5 Verify by the following indications that natural , circulation flow has been established within J approximately 15 minutes after RCPs were tripped:

1. Loop 4 T (T Tc ) less than normal full hC FJ.

powerd T (<46

     .                2. Cold leg temperatures (Tc) constant or decreasing.

3. Hot leg temperatures (Th) stable (i.e. ,

not steadily increasing). 1

4. No abnormal differences between Th RTD's and core thermocouples.

5.6 Confirm boron concentration in the RCS by sampling from as many different points as possible. 5.7 Maintain the plant in a stabilized condition based upon auxiliary plant system availability (e.g., condensate inventory). 5.8 If one or more RCPs are restored to an operable condition within 10 minutes, start an RCP in each loop if the following criteria are satisfied:

1. At least one Steam Generator is removing heat from the RCS.

  ,h.,

7; 2. Pressurizer level and pressure are responding normally to the Pressurizer Level

   -                      and Pressure Control Systems.
  <:                  3. The RCS is at least 20 F subcooled (refer
   ,                      to Figure 1).

[' L 4. The yellow PERMISSIVE light on the associated

j. pump control switch is lit.

5. No indication of voids in RCS are present.

I m.y

Prgs 6 of 27 NC/C ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE NUMBER 2-0120040, REVISION 2 NATURAL CIRCULATION /COOLDOWN l[ q i

                                                                                                                                                        !W . <- <

5.0 SUBSEQUENT ACTIONS: (Cont.)

                                                                                                                                       . CHECK L

5.9 If all four RCPs can be retu,rned to operable } , status within 10 minutes, power operation say be - - - - - resumed under the direction of the Nuclear Plant Supervisor. If RCS cooldown is required under- 'l these conditions, the cooldown_should be i accomplished using forced circulation. 1 5.10 If required to conduct a plant cooldown to shutdown cooling (SDC) conditions using natural circulation, proceed as follows:

1. Establish as stable plant conditions as J circumstances permit.

l

2. Commence boration to maintain required Shutdown Margin (SDM) during cooldown.

3. Commence an RCS cooldown by utilizing one of the following methods:

f' A. . If the Condenser is available, use the Steam Dump Bypass System and Main or Auxiliary Feedwater. B. If the Condenser is not available, use the atmospheric dump valves and Main or Auxiliary Feedwater. _[i ' 4. Continuously verify natural circulation 1 flow throughout the cooldown process. , d

5. Observe all available indicacicaa 'to determine conditions within the RCS.

       ;                                                      A. Use the QSPDS Saturation Margin Displ'ay (SMD)                                            /R2 Th, Tc, and RCS pressure to verify that

^ the RCS is subcooled..

B. Figure 1 or the nomograph on RTGB-203 should be used for comparison with the QSPDS SMD. Subcooled margin can also be determined by subtracing Th fr62 pressurizer temperature (TI-1101). /R2 C. Incore thermocouples, indicated on the QSPDS or recorded on the DDPS, can alio ba used for (j indication of Th. w .

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                 -                                                                                                         Pega 7 of 27 NC/C
                           ,                                                    ST. LUCIE UNIT 2                                     ,

EMERGENCY OPERATING PROCEDURE NUMBER 2-0120040, REVISION 2 [ "g NATURAL CIRCULATION /COOLDOWN f g .- \.l L32 5.0 SUBSEOUENT ACTIONS: (Cont.) CHECK J j f' 5.10 (Cont.) I , i 6 .- !:scablish and maintain an RCS cooldown rate of 50 F/hr (See Figure 2). The highest RCS cold leg temperature shall be plotted every 30 minutes on a copy of Figure 4. The RCS temperature and pressure shall be determined to be within the limits of Technical Specification Figure 3.4-3 at least once per 30 minutes during cooldown.

7. The' Pressurizer water phase shall be recorded on Table 1 and plotted every 30 minutes on Figure 4. This tenperature shall also be compared with the lowest spray water temperature to ensure that differential temperature does not exceed 350*F.

8. Maintain RCS pressure above and to the right of curve values shown on Figure 3.

9. During the cooldown, maintain a minimum of 20 F subcooling by the following methods (listed in order of preference):

A. Manual control of Pressurizer heaters and auxiliary spray. a-NOTE: Use only one Charging Pump. 1 B. Operating Charging or HPSI Pumps. d 6" 10. During the cooldown, maintain Pressurizer a level by the following methods (listed in order of preference):

a. Control charging end letdown.
.9: b. Operating HPSI Pumps.; 11. Monitor the available condensate l .y . ._ _ inventory and replenish the CST as required.

3 CAITTION: CONDENSATE STORAGE TANK VOLUME SHALL BE MAINTAINED PER TECHNICAL SPECIFICATION 3.7.1.3.

12. During RCS cooldown and depressurization, perform 7

the evolutions specified in Appendix C. L

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   ,;                                                                           NATURAL CIRCULATION /COOLDOWN 1                                                                                                                                                                 6-=:

I4 5.0 SUBSEQUENT ACTIONS: (Cont.) j' CHECK 5.10 (Cont.)

13. During RCS depressurization monitor for void formation in the reactor vessel upper head region. Indications of possible void formation include:

A. RCS temperature = Tsat for the corresponding RCS pressure. B. A Pres 9urizer level increase significantly greater than expected while operating auxiliary spray. C. A Pressurizer level decrease while operating charging. D. If the Pressurizer Level Control System is in automatic, an unanticipated letdown flow F.reater? than charging flow.

14. If voiding in the 2CS is indicated, perfors the following:

A. Isolate letdown by closing V-2515,' V-2516 and V-2522 (Letdown Containment Isoll.. /R2 B. Stop the RCS depressurization. C. Stop the RCS cooldown. N D. If possible, review and select one RCP in

          ,                                                              each loop for restarting.

J E. Repressurize the RCS to elialerte the void by operating Pressurizer neaters or HPSI and Charging Pumps. ,

NOTE: If the HPS". or Charging pumps are utilized to "

       ,                                                                      charge the RCS solid, the pumps should be
          ,'          1                                                       stopped after' solid RCS conditions are l             indicated.

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15. If off-site power has been lost and it becomes necessary to augment the cooldown rate, refer to Appendix E.

16. When RCS temperature reaches 325 0 F, maintain the RCS at this temperattre for an additional 20.4 hours (See Figure 2).

('-

17. Upon completion of the required " soak" period, initiate SDC in accordance with Appendix F.

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i Ptga 5 of 42 ST. LUCIE UNIT 2 / - EMERGENCY OPERATING PROCEDURE NUMBER 2-0030141 REVISION 3 : fl CONTROL ROOM INACCESSIBILITY m--)

5.0 INSTRUCTIONS

(continued) 5.1 (continued) 4 (continued) CHECK C. Open or check open isolation valves for Letdown pressure and level control valves (V-2110P and V-2201P). Isolate V-2110Q and V-2201Q. D. Proceed to the Charging Pump area and establish communications on the Sound Powered Phone circuit. 5.2 Maintain Pressurizer level at approximately 33% indicated level. 5.3 Maintain Pressurizer pressure at approximately 2100 psia. 5.4 Maintain Reactor Coolant System temperature at or below 532*F (2A cold leg temperature) by use of atmospheric steam dump and/or selective shutdown of Reactor Coolant Pumps. NOTE: Stop Reactor Coolant Pumps as required by opening the Reactor Coolant Pump breakers in the Turbine Building Switchgear Room. . 5.5 Maintain Steam Generator levels at approximately 65% indicated level by operation of the Auxiliary Feedwater Pumps and discharge valves to the Steam Generators. 5.6 Isolate Steam Generator blowdown by manually closing isolation valves at the Closed 31owdown Heat Exchangers. 5.7 When Turbine speed decreases to "0" RPM, verify that the Turning Gear Oil Pump and the turning gear are in operation 5.8 Periodically check the habitability of the Control Room and when conditions permit, reoccupy the Control Rooe. Return isolation switches to NORMAL for switches and controls that are operational and maintain the Unit at Hot Standby until a complete evaluation has been made.

Page 14.of 27 NClc ST. LUCIE UNIT 2 , EMERGENCY OPERATING PROCEDURE NUMBER 2-0120040, REVISION 2 i

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I l l ! Page 15 of 27 ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE NUMBER 2-0120040, REVISION 2 3

         ,                                  NATURAL CIRCUIATION/COOLDOWN                                     /**     (
                                                                                                        .. J y 1    i TABLE 1                                           /     ,.
                                                                                                         /    L.

DATE j s-TIME COLUMN 1 COLUMN 2 COLUMN 3

DIFFERENCE PRESSURIZER AUX SPRAY PRESSURIZER COLLHN 1 every TEMP I LINE TEMP PRESS MINUS l 30 minutes I TI-1101 I TI-2229 ' PI 1107-1/1108-1 COLINN 2 I l

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LIMITED TO < 3500 AND > 50 Operator Shift )

SHALL BE WITHIN LIMITS Operator Shift OF FIGURE 3.4-3 FOR EACH 30 MINUTE PERIOD. Operator Shift l l I

P gs 16 of 27 NC/C ST. LUCIE UNIT 2

            .           EMERGENCY OPERATING PROCEDURE NUMBER 2-0120040, REVISION 2 NATURAL CIRCULATION /C00LD0'JN                               a 4

APPENDIX A , PRECAUTIONS f

1. Natural circulation flow cannot be verified until the RCP's have stopped 2 coasting down after being tripped.

2. Due to increased loop transit times, verification of plant responses to a plant change cannot be accomplished until approximately 10 to 15 minutes following the action.

3. After a cold shutdown boron concentration is attained in the RCS, makeup water added to the RCS during the cooldown should be at least the same boron concentration as in the RCS to prevent any dilution of RCS bcron concentration.

4 Once Pressurizer cooldown has begun, Pressurizer level indication decalibration will occur (indication on the normal Pressurizer level indication will begin to deviate from the true Pressurizer level). The temperature dompensation correction curve posted on the RTGB should be used to determine true Pressurizer water level. Cold calibrated Pressurizer level indication is also available for lower Pressurizer temperatures.

5. Minimize the use of Pressurizer auxiliary spray whenever the temperature differential between the spray water and the Pressurizer is >200 F. Any auxiliary spray cycle with a temperature differential > 2000F shall be recorded in accordance with AP 0010134

6. If Pressurizer spray is not available, boron concentration in the Pressurizer may be lower than the RCS loop boron concentration. RCS boron concentration should be increased to avoid being diluted below minimum requirements by a possible Pressurizer outsurge.

7. If either the HPSI or LPSI Pumps are utilized to collapse any steam voids in the RCS by charging the system solid, the pump (s) should be stopped after solid conditions are indicated. This will minimize the potential

, for any inadvertant flowpath from the RCS back to the Refueling TJater Tank.

8. If the RCS is solid, closely monitor any makeup or draining and any system heatup or cooldown to avoid any unfavorable rapid pressure excursions. .

I

9. During all phases of the cooldown, monitor RCS temperature to avoid I exceeding a cooldown rate > 100 0F/hr.

y , ,T "

Pago 17 of 27 NC/C

       ,                                 ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE NUMBER 2-0120040, REVISION 2                   ;

NATURAL CIRCULATION /COOLDOWN , l APPENDIX A (Cont.) PRECAUTIONS

10. If cooling down by natural circulation with an isolated steam Generator, an inverted 2h T (i.e., Tc > Th) may be observed in the idle loop. This is due to a small amount of reverse heat transfer in the isolated Steam Generator and will have no ef fect on natural circulation flow in the intact Steam Generator.

11. All available indications should be used to aid in diagnosing the event since it may cause irregularities in a particular instrument reading.

Critical parameters must be verified when one or more confirmatory indications are available.

12. When establishing auxiliary feedwater flow to the Steam Generators, use Steam Generator levels as well as header flowrates to ensure each Steam Generator is receiving auxiliary feedwater.

13. Condensate inventory should be monitored periodically to ens'ure that an adequate supply is available. Makeup to the Condensate Storage Tank should be started as soon as practical. If CST level decreases to minimum required by Technical Specifications, the plant should be immediately cooled down utilizing the Fill and Drain Method (Appendix D).

o f l l l I

Ptg2 IS of 27 NC/C ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE NUMBER 2-0120040, REVISION 2

NATURAL CIRCULATION /COOLDOWN i 4

l APPENDIX B e DISCUSSION Reactor Coolant Pump forced circulation and heat transfer to the Steam Generators is the preferred mode of operation for decay heat removal whenever plant temperatures and pressures are above the Shutdown Cooling System (SDC) entry conditions. The natural circulation capability at the St. Lucie Plant provides an emergency means for core cooling using the steam generators, if the RCPs are unavailable. Natural circulation is governed by decay heat, component elevations, primary to secondary heat transfer, loop flow resistance, and voiding. Component elevations at St. Lucie Plant are such that satisfactory natural circulation decay heat removal is obtained by density differences between the bottom of the core and the top of the Steam Generator tube sheet. An additional contribution to natural circulation flowrate is the density difference obtained as the coolant passes through the Steam Generator U-tubes, but this is not required for satisfactory natural circulation. Natural circulation is assured even if the U-tubes are partially uncovered on the Steam Generator secondary side. Because of the temperature distribution in the Steam Generator U-tubes, there is no degradation in primary to secondary heat transfer as long as the secondary level covers at letic 1/3 of the tube ( height. By ensuring that the loop 21 T is less than the full power 2k T, the power-to-flow ratio is assured to be less than 1.0 during natural circulation. Satisfactory natural circulation heat removal can be obtained with either one or two Steam Generators. Unequal auxiliary feedwater to the Steam Generators will not lead to unsatisfactory natural circulation as long as all the decay heat is being removed through the Steam Generators. Assurance that the RCS is being maintained in a subcooled condition can be obtained as follows. With the QSPDS Saturation Margin Display (SMD) operating normally, the graph on RTGB-203 is used in conj unction with the SMD to eliminate dependence on a single instrument. With the SMD inoperable, reference to the nomograph utilizing Control Room indication such as hot leg temperature, Pressurizer pressure, and incore thermocouples will determine the margin to saturation. Subcooling margin can also be determined by subtracting hot leg temperature from Pressurizer temperature (TI-1101). /R2 During normal plant operation under conditions of forced circulation flow, there is only a small flow of coolant in the reactor vessel head area. During periods of natural circulation, there is little, if any, effective flow. If the RCS is cooled down using natural circulation, it is possible to generate a steam void in the reactor vessel head when saturation conditions develop. These conditions can be produced by the temperature sustained by the retained metal heat and decreased RCS pressure during cooldown. r.:

     /
                                                                                                             +.

I P:gs 19 of 27 ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE NUMBER 2-0120040, REVISION 2 NATURAL CIRCULATION /COOLDOWN , APPENDIX B (Cont.) DISCUSSION l Analyses have demonstrated that the upper reactor head region fluid can be cooled to SDC entry conditions without void formation using a hot leg I

.                    temperature cooldown rate of 50*F/hr in approximately 14.2 hours. In order to provide additional conservatism, this procedure directs that a cooldown rate                  l of about 50 F/hr to 325 F be utilized, followed by a soak at 3250 F for                        ]

20.4 hours for a total cooldown time of approximately 25.7 hours from cooldown , j initiation. (See Figure 2). The condensate supply required for this cooldown ! is 270,500 gallons. Makeup water can be supplied from the Water Treatment ! . Plant and the two 500,000 gallon City Water Storage Tanks, or . Treated Water . Storage Tank. Pumping capability from all sources can be supplied from the Diesel Generators. c An alternative to the above cooldown procedure is the fill and drain method (See Appendix D). This method may be employed should an extremely low probability event occur which could cause a loss of condensate makeup capacity or require a rapid RCS de pressurization rate. It provides for cooling of the upper reactor vessel head region by using auxiliary spray to the Pressurizer to lower RCS pressure and create a void in the upper head. Voiding in the upper head flushes hot upper head fluid into the cooler RCS where it mixes with RCS water. The water flushed out of the upper head will cause a surge of water from the RCS into the Pressurizer. The process is halted by stopping the spray. The insurge compresses the pressurizer steam space, raising the pressure, thus stopping the insurge and halting flashing in the upper head. l Charging to the RCS will then force fluid into the upper head. Mixing of

;                    colder loop unter with the hot upper head cools the upper head and causes an outsurge from the Pressurizer. The process is continued until the upper head 1                     is solid. The cycle is then repeated until RCS temperature and pressure have 1

been reduced to SDC entry conditions. t : py The above procedure has been analyzed and performed successfully twice at St. Lucie and is considered a safe, alternative method of natural circulation cooldown. z ;;

e' b

i b t > 4

Ptg2 10 of 27 ST. LUCIE UNIT 2 -

    ,         EMERGENCY OPERATING PROCEDURE NUMBER 2-0120040, REVISION 2                      g NATURAL CIRCULATION /COOLDOWN                                ,

le) APPENDIX C RCS COOLDOWN/DE-PRESSURIZATION CKECKOFF LIST INITIAL

1. At RCS pressure of 1750 psis, isolate and bypass the following transmitters:

A. FT-2212 (Charging Hde Flow Transmitter) NOTE: Close the valve on the transmitter marked HIGH SIDE, open the valve marked BYPASS, and close the valve marked LOW SIDE. B. PT-2212 (Charging Hdr Pressure Transmitter) NOTE: Close its isolation valve.

2. At RCS pressure of 1836 psia, the "SIAS Channel Activation Block Permiss" annunciator will come on. Block Channels A and B of SIAS by turning the key-interlocked switches in the BLOCK direction. /R2 NOTE: If the channels have been blocked, the two annunciators "SIAS Channel A Blocked" and "SIAS Channel B Blocked" will come on. /R2

3. At RCS pressure <1750 psia and prior to initiating SDC operations, isolate the Hydrazine Injection System by:

A. Racking out 2A Hydrazine pump (Bkr 2-41259). B. Racking out 2B Hydrazine Pump (Bkr 2-42053). C. Racking out 2A Containment Spray Pump (Bkr 2-20203). D. Racking out 2B Containment Spray Pump (Bkr'2-20407). 4 At Steam Generator pressure of 685 psig, the "MSIS Channel A

 ,               Actuation Block Permissive" and "MSIS Channel B Actuation Block Permissive" annunciators will come on. Block the MSIS channels by turning the key-interlocked switches in the BLOCK direction.                                                               /R2 NOTE: If the channels have been blocked, the two annunciators "MSIS Channel A Actuation Blocked" and "MSIS Channel B Actuation Blocked" will come on.                                 /R2

5. Prior to reaching RCS pressure of 1100 psia, unisolate and place in operation the standby Pressurizer level control and letdown pressure control valves.

Pega 21 of 27 NC/C

      ,                                 ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE NUMBER 2-0120040, REVISION 2                ,

r NATURAL CIRCULATION /COOLDOWN APPENDIX C (Cont.)

                   . RCS COOLDOWN/DE-PRESSURIZATION CHECK 0FP LIST INITIAL

6. When RCS pressure is 650 psia, de pressurize the Safety Injection Tanks to 260 psia by opening the SIT vent valves.

2A1 SIT at 260 psia 2A2 SIT at 260 psia 2B2 SIT at 260 psia 2B1 SIT at 260 psia

7. When RCS temperature is < 5000F and RCS pressure is < 1500 psia, perform the following:

A. Close the Containment Spray (CS) pump discharge valves: V-07145 V-07130 I i B. Close and' tag the manual valves in the CS header: V-07162 (A Rdr) V-07165 (B Edr) C. Close Containment Spray motor operated valves: MV-07-3 (A Rdr) MV-07-4 (B Edr) NOTE: Manual valves at present. /R2

8. When RCS cold leg temperature reaches 2800F, annunciators "PORV 1474 LTOP CONDTN SELECT LTOP" and "PORV 1475 LTOP CONDTN SELECT LTOP" will come on. /R2 l'

A. Close MOV-1476 and MOV-1477 (Relief Block Valve). /R2 B. Select LTOP on control switches for PORV-1474 and l PORV-1475, and ensure that neither PORV opens. /R2 C. Open MOV-1476 and MOV-1477. 1 l j

Pig 3 22 of 27 NC/C

          .                              ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE NUMBER 2-0120040, REVISION 2 NATURAL CIRCULATION /COOLDOWN l'?       :

APPENDIX C (Cont.) RCS COOLDOWN/DE-PRESSURIZATION CHECKOFF LIST ' : INITIAL -

9. When RCS pressure is < 275 psia rack in the breakers for and

                                              ,                                                           H then close the SIT discharge valves by placing the switch in the CLOSE position.

MV-3614 (Bkr 2-41219) } MV-3624 (Bkr 2-41311) MV-3634 (Bkr 2-42117) MV-3644 (Bkr 2-42048) /R2

10. Rack out the breakers for the SIT discharge valves.

11. When RCS temperature reaches 3250 F and RCS pressure reaches 275 psia, perform the following:

A. Remove the trip and close fuses on one HPSI pump, and tag with caution tags.

   ,,                       NOTE: Ensure the remaining RPSI pump is operable.

B. Remove the trip and close fuses on the 2A and 2B CS Pumps, and tag with caution tags.

12. When RCS temperature reaches 200 F, perform the following:

A. Remove the trip and close fuses on the remaining HPSI pump and tag with caution tags. B. Tag out one Charging Pump such that no more than two Charging Pumps are available for dilution below 200 F. Ne #

Ptg2 23 of 27 ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE NUMBER 2-0120040, REVISION 2 NATURAL CIRCULATION /COOLDOWN ft Li \ l APPENDIX D RCS FILL AND DRAIN KETHOD OF COOLING l l REACTOR VESSEL READ REGION NOTE: This method of RCS cooldown should only be employed in the event that rapid de pressurization of the RCS is required, or Condensate Storage Tank level decreases below minimus required by Tech Specs. CAUTION: DURING THIS EVOLUTION, PRESSURIZER LEVEL IS NOT A VALID INDICATOR OF RCS INVENTORY DURING TRANSIENT CONDITIONS. CARE SHOULD BE EXERCISED TO OBSERVE OTHER PARAMETERS WHICH WOULD INDICATE ANY LOSS OF RCS INVENTORY.

1. Take manual control of the charging and letdown system.

2. Lower RCS pressure by using auxiliary sprays into the Pressurizer.

3. As voiding occurs in the upper reactor vessel head, a surge of water from the RCS will cause Pressurizar level to increase rapidly. Terminate auxiliary spray prior to Pressurizer level increasing to 70% indicated level.

4 Cool the upper reactor vessel head region by charging with a Charging Pump to the RCS loop (s). Continue charging until either of the following conditions occur: 4.1 Pressurizer level decreases to 30% indi.cated level 8 4.2 The upper reactor head is charged solid. NOTE: A solid upper head condition will be evident by an increasing

 ,,                    Pressurizer level as charging to the loops is continued.

5. Repeat steps 1 through 4 above until SDC entry conditions are established.

NOTE: If the above were to prove unsuccessful, Pressurizer heaters may be used (if sufficient volume is available) to heat up the pressurizer

                 - and remove a vessel head void. This strategy should be used only as a last resort and will take an hour or more to be successful.            /R2 l

l l i I

Pegs 24 cf 27

      .                                    ST. LUCIE UNIT 2 EMERCENCY OPERATING PROCEDURE NUMBER 2-0120040 REVISION 2 NATURAL CIRCULATION /COOLDOWN APPENDIX E AUCMEEED C00LDOWN WITH THE STEAM DUMP BYPASS SYSTEM (SBCS)                                          l _

If the desired RCS cooldown rate cannot be attained, the SBCS can be used either by itself os in conjunction with the atmospheric dump valves. Since Condenser vacuun may not be available, the following actions should be taken to place the SBCS in service:

1. Call available maintenance personnel onsite to remove the target flange on a SBVS valve (preferably V-8803). <

NOTE: If no maintenance personnel are on site, call the Duty Call j Supervisor.

2. Isolate all other SBCS valves from the Condenser (except the selected valve). 1

3. Jumper low vacuum interlock in SBCS (performed by I & C.).

4 Reset the Condenser vacuum interlock by depressing the reset button (on the outside of the RRS #2 cabinet) and observe that ( the Condenser vacuum interlock yellow light goes out. NOTE: This will bypass the vacuum permissive and allow operation of V-8803 to atmosphere af ter removal of the target flange.

5. Place all SBCS controllers in MANUAL.

6. When the target flange for V-8803 has been removed and the vacuum interlock jumpered, manually adjust the controller for V-8803 to control RCS cooldown rate.

CAUTION: DO NOT EXCEED A C00LDOWN RATE },750/RR. l W

                                                                                       - . _.m.           ,

ww- < - e

1 Pego 25 of 27 ST. LUCIE UNIT 2 3

        ,           EMERGENCY OPERATING PROCEDURE NUMBER 2-0120040, REVISION 2                    '.

NATURAL CIRCULATION /C00LDOWN e t E b)- APPENDIX F INITIATION OF SHUTDOWN COOLING f NOTE: Perform bracketed steps for train "B"

1. Open HCV-3657 [3512] (SDC disch to LPSI hdr).

2. Open MV-3517 [3658] (LPSI pump supply to SDC HX).

3. Check to be open FCV-3306 [3301] (SDC HX bypass).

4 Open MV-3536 [3539] (SDC recire warmup).

5. Open MV-3456 [3457] (LPSI pump return from SDC HX).

6. Check to be open V-3767 [3205] (LPSI pump mini-flow).

7. Check to be open V-3495 and 3659 [3496 and 3660] (Mini-flow hdr stop).

8. Start 2A [2B] LPSI pump.

9. Check to be closed V-3661 (Check valve leakage drain).

10. Open HCV-3615 and 3625 [3635 and 3645] (LPSI isol).

11. Open HCV-3618 and 3628 [3638 and 3648] (Check valve leakage control).

12. Open V-3459, V-3463, and I-SE-03-2A and 2B (RWT recirc stop).

13. Check the boron concentration in the system after circulating for ten minutes. Continue circulation until the boron concentration is 1 to the concentration in the RCS.

14. Close HCV-3618, HCV-3628, [HCV-3638 and HCV-3648]

(Check valve leakage control).

15. Close V-3459, V-3463 and I-SE-03-2A and 2B (RWT recirc stop).

16. Close HCV-3615 and 3625 [3635 and 3645] (LPSI isol).

17. Close HCV-3657 [3512] (SDC disch to LPSI hdr).

18. Continue to run LPSI pump to heat the SDC system as much as pratical.

19. Verify flow on FI-3306 [3301].

20. Close V-3767 [3205]. Ensure pump minimum flow requirements are met.

21. Stop the LPSI pump.

22. Close V-3444 [3432] (LPSI pump suction from RWT).

23. Close MV-3536 [3539] (SDC recire warmup).

24 Check RCS pressure < 275 psia, then open V-3480, 3481 and 3664 [V-3651, 3652 and 3665] (SDC return valves).

25. Open HCV-14-3A [3B] (CCW to SDC HX).

26. Start 2A [2B] LPSI pump.

l 1 1

i ! Prgs 26 of 27 ( NC/C ST. LUCIE UNIT 2 % l EMERGENCY OPERATING PROCEDURE NUMBER 2-0120040, REVISION 2 NATURAL CIRCUIATION/COOLDOWN

                                                                                      .-J l

l APPENDIX F (Cont.) INITIATION OF SHUTDOWN COOLING ' I J

27. Slowly inch open HCV-3625 (3635] to bring SDC system up to temperature.

28. Adjust FIC-3306 (3301] to maximum flow in AUTO mode.

29. When temperature has stabilized, open fully HCV-3615 and 3625

                -[3635 and 3645] and adjust FIC-3306 [3301] to control at 3000 gpa in AUTO.

30. Adjust HCV-3657 [3512] to maintain desired cooldown rate.

( 1 l 1 l v

o Pego 27 of 27 NC/C ST. LUCIE UNIT 2 EMERGENCY OPERATING PROCEDURE NUMBER 2-0120040, REVISION 2 - NATURAL CIRCULATION /COOLDOWN , e

6.0 DISCUSSION

d See Appendix B

7.0 REFERENCES

7.1 CE Emergency Operating Procedure Guidelines, CEN-152 7.2 Emergency Operating Procedure 1-0120040, " Natural Circulation /Cooldown" l I 8.0 RECORDS REQUIRED: 8.1 Normal log entries

9.0 APPROVAL

Reviewed by Facility Review Group October 26 1982 Approved by J. H. Barrow ( for) Plant Manager October 26 1982 Revision 2 Reviewed b7 FRG 2. L 19 % Approved by b4 Le et h Plant Manager /f/ 4_ ? A ) 19/ Il l (. 1 "LAST PAGE" ' EP 2-0120040 Rev. 2 Total No. of Pages E O P+w-e-

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1 Peg) 1 of 3 FLORIDA POWER & LIGHT COMPANY ST. LUCIE UNIr 2 0FF-NORMAL OPERATING PROCEDURE NO. 2-0360030 . REVISION 1

1.0 TITLE

i -i Operational Requirements for the Emergency Cooling Water Canal 2.0 REVIEN AND APPROVAL: Reviewed by Facility Review Group March 25 1983 Approved by J. H. Barrow ( for) Plant Manager April 4 1983 Revision 1 Reviewed by FRG M% t- 19 S 3 Approved by A / ctA e +[ /blantManager 81?M s i 19 / 7

3.0 PURPOSE

The Emergency Cooling Water System consists of a canal connecting Big Mud Creek to the intake in front e,f the circulating water intake structure. This secondary source will be used only in the event that the primary source from the Atlantic Ocean becomes inoperable. For normal operation the barrier wall across the Ultimate Heat Sink (URS) separates the intake canal from Big Mud Creek. An operable UHS ensures that sufficient cooling capacity is available to either (1) provide normal cooldown of the facility, or (2) to mitigate the effects of accident conditions within acceptable limits.

4.0 SYMFr0MS

4.1 Intake structure low water level (Annunciators LA-1 and LB-1) 4.2 Intake local level indication less than -9 ft. FOR IUFORMATION ONLY This document is not centrolled B f

                                                              . o ore use, verify inicrmation with a cont rolled document.

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Ptg3 2 of 3 . ST. LUCIE UNIT 2 c, OFF-NORMAL OPERATING PROCEDURE NO. 2-0360030 REVISION 1 / ., OPERATIONAL REQUIREME WS FOR EMERGENCY COOLING WATER CANAL 'O -

5.0 INSTRUCTIONS

Ji:

5.1 The Nuclear Plant Supervisor shall determine the need to operate the

/*[

L, Emergency UBS valves. j 5.2 Insure Unit 1 Control Room is aware of low water level condition. 5.3 The Nuclear Plant Supervisor shall notify the Duty Call Supervisor. 5.4 The turbine generator and associated equipment will be shut down' per OP 2-0030125.

    ,                5.5 The Circulating Water System shall be shut down per OP 2-0620020.

5.6 Implement the Emergency Plan as necessary in accordance with EPIP 3100021E, " Duties of the Emergency Coordinator." 5.7 The reactor shall be shut down and placed in mode 3. NOTE: The reactor shall be in mode 3 within one hour of reaching an intake water level of less than -10.5 f t. 5.8 Within 12 hours after placing the reactor in mode 3, the URS barrier I valves I-SE-37-1 and I-SE-37-2 shall be opened providing cooling water from Big Mud Creek. Verify by alarm (E-44) and valve position indicator lights.

NOTE: In the event barrier valves fail to open on signsl, first A

instruct Unit 1 Control Room to attempt to open them. If valves still fail to open, they can be opened by placing an air assist on the top of the piston per steps 5.8.1.1 through 5.8.1.5. The required tubing, connectors and regulator will j be available at the valve or from the I & C Department. 5.8.1 Operation Procedure i 5.8.1.1 Insure valve has an open signal before attaching i hose so upper piston void can intake air preventing a vacuum from forming. 5.8.1.2 Attach hose to upper piston connection and air -

, supply.

.. 5.8.1.3 Unlock and open supply air valve (V-37221 or

V-37220, BA 3 Key).

5.8.1.4 Regulate 1-2 psig intervals until valve opens (normally <5 psig opens valve). _ 5.8.1.5 Close supply air valve, vent upper piston and remove hose. 5.9 Continue reactor cooldown per OP 2-0030127.

                                                                                                                      /R1 I

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                                                                                                               -            ?_

Pcgs 3 of 3 ST. LUCIE UNIT 2 j OFF-NORMAL OPERATING PROCEDURE NO. 2-0360030, FI7ISION 1 OPERATIONAL REQUIREMENTS FOR E4ERGENCY COOLING WATER CANAL t

                                                                                                 #'        i

6.0 REFERENCES

I

__J} ,9 6.1 St. Lucie Unit 2 FSAR, Section 9 /R1 6.2 Unit 2 Technical Specificatica Section 3.7.5.1 jf

                                                                                           ;                1 6.3 m reulating Water Systen Normal Operation, OP 2-0620020 6.4 Turbine Shutdown, OP 2-0030125 6.5 Reactor Cooldown from Mode 3, OP 2-0030127                                          - '

7.0 RECORDS REQUIRED: 4 7.1 Normal log entries s v a 4 . e i e h 4

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FLORIDA POWER & LIGHT COMPANY (O g

             -                                                         ST. LUCIE UNIT 2                                                                             i 0FF-NORMAL OPERATING PROCEDURE 1-0410030 REVISION 1 q ,c .

1.0 TITLE

                                                                                                I FO R Ie.u    e- nwn
                                                                                                           . .wP '"          ~-

EPSI 0FF MORMAL OPT.RA! ION This document is ut conheW " N M l I verify information with a cenns,w >,msM. 2.0 REVIEW AND 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 6-25' 19 O Approved by ) N $ # < , /% [ "E M lant Manager _ E'M d 19 [s] 3.0 PURPOSE AND DISCUSSION:

3.1 Purpose

This procedure provides instructions for various off normal situations that could occur when High Pressure Safety Injection (HPSI) is required.

'~

3.2 Discussion

1. No single active component failure will prevent the system from performing its design function. However, manual action may be required to maintain maximum system effectiveness.

2. The minimum components required to function are one HPSI pump, one LPSI pump, and three Saf.aty Injection Tanks.

3. All motor and air operated valves required to operate during safety injection have been designed to fail in such a position as to ensure failsafe operation.

1 4 HPSI pu aj s for each flow path are located in separate water tigM Jow : ta ensure that a succion or discharge line break vt I at - sable both flow paths. i

5. here enats a possibility that during operation witE CCS

      .                                        pressure 11836 psia a loss of coolant accident could occur with f                                      safety injection blocked. Should conditions indicate an LOCA,                        >

safety injection will have to be ~ manually initiated. '

/R1

6. If;the HPSI system has been automatically actuated because of a lov, pressure condition, it carst remain in operation until:

        ,                  1                   A. 20 subcooling exists in the ' Reactor- Coolant System and pressurizer pressure and lev p control are established, and

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                                    /.         3.-The operator has determin.td that no LOCA conditions exist.

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Pags 2 of 4 ST. LUCIE UNIT 2 0FF-NORMAL OPERATING PROCEDURE NUMBER 2-0410030, REVISION 1 HPSI - 0FF NORMAL OPERATION

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4.0 SYMPTOMS

4.1 Safeguards room sump high level annunciation 4.2 Area radiation monitor alarm - l 4.3 Visual indication of safety injection system leakage 4.4 Visual indication of pump or valve malfunction at the RTGB 4.5 No indication of safety injection loop flow

   ,              4.6  Indication of excessive safety injection loop flow i

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Ptga 3 of 4

                                                     .ST. LUCIE UNIT 2 OFF-NORMAL OPERATING PROCEDURE NUMBER 2-0410030, REVISION 1 RPSI - 0FF NORMAL OPERATION

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5.0 INSTRUCTIONS

I f ! 5.1 Immediate Automatic Action: None 5.2 Immediate Operator Action: 5.2.1 Observe plant parameters; determine nature of the problem, take appropriate subsequent action. 5.3 Subsequent Operator Action: 5.3.1 Failure of motor or air operated valves to operate on SIAS:

1. Manually operate valves.

5.3.2 Rupture of pump suction line upstream of pump suction isolation valve:

1. Close affected header NV suction valve (RWT or containment sump).

2. Stop affected HPSI and LPSI Pumps.

             ,                5.3.3  Rupture of pump discharge line between pump discharge 1_                      isolation valve and SI header valves:

1. Close affected header isolation valve.

2. Stop pump.

3. Close pump suction or discharge isolation valve.

5.3.4 Rupture of pump discharge line between header isolation valve and loop isolation valves:

         ,                           1. Close header isolation valve.

2. Close affected loop isolation valve (s).

3. Stop affected pump.

5.3.5 Rupture of SI line between loop isolation valve and RCS:

1. Close affected loop isolation valve.

J 5.3.6 No indication of flow to loop (s): 1. Verify isolation valves in correct position. I 5.3.7 Indication of LOCA with safety injection signal blocked:

1. Manually initiate safety injection either by unblocking signal or with manual pushbuttons.

2. Verify actuation.

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Pegs 4 of 4 ST. LUCIE UNIT 2 0FF-NORMAL OPERATING PROCEDURE NUMBER 2-0410030, REVISION 1 HPSI - 0FF NORMAL OPERATION ,.* I; [j

6.0 REFERENCES

*) / .

6.1 CE P&ID E13172-310-130, Safety Injection System, Sheet 1 6.2 CE P&ID E13172-310-131, Safety Injection System, Sheet 2 t

7.0 RECORDS REQUIRED: 7.1 Normal log entries (m 4 i 1 e (_. l JP9 *'

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Ptgn 1 of 3 . FLORIDA POWER & LIGHT COMPANY ST. LUCIE UNIT 2 0FF-NORMAL OPERATING PROCEDURE NO. 2-0640030 ' REVISION 1 _

1.0 TITLE

0R niF0EI'F 339 UU Sd 3dore use ICW SYSTEM - 0FF NORMAL OPERATION ,, a e to ad d:c"*' #*j 2.C REVIEW AND APPROVAL: Reviewed by Facility Review Group January 25 1983 Approved by C. M. Wethy Plant Manager January 25 1983 Revision 1 Reviewed b FRG & 19 N Approved by dM ctX s rt. [ k ant Manager %- N 196 3 V 3.0 PURPOSE AND DISCUSSION: 1 3.1 This procedure provides instructions to be followed when a malfunction or failure in the Intake Cooling Water (ICW) System l occurs. 3.2 While one ICW Pump and header are sufficient to meet minimum requirements, redundancy has been lost when one header and/or ICW Heat Exchanger is out of service. Maximum effort should be made to restore out of service equipment to normal. 3.3 An inoperable Intake Cooling Water loop shall be made operable within 72 hours or be in at least Hot Standby within the next 6 hours and in Cold Shutdown within the following 30 hours.

4.0 SYMPTOMS

4.1 Intake Cooling Water headers low pressure (E-30) [ 4.2 Intake Cooling Water pumps motor overload alarms (E-6) (E-7) (E-8) 4.3 Intake Cooling Water Pumps motor overload trip alarm (E-6) (E-7) (E-8) 4.4 High temperature alarms on CCW and TCW Heat Exchanger outlets (S-13) (E-37) 4.5 High differential pressure on TCW basket strainers, SS-21-4A and SS-21-4B (E-32) 4.6 High differential pressure on CCW basket strainers, I-SS-21-1A and I-SS-21-1B (E-31) 4.7 Visible evidence of line rupture 4.8 Low Flow Alarm on CCW Heat Exchangers outlet (saltwater) (S-3) (S-5)

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                                                                                                                                                                                             /R1

Pega 2 of 3 ST. LUCIE UNIT 2 0FF-NORMAL OPERATING PROCEDURE No. 2-0640030, REVISION 1 O ICW SYSTEM - 0FF NORMAL OPERATION f k il.->

5.0 INSTRUCTIONS

5.1 Immediate Automatic Action: l None i 5.2 Immediate Operator Action: None 5.3 Subsequent Operator Action:

1. If ICW Pumps discharge low pressure alarm is associated with high flow through a CCW Heat Exchanger, TCW Heat Exchanger, or OBCS Heat Exchanger, instruct the operator to take manual 4

control of the affected flow control valve and reduce flow to normal operating flows.

2. Upon loss of an ICW Pump, line up the standby pump to the affected header and start the standby pump.

3. Blocked CCW Heat Exchanger basket strainer (SS-21-1 A or SS-21-1B).

a. Open affected strainer bypass valve (v21187 or V21234).

b. Back wash or clean the affected strainer.

NOTE: While backwashing, observe FIS-21-9A or FIS-21-9B to ensure adequat. ICW flow on header.

c. Return system to normal lineup.

4 Blocked TCW heat exchanger basket strainer (SS-21-4A or SS-21-4B).

a. Open V-21215 (TCW Hx inlet tie).

b. Backwash or clean the affected strainer.

c. Recurn system to normal lineup.

Ptg3 3 of 3 ST. LUCIE UNIT 2 OFF-NORMAL OPERATING PROCEDURE NO. 2-0640030, REVISION 1 h ICW SYSTEM - 0FF NORMAL OPERATION I j U(* 3

5.0 INSTRUCTIONS: (Cont.)

\ #

i 5.3 (Cont.)

5. Rupture of ICW line.

 ,                      a.       Deter:nine if affected portion of line can be isolated.

Isolate affected portion if possible and align standby pu:np to unaffected header. Proceed to tie headers together where applicable to keep both heat exchangers in service.

b. An inoperable Intake Cooling Water loop shall be made operable within 72 hours or be in a least Hot Standby within the next 6 hours and in Cold Shutdown within the following 30 hours.

6.0 REFERENCES

6.1 Ebasco P & ID 2998-G-082 l 6.2 St. Lucie Unit 2 Technical Specification 3.7.4 ! 7.0 RECORDS REOUIRED: 7.1 Nor:nal log entries l 4

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Paga 1 of 49

       .                                                                                                        l FLORIDA POWER & LIGHT COMPANY ST. LUCIE UNIT 2 0FF-NORMAL OPERATING PROCEDURE NO. 2-0960030                        ,
                                                                                                     *  )'

i REVISION 1 i ;

1.0 TITLE

J DC GROUND ISOLATION . 2.0 REVIEW AND APPROVAL: Reviewed by Facility Review Group March 9 1983 Approved by J. H. Barrow ( for) Plant Manager April 1 1983 Revision 1 Reviewed by FRG _- 6d J A 19 B3 Approved by [ /zA e p [bant Manager -I'D 19 M

3.0 PURPOSE

3.1 Provide instructions for isolating a DC system ground without affecting plant operation.

3.2 Discussion

This procedure shall be used as a guideline for DC ground location and isolation. The Nuclear Plant Supervisor and the Nuclear Watch Engineer shall use any section, in any order, as they deem necessary to maintain the plant stability and to insure that no limiting condition for operation from the Standard Technical Specification is violated. 4.0 PRECAUTIONS AND LIMITS: Maintain two way radio communication between control center and operating point.. Verify control center operator is observing ground light on RTGB-201 when isolating circuits to minimize time each circuit is switched off. 5.0 RELATED SYSTEM STATUS: None

6.0 REFERENCES

6.1 Ebasco Power Distribution Motor Data 2998-B-335 series drawings 6.2 Ebasco Control Wiring Diagrams 2998-3-327 series drawings 7.0 RECORDS REQUIRED: Plant Work Order for the grounded circuits \ F031.170ESTWI This document is not conf verify information withro!!ed. Before use OCLY a controlled documen,t. e.e.

Page 2 of 49 l ST. LUCIE UNIT 2 #,% ! OFF-NORMAL OPERATING PROCEDURE No. 2-0960030, REVISION 1 t DC GROUND ISOLATION ()'f y

8.0 INSTRUCTIONS

,/

f y i 8.1 If the ground appears on a bus which is tied to the 2A, 2B, or 2C DC f bus, then proceed to Step 8.1.1. If the ground is on a separate ! isolated bus, then proceed to Step 8.1.5. 8.1.1 Energize the standby battery charger and verify that all the 125V DC buses are being supplied from their respective chargers. 8.1.2 Open or verify open the following breakers in 125V DC bus 2AB power panels: 8.1.2.1 Brk. 2-60310,125V DC bus 2C 8.1.2.2 Brk. 2-60335, 125V DC bus 2A 8.1.2.3 Brk. 2-60333, 125V DC bus 23 8.1.3 The 2AB 125V DC bus is now isolated from the 2A and 2B 125V DC buses, and the 2C 125V DC bus is isolated from the 2AB 125V DC bus. Determine which DC bus is grounded. 8.1.4 Return the 125V DC system to its original lineup. 8.1.5 Proceed to the appropriate section as follows: 125V DC bus 2A ground: Section 8.2 125V DC bus 2B ground: Section 8.3 125V DC bus 2AB ground: Section 8.4 125V DC bus 2C ground: Section 8.5 S.2 Isolate a ground on 125V DC bus 2A as follows: 8.2.1 Breaker 2-60101 (PSL 1/PSL 2 Inst. Air Tie Valves PCV-18.5 and PCV-18.6) 8.2.2 Breaker 2-60102 RTGB-201 and RTGB-203

1. RTGB-201 CWD 800 F1 and F2 CWD 720 F3 and F4 CWD 883 F33 and F34 CWD 711

2. RTGB-203 CWD 396 F31 and F32 CWD 130 F35 and F36 CWD 121 F39 and F40 CWD 98 F43 and F44 CWD 138 F33 and F34 CWD 103

 -                     F45 and F46 CWD 97
                                                                                        /R1

l l l Pags 3 of 49 ST. LUCIE UNIT 2

  .         OFF-NORMAL OPERATING PROCEDURE NO. 2-0960030, REVISION 1 DC GROUND ISOLATION

8.0 INSTRUCTIONS

(Cont.) 8.2 (Cont.) 8.2.3 Breaker 2-60103 (480V Swgr. 2A-1): Momentarily open and E- ] reclose breaker. If ground does not clear, proceed to Section 8.2.4 If the ground did clear, proceed to 480V LC Swgr. 2Al and perform the following: 3.2.3.1 At the rear of each compartment listed below, momentarily remove and replace the close and trip circuit fuses for the listed breakers: COMPT. BREAKER EQUIPMENT 2B 2-40103 Main Feed - Station Service Transformer 3C 2-40107 Station Air Compressor 5B 2-40111 Hypochlorite MCC 2A10 3C 2-40112 Main Transformer 2A Cooling Source #1 6A 2-40114 Main Transformer 2B Cooling Source #2 6B 2-40115 Turbine Area MCC 2A1 6C 2-40116 Intake Area MCC 2A3 7B 2-40119 Turbine Area MCC 2C 7C 2-40120 Turbine Bldg. Crane #2 7D 2-40121 Rad Waste MCC 2A2 8.2.4 Breaker 2-60104 (6900V Swgr. 2A1)

1. COMPT BREAKER EQUIPMENT 01 2-30101 Incoming fdr aux trans 2A (2W87) 02 2-30102 Incoming fdr S/U trans (2W89) standby 2A 03 2-30103 Feedwater pump 2A 04 2-30140 RCP 2A1 05 2-30105 RCP 2B2

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Paga 4 of 49 ST. LUCIE UNIT 2 0FF-NORMAL OPERATING PROCEDURE NO. 2-0960030, REVISION 1 DC CROUND ISOLATION f l em I E b E"""

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(Cont.) 8.2 (Cont.) 8.2.5 Breaker 2-60105 (480V Swgr. 2A-2): Momentarily open and reclose breaker. If the ground did not clear, proceed to j Section 8.2.6. If the ground did clear, proceed to 480V Swgr. 2A-2 and perform the following: 8.2.5.1 At the rear of each compartment listed below, momentarily remove and replace the close and trip circuit fuses for the listed breakers: COMPT. BREAKER EQUIPMENT 4B 2-40211 2HVE-10A 4C 2-40212 CEA MG Set 2A 5A 2-40214 Spare /R1 8.2.6 Breaker 2-60106 (4160V Swgr. 2A-2): Momentarily open and reclose breaker. NOTE: Annunciator window B4 and 312 will alarm. If the ground did not clear, proceed to Section 8.2.7. If the ground did clear, proceed to 4160V Swgr. 2A-2 and perform the following: 8.2.6.1 Open cubicle 1 and momentarily remove and replace the close and trip circuit fuses for breaker (1W86) 2-20101. If the ground did not clear, momentarily remove and replace the 4160V 2A-2 undervoltage fuses. Close cubicle 1. /R1 8.2.6.2 Open cubicle 2 and momentarily remove and replace the close and trip circuit fuses for breaker 2-20102. If the ground did not clear, somentarily remove and replace the startup standby transformer 2A lockout relay fuses. NOTE: Annunciator window B12 will annunciate. Close cubicle 2. 8.2.6.3 Open cubicle 10 and momentarily remove and replace the close and trip circuit fuses for breaker ^ 2-20110. If the ground did not clear, momentarily remove and replace the 4160V Swgr. 2A-2 differencial relay fuses. NOTE: Annunciator window B4 will alarm.

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l ST. LUCIE UNIT 2 0FF-NORMAL OPERATING PROCEDURE NO. 2-0960030, REVISION 1 A ' DC GROUND ISOLATION / i 0 Pb t

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8.0 INSTRUCTIONS

(Cont.) 8.2 (Cont.) 8.2.6 (Cont.) _l {_ _ 8.2.6.4 Open the cubicles listed below and momentarily remove and replace the close and trip circuit fuses for the listed breakers: CUBICLE BREAKER EOUIPMENT 03 2-20103 CWP 2A1 04 2-20104 CWP 2B1 05 2-20105 SGBD MCC IB-9 Transformer 06 2-20106 TCWP 2A 07 2-20107 Condensate Pump 2A 08 2-20108 Her. Drain Pu=p 2A 09 2-20109 Feed to 4160V Swgr. 2A3 8.2.7 Breaker 2-60107 (125V DC PP218): Momentarily open and reclose breaker. See Appendix E for load list. 8.2.8 Breaker 2-60108 (Test Station for 6.9KV Swgr. 2A1 and 2B1): Momentarily open and reclose breaker. 8.2.9 Breaker 2-60109 (Comp. Cooling Water Surge Tank): Momentarily open and reciose breaker. NOTE: LCV-14-1 (CCW surge tank inlet) f ails closed. 8.2.10 Breaker 2-60110 (Unit Aux XFKER 2A Control Cabinet): Momentarily open and reclose breaker. NOTE: Annunciator window C-48 will alarm. 8.2.11 Breaker 2-60111 (DC LP 227): Momentarily open and reclose breaker. See Appendix E for load list. 8.2.12 Breaker 2-60112 (S/U Standby K7MER 2A Control Cabinet): Momentarily open and reclose breaker. NOTE: Annunciator B-21 will alarm. 8.2.13 Breaker 2-60113 (480V Pzr. Her. Bus 2A3 Sudden Pressure Relay Ckt.): Momentarily open and reclose breaker. l

Paga 6 of 49 ST. LUCIE UNIT 2

         ,        OFF-NOFliAL OPERATING PROCEDURE NO. 2-0960030, REVISION 1 DC GROUND ISOLATION                                 fp,h

8.0 INSTRUCTIONS

(Cont.) 8.2 (Cont.) 8.2.14 Breaker 2-60114 (Main XFMER 2A Control Cabinet): l 1 Momentarily open and reclose breaker. NOTE: Annunciator window C-36 will alarm. _ 8.2.15 Breaker 2-60115 (RTGB-205 and 203): Momentarily open and reclose breaker. See Appendix E for load list, FF1 to FF20 (RTGB-205), FF1 to FF12 (RTGB-203). 8.2.16 Breaker 2-60116 (4160 Swgr. 2A-3): Momentarily open and reclose breaker. NOTE: Annunciator windows B4, 15, 18, 19, 54, 56, 57 and 59; E-46; G-44, R-28 and 30, S-47, 57 and X-8 will alarm. If the ground did not clear, proceed to Section 8.2.17. If the ground did clear, proceed to 4160V Swgr. 2A-3 and perform the following: 3.2.16.1 Open cubicle 6 and momentarily remove and replace the close and trip circuit fuses for breaker 2-20206, CCWP 2A. NOTE: Annunciator window S-51 will alarm. If the ground did not clear, momentarily remove and replace the 4160V Swgr. 2A-3 differential relay fuses. NOTE: Annunciator window B-4 will alarm. 8.2.16.2 Open cubicle 11 and momentarily remove and replace the close and trip circuit fuses for breaker 2-20211, Diesel Generator 2A. NOTE: Annunciator window B-56 will alarm. If the ground does not clear, momentarily remove and replace the 4160V Swgr. 2A-3 load shedding relay fuses. NOTE: Annunciator window B-15 will alarm. 8.2.16.3 Open the cubicles listed below and momentarily remove and replace the close and trip circuit fuses for the listed breakers. NOTE: Listed t annunciator windows will alarm. ANN. WINDOW COMPT. BREAKER EQUIPMENT R-30 1 2-20201 HPSI Pump 2A R-28 2 2-20202 LPSI Pump 2A S-47 3 2-20203 Cont. Spray 2A B-59 4 2-20204 Feed to Prz. Her. 2A3 X-8 5 2-20205 CEDM Cooling Fan 2HVE-21 A E-46 7 2-20207 ICWP 2A l B-54 8 2-20208 Feed to 4160V 2AB B-19 9 2-20209 Supply from 4160V 2'2 B-47 10 2-20210 Feed to 4bOV LC 2A2/2A5 G-44 12 2-20212 AFWP 2A l /R1

Prga 7 of 49 ST. LUCIE UNIT 2 gg 0FF-NORMAL OPERATING PROCEDURE NO. 2-0960030, REVISION 1

i l DC GROUND ISOLATION 1

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      '8.0 INSTRUCTIONS: (Cont.)

8.2 (Cont.) 8.2.17 Breaker 2-60117 (DG 2A Cont. Pnl.): Momentarily open and reclose breaker. NOTE: This breaker is the feed to the annunciator circuit on 2A DG. 8.2.18 Breaker 2-60118 (Cont. Transfer Panel 2A): Momentarily open and reclose breaker. 8.2.19 Breaker 2-60119 (RTGB-206): Momentarily open and reclose breaker. NOTE: See Appendix E for load list. 8.2.20 Breaker 2-60120 (Static Inv. Cab. 2A): Remove Static Inverter 2A from service by performing Section 8.3 of Operating Procedure 2-0970020. 8.2.21 Breaker 2-60121 (IRS 2A Valve SE-07-3A): Momentarily open and reclose breaker. NOTS: Valve SE-07-3A will open. 8.2.22 Breaker 2-60122 (DG 2A Control Panel): Momentarily open and reclose breaker. NOTE: Annunciator window B-36 and B-26 on RTGB-201 and B-3 on DG 2A local annunciator will alarm. If the ground did not clear, proceed to step 8.2.23. /R1 8.2.23 Breaker 2-60123 (480V Swgr. 2A-2): Momentarily open and reclose breaker. NOTE: B-29 will alarm. If the ground does not clear, proceed to 8.2.4 If the ground did clear, proceed to 480V Swgr. 2A-2 and perform the following: 8.2.23.1 Open compartment 6A (instrumentation) and momentarily

   .s                         remove and replace the 2A-2 Swgr. UV relay fuses.

NOTE: Annunciator window B-29 will alarm. Close compartment 6A. I l l l l i

Pags 8 of 49 ST. LUCIE UNIT 2 0FF-NORMAL OPERATING PROCEDURE NO. 2-0960030, REVISION 1 DC GROUND ISOLATION f t L fl

8.0 INSTRUCTIONS

(Cont.) / 8.2 (Cont.) J L 1 8.2.23 (Cont.) 8.2.23.2 At the rear of each compartment listed below, momentarily remove and replace the close and trip circuit fuses for the listed breakers: COMPT. BREAKER EQUIPMENT 1A 2-40201 Spare IB 2-40202 MCC 2A-7 1C 2-40203 MCC 2A-5 1D 2-40204 Spare . 5B 2-40215 MCC 2A9-1A SC 2-40216 Spare SD 2-40217 Charging Pump 2A 6B 2-40219 Main Feed 6C 2-40220 480V LC 2AB 8.2.24 Breake r 2-60124 (Relief Valve V-1475): Momentarily open and close breaker. 8.2.25 Breaker 2-60125 (Battery Charger 2A): Momentarily open and close breaker. 8.2.26 8.2.27 Breaker 2-60127 (HVCB): Momentarily open and reclose breaker. See Appendix E for load list, FF25 to FF36. 8.2.28 Breaker 2-60128 (Spare) 8.2.29 Breaker 2-60129 (Static Inverter Cabinet 2C): Remove static inverter 2C from service by performing Section 8.3 of Operating Procedure 2-0970020. 8.2.30 Breaker 2-60130 (Control Transfer Panel 2A): Momentarily open and reclose breaker. 8.2.31 Breaker 2-60131 (Plt. Aux. Cont. Ann. - LA): Momentarily open and reclose breaker.

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Pags 9 of 49 ST. LUCIE UNIT 2 OFF-NORMAL OPERATING FROCEDURE NO. 2-0960030, REVISION 1 DC GROUND ISOLATION

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(Cont.) 8.2 (Cont.) 8.2.32 Breaker 2-60132 (DC PP-238): Momentarily open and reclosel breaker. See Appendix E for load list. 8.2.33 Breake r 2-60133 (Bus MA): This breaker trips reactor trip breakers TCB-1 and TCB-5. Verify that reactor trip breakers TCB-1 through 8 are closed. 8.2.33.1 Inform the Control Room that TCB-1 and TCB-5 will be tripped. Momentarily open and reclose breaker 2-60133. NOTE: Annunciator windows K-9 and K-10 will alarm. If the ground did not clear, proceed to Section 8.2.34 If the ground did momentarily clear, proceed to reactor trip switchgear and perform the following: 8.2.33.1.1 Momentarily remove and replace the close and trip fuses for TCB-1. 8.2.33.1.2 Momentarily remove and replace the close and trip fuses for TCB-5. 8.2.33.2 Verify that reactor trip breakers TCB-1 through 8 are closed before proceeding with remainder of procedure. 8.2.34 Breaker 2-60134 (Bus MC): This breaker trips reactor trip breakers TCB-3 and TCB-7. Verify that reactor trip breakers TCB-1 through TCB-8 are closed. 8.2.34.1 Inform the Control Room that TCB-3 and TCB-7 will be tripped. Momentarily open and reclose breaker 2-60134 NOTE: Annunciator windows K-4 and K-5 will alarm. If the ground did not clear, proceed to Section 8.2.35. If the ground did momentarily clear, proceed to reactor trip switchgear and perform the following: 8.2.34.1.1 Momentarily remove and replace the close and trip fuses for TCB-3. 8.2.34.1.2 Momentarily remove and replace the close and trip fuses for TCB-7. 8.2.34.2 Verify that reactor trip breakers TCB-1 through 8 are closed before proceeding with remainder of procedure.

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Pags 10 of 49 ST. LUCIE UNIT 2 0FF-NORMAL OPERATING PROCEDURE NO. 2-0960030, REVISION 1 [ . DC GROUND ISOLATION 1 .e )

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8.0 INSTRUCTIONS : (Cont.) 8.2 (Cont.) 8.2.35 Breaker 2-60135 (ISO CAB "SA"): Verify SS in isolation panel SA are in " normal" position. Momentarily open and close breaker. 8.2.36 Breaker 2-60136 (Charging Line 2A2 Valve I-SE-02-02) 8.2.37 Breaker 2-60137 (DG 2A Cont. Pnl. Exc.) 8.2.38 Breaker 2-60138 (Iso. Pol. 21-Charging Line Iso. Valve V-2523) 8.2.39 Breaker 2-60139 480V LC 2A5. 8.2.40 Breaker 2-60140 125V DC PP-254. 8.2.41 Breaker 2-60141 Spare. 8.2.42 Breaker 2-60142 Spare. 8.2.43 Momentarily remove and replace the DC bus 2A under-voltage relay fuses in DC bus 2A. 8.2.44 Momentarily remove and replace the DC bus 2A ground relay fuses in DC bus 2A.

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Paga 11 of 49 ST. LUCIE UNIT 2 0FF-NORMAL OPERATING PROCEDURE NO. 2-0960030, REVISION 1 g DC GROUND ISOLATION g em e jl 2

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(Cont.) 8.3 Isolate a ground on 125V DC bus 23 as follows: 8.3.1 Breaker 2-60201 (Hydrogen Panel): Momentarily open and u ] reclose breaker. NOTE: The annunciator horn at the Ho control panel must bd reset locally.

8.3.2 Breaker 2-60202 (LP-228): Momentarily open and reclose breaker. See Appendix F for load list. 8.3.3 Breaker 2-60203 (Turbine Oil 2H Seal Oil and Htr. Drain Fire Protection): Momentarily open and reclose breaker. 8.3.4 Breaker 2-60204 (S/U Standby XFMER 2B Cont. Cab.): Momentarily open and reclose breaker. 8.3.5 Breaker 2-60205 (480V Pzr. Her. Bus 233 Sudden Press. Relay Ckt.): Momentarily open and reclose breaker. 8.3.6 Breaker 2-60206 (Main KR{ER 2B Cont. Cab.): Momentarily open and reclose breaker. 8.3.7 Breaker 2-60207 (480V Swgr. 2B2 cont. Cab.): Momentarily open and reclose breaker. If the ground did not clear, proceed to Section 8.3.8. If the ground did clear, proceed to 480V Swgr. 2A-2 and perform the following: 8.3.7.1 At the rear of each compartment listed below, momentarily remove and replace the close and trip fuses for the listed breakers: COMPT. BREAKER EOUIPMENT 3A 40505 Spare /R1 4B 40510 2HVE-103 ', 4C 40511 CEA MG Set 2B 8.3.8 Breaker 2-60208 ( Aux. XFMER 23 Control Cab.): Momentarily 6 open and reclose breaker. 8.3.9 Breaker 2-60209 (Excitation Swgr.): Do Not Operate this breaker. Proceed to 8.3.10. If ground cannot be cleared after completion of 8.3, notify Electrical Department that I the ground is apparently in the excitation switchgear. I l NOTE: Operation of breaker will trip generator on loss of DC. l l i 1 1 i l I

I Page 12 of 49 ST. LUCIE flNIT 2 l 0FF-NORMAL OPERATING PROCEDURE NO. 2-0960030, REVISION 1 DC CROUND ISOLATION L""'

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(Cont.) 8.3 (Cont.) 8.3.10 Breake r 2-60210 RTGB-201 CWD 800 ,.. 1 8.3.11 Breaker 2-60211 (480V Swgr. 28-1): Momentarily open and reclose breaker. If ground does not clear, proceed to Section 8.3.12. If ground did clear, proceed to 480V LC Sugr. 2B-1 and perform the following: 8.3.11.1 At the rear of each compartment listed below, momentarily remove and replace the close and trip fuses for the listed breakers: COMPT. BREAKER EQUIPMENT 1B 2-40402 Main IFXER 2A Cooling Source #2 1D 2-40404 MCC #23-2 23 2-40406 MCC #23-10 2C 2-40407 Main IFXER 2B Cooling Source #1 3A 2-40409 MCC #2C 3B 2-40410 MCC #2S-1 3C 2-40411 MCC #2B-3 6B 2-40419 Main Feed 6C 2-40420 2B1-2A1 Tie 8.3.12 Breaker 2-60212 (6900V Swgr. 23-1): Momentarily open and reclose breaker. If ground did not clear, proceed to Section 8.3.13. If ground did clear, proceed to 6900V Swgr. 2B1 and perform the following: 8.3.12.1 Open the cubicles listed below and momentarily remove and replace the close and trip circuit fuses for the listed breakers: CUBICLE BREAKER EOUIPMENT t 01 2-30205 Reactor Coolant Pamp 2B1 02 2-30204 Reactor Coolant Pump 2A2 03 2-30203 Feedwater Pump 2B l-j l l l

Pags 13 of 49 ST. LUCIE UNIT 2 0FF-NORMAL OPERATING PROCEDURE 50. 2-0960030, REVISION 1 DC GROUND ISOLATION p e i

8.0 INSTRUCTIONS

(Cont.) l 8.3 (Cont.)

[ 8.3.13 Breaker 2-60213 (PP-219): Momentarily open and reclose L breaker. See Appendix G for load list. ; 8.3.14 Breaker 2-60214 (4160V Swgr. 2B-2): Momentarily open and reclose breaker. NOTE: Annunciator windows A4 and A15 will ala rm. If the ground does not clear, proceed to Section 8.3.15. If the ground did clear, proceed to 4.16KV Swgr. 2B-2 and perform the following: 8.3.14.1 Open cubicle 10 and momentarily remove and replace the close and trip fuses for breaker 2-20301. If the ground did not clear, momentarily remove and replace 4.16KV Swgr. 2B2 undervoltage fuses. Close cubicle 10. 8.3.14.2 Open cubicle 9 and momentarily remove and replace the close and trip fuse for breaker 2-20302. If the ground did not clear, momentarily remove and replace the startup standby transformer 2B lockout relay fuses. NOTE: Annunciator window A15 will alarm. Close cubicle 9. 8.3.14.3 open cubicle 1 and momentarily remove and replace the close and trip fuses for breaker 2-20310. If the ground did not clear, momentarily remove and replace the 4.16KV Swgr. 2B2 differential relay fuses. NOTE: Annunciator window A4 will alarm. 3 8.3.14.4 Open the cubicles listed below and momentarily remove and replace the close and trip circuit fuses for the listed breakers: CUBICLE BREAKER EOUIPMENT 02 2-20309 Feed to 4160V Bus ?B3 03 2-20308 Her. Dr. Pump 2B 04 2-20307 Condensate Pump 2B 05 2-20306 TCWP 23 07 2-20304 CWP 2B2 08 2-20303 CWP 2A2

L l k- Page 14 of 49 ST. LUCIE UNIT 2 OFF-NORMAL OPERATING PROCEDURE No. 2-0960030, REVISION 1 DC CROUND ISOLATION : g is

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(Cont.) 8.3 (Cont.) 8.3.15 Breaker 2-60215 (480V Swgr. 2B-2): Momentarily open and reclose breaker. If the ground did not clear, proceed to Section 8.3.16. If the ground did momentarily clear, proceed to 480V Swgr. 2B2 and perform the following: 8.3.15.1 Open compartment 2A (instrumentation) and momentarily remove and replace the 2B2 swgr. undervoltage relay fuses. Close compartment 2A. 8.3.15.2 At the rear of each compartment listed below, momentarily remove and replace the close and trip fuses for the listed breakers: COMPT. BREAKER EOUIPMENT 2C 2-40504 2B2-2AB Tie 3B 2-40506 MCC 28-9 2RVS-1C 3C 2-40507 Spare /R1 3D 2-40508 Charging Pump 2B 6A 2-40514 Reactor Crane #2 7A 2-40518 Spare /R1 7B 2-40519 MCC 2B-7 7C 2-40520 MCC 2B-5 7D 2-40521 Spare /R1 8.3.16 Breaker 2-60216 (Aux. Spray Valve ISE-02-4): Momentarily open and reclose breaker. NOTE: Valve fails closed, loses indication. 8.3.17 Breaker 2-60217 (IRS Valve 23 SE-07-3B - 100W): Momentarily open and reclose breaker. I

4 Paga 15 of 49 ST. LUCIE UNIT 2 0FF-NORMAL OPERATING PROCEDURE No. 2-0960030, REVISION 1 . DC GROUND ISOLATION O

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(Cont.) 8.3 (Cont.) 8.3.18 Breaker 2-60218 (4.16KV Swgr. 2B-3): Momentarily open and _ _; reclose breaker. NOTE: Annunciator windows A4, A15, A52, AS4, A56, A57, A59. E47, G45, RS2, RS6, R59 and S52 will alarm. If the ground did not clear, proceed to Section 8.3.19. If the ground did clear, proceed to 4.16KV Swgr. 23-3 and perform the following: 8.3.18.1 Open cubicle 4 and momentarily remove and replace the close and trip fuses for breaker 2-20404 NOTE: Annunciator window S52 will alarm. If the ground did not clear, momentarily remove and replace the 4.16KV Swgr. 2B-3 differential relay fuses. NOTE: Annunciator window A4 will alarm. 8.3.18.2 Open cubicle 1 and momentarily remove and replace the close and trip fuses for breaker 2-20401. NOTE: Annunciator window A56 will alarm. If the ground did not clear, momentarily remove and repalce the 4.16KV Swgr. 2B-3 load shedding relay fuses. NOTE: Annunciator window A15 will alarm. 8.3.18.3 Open the cubicles listed below and momentarily remove and replace the close and trip fuses for the listed breakers. NOTE: Listed annunciator windows will alarm. CUBICLE BREAKER ANN. WINDOW EOUIPMENT 2 2-20402 A-57 Feed to 2B2 480V LC 3 2-20403 A-59 Feed to 2B3 480V Press. Htrs. 5 2-20405 R-56 HPSI Pump 2B 6 2-20406 R-59 LPSI Pump 2B 7 2-20407 R-52 Cont. Spray Pump 2B 8 2-20408 CEDM Cooling Fan 2HVE-21B 9 2-20409 A-54 Feed to 2AB 4160V 10 2-20410 E-47 ICWP 2B 11 2-20411 A-52 Supply from 2B2 4160V 12 2-20412 G-45 Aux. Feed Water Pump 2B 8.3.19 Breaker 2-60219 (DG 2B Control Panel) f 1 I

Paga 16 of 49 ST. LUCIE UNIT 2 #

                                                                                          #%s OFF-NORMAL OPERATING PROCEDURE NO. 2-0960030, REVISION 1              ,

g.) I DC CROUND ISOLATION } a

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INSTRUCTIONS: (Cont.) 8.3 (Cont.) 8.3.20 Breaker 2-60220 (Static Inverter Cab. 23): Remove inverter 23 from service by performing Section 8.3.1 through 8.3.8 of Operating Procedure 2-0970020. 8.3.21 Breaker 2-60221 (DG 2B Cont. Panel). Momentarily open and reclose breaker. NOTE: Annunciator window A-36 and A-26 on RTGB-201 and 8-3 on DG 23 local annunciator will alarm. If the ground did not clear, proceed to step 8.3.22. /R1 8.3.22 Breaker 2-60222 (Static Inverter Cab. 2D): Remove inverter 2D from service by performing Section 8.3.1 through 8.3.8 of Operating Procedure 2-0970020. 8.3.23 Breaker 2-60223 (Plant Aux. Cont. BD Ann.-LB): Momentarily open and reclose breaker. 8.3.24 Breaker 2-60224 (Cont. Transfer Panel 2B): Momentarily open and reclose breaker. 8.3.25 Breaker 2-60225 (2B Battery Charger): Momentarily open and reclose breaker. 8.3.26 Breaker 2-60226 (Space) _. 8. 3. 2J Breaker 2-60227 (RTGB-203, 205): Momentarily open and

     .                   reclose breaker. See Appendix H for load list.

8.3.28 Breaker 2-60228 (DC PP-239): Momentarily open and close

   ,                     breaker. See Appendix I for load list.

8.3.29 Breaker 2-60229 480V LC 2B5. /R1 8.3.30 Breaker 2-60230 (DG Control Panel): Momentarily open and reclose breaker. l 4 i

Paga 17 of 49 ST. LUCIE UNIT 2 0FF-NORMAL OPERATING PROCEDURE NO. 2-0960030, REVISION 1 DC CROUND ISOLATION g w b k

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(Cont.) 8.3 (Cont.) 8.3.31 Breaker 2-60231 (RTCB-206): Momentarily open and reclose 8 ') g breaker. See Appendix J for load list. 8.3.32 Breaker 2-60232 (Letdown Control Isol. Valve V-2522): Momentarily open and reclose breaker. Valve will fail closed, lose indication. 8.3.33 Breaker 2-60233 (Bus MB): Thic breaker trips reactor trip breakers TCB-2, TCB-6 and TCB-9. Verify that reactor trip breakers TCB-1 through 8 are closed. 8.3.33.1 Inform the Control Room that TCB-2, TCB-6 and TCB-9 will be tripped. Momentarily open and reclose breaker 2-60233. NOTE: Annunciator windows K-1 and K-2 will alarm. If the ground did not clear, proceed to Section 8.3.34 If the ground did momentarily clear, proceed to reactor trip switchgear and perform the following: 8.3.33.1.1 Momentarily remove and replace the close and trip fuses for TCB-2. 8.3.33.1.2 Momentarily remove and replace the close and trip fuses for TCB-6. 8.3.33.1.3 Momentarily remove and replace the close and trip fuses for TCB-9. 8.3.33.2 Verify that reactor trip breakers TCB-1 through 8 are closed before proceeding with remainder of procedure. 8.3.34 Breaker 2-60234 (Bus MD): This breaker trips reactor trip breakers TCB-4 and TCB-8. Verify that reactor trip breakers TCB-1 through TCB-8 are closed. 8.3.34.1 Inform the Control Room that TCB-4 and TCB-8 will be tripped. Momentarily open and reclose breaker 2-60234. NOTE: Annunciator windows K-12 and K-13 I will alarm. If the ground did not clear, proceed l co Section 8.3.35. If the-ground did momentarily clear, proceed to reactor trip switchgear and perform the following: t 8.3.34.1.1 Momentarily remove and replace the _ close and trip fuses for TCB-4 8.3.34.1.2 Momentarily remove and replace the close and trip fuses for TCB-8.

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Paga 18 of 49 ST. LUCIE UNIT 2 0FF-NORMAL OPERATING PROCEDURE NO. 2-0960030,, REVISION 1 DC CROUND ISOLATI02 I (1 ( i _4 8

8.0 INSTRUCTIONS

(Cont.) / d? 8.3 (Cont.) 8.3.34 (Cont.) ! 8.3.34.2 Verify that reactor trip breakers TCB-1 through 8 are closed before proceeding with remair. der of procedure. 8.3.35 Breaker 2-60235 (Charging Line 231 Valve I-SE-02-01): Momentarily open and reclose breaker. (* missing C'4D) 8.3.36 Breaker 2-60236 (Relief Valve V-1474): Momentarily open and reclose breaker. Valve fail closed, lose indication, window E-12 will alarm. 8.3.37 Breaker 2-60237 (Iso. Cab. "SB"): Momentarily open and reclose breaker. 8.3.38 Breaker 2-60238 (HVCB): Momentarily open and reclose breaker. See Appendix K for load list. 8.3.39 Breaker 2-60239 Spare. 8.3.40 Breaker 2-60240 125V DC PP-255.- 8.3.41 Breaker 2-60241 Spare. 8.3.42 Breaker 2-60242 Spare.

 ,           8.3.43 Momentarily remove and replace the DC bus 2B undervoltage relay fuses in DC bus 2B.

8.3.44 Momentarily remove and replace the DC bus 23 ground relay fuses in DC bus 2B.

8.3.45 If the ground has not cleared at tbts point, notify Electrical Maintenance Department 1that the ground is~ apparently in the gecerator excitation swgr. Do Not Operate , breaker 2-60209 Main Generator will trip on loss of DC. .!

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i Paga 19 of 49 ST. LUCIE UNIT 2 l OFF-NORMAL OPERATING PROCEDURE NO. 2-0960030, REVISION 1 ],8 ,g k I DC CROUND ISOLATION 3 . ) '

8.0 INSTRUCTIONS

(Cont.) 8.4 Isolate a ground on the 2AB 125V DC Bus as follows: 8.4.1 Breaker 2-60301 Spare. 8.4.2 Breaker 2-60302 (RVCB): Momentarily open and reclose breaker. See Appendix M for load list. 8.4.3 Breaker 2-60303 (RTGB-205): Momentarily open and reclose breaker. See Appendix N for load list. 8.4.4 Breaker 2-60304 (RTGE-205): Momentarily open and reclose breaker. See Appendix 0 for load list. 8.4.5 Breaker 2-60305 (Spare) 8.4.6 Breaker 2-60306 (Spare) 8.4.7 Breaker 2-60307 (Spare) 8.4.8 Breaker 2-60308 (Spare) 8.4.9 Breaksr 2-60309 (SUPS Cabinet): Remove the vital AC inverter from service by performing steps 8.4.1 through 8.4.12 of Operating Procedure 2-0970021. 8.4.10 Breaker 2-60310 (125V DC tie to 2C bus) should be open. 8.4.11 Breaker 2-60311 Spare. 8.4.12 Breaker 2-60312 (Iso. Term Cab. 3): Momentarily open and

 ,                                     reclose breaker.

8.4.13 Breaker 2-60313 (Spare) 8.4.14 Breaker 2-60314 (Spare) 8.4.15 Breaker 2-60315 (Spare) 8.4.16' Braaker 2-60316 (Spare) 8.4.17 Breakar-2-60317 (Spare) 8.4.18 Breaker 2-60318 (Spare) 8.4.19 Breaker 2-60319 Space.

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9 , _ ST. L"CIE UNIT 2

                   ' f<'*                     OFF-NORMAL OPERATING PROCEDURE NO. 2-0960030, REVISION 1 DC CROUND ISOLATION y

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I e 8.0 TNSTRUCTIONS: ( Cont. ) 8.4 ,(Cont.) L h ] 8.4.20 Breaker 2-60320 (Aux. FWP Steam Valve MV-08-3): Verify 2C AFWP is not running. Momentaril q open and reclosa ' breaker. 8.4.21 Breaker 2-60321 (4160V Swgr. 2A3)b Momentaril;.open and close breaker. NOTE: Annunciator windows A5, A54, B54, E91, 553 and R57 will alars. If ground did nat clear, proceed to Section 8.4.22. If ground did clear,' proceed to 4160V Swgr. 2AB and perform the folicwing G 8.4.21.1 Open cubicle 1 and momentarily remove and repla'ce the close and trip fuses for breaker 2 '40501 (spare cubicle).

                                                                                                                                                /R1 Open the cubicles listed below and momentarily remove and repisce the close and trip circuit fusos for the listed breakers, s

CUBICLE BREAKER EQUIPMENT

                                                                '02            2-20502                CCWP 2C 03             2,-20503                 ICWP 2C 04            ,2-20504                 Feed from 4.16KV Bus 233 05             2-20505                 7eedffrom 4.16KV Bus 2A3 t* ;

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Ptg3 21 of 49 l ST. LUCIE UNIT 2 1 0FF-NORMAL OPERATING PROCEDURE NO. 2-0960030 REVISION 1 l DC GROUND ISOLATION ,%p l

8.0 INSTRUCTIONS

(Cont.) 8.4 (Cont.) 8.4.22 Breaker 2-60322 (480V Swgr. 2AB): Mcutentarily open and b J reclose breaker. If the ground did not clear, proceed to Section 8.4.23. If the ground did clear, proceed to 480V Swgr. 2AB and perform the following: 8.4.22.1 Open compartment 2A (instrumentation) and momentarily remove and replace the 480V swgr. 2AB undervoltage relay fuses. Close compartment 2A. 8.4.22.2 At the rear of each compartment listed below, momentarily remove and replace the close and trip fuses for the listed breakers: COMPT. BREAKER EQUIPMENT 1B 2-40702 Bus Tie to 480V Swgr. 2A-2 1C 2-40703 MCC 2AB 2B 2-40706 Bus Tie to 480V Swgr. 2B-2 2C 2-40707 Charging Pump 2C 8.4.23 Breaker 2-60323 (Isol. Cab. "SAB"): Momentarily open and reclose breaker. 8.4.24 Breaker 2-60324 (PP-240): Momentarily open and reclose breaker. See Appendix R for load list. 8.4.25 Breaker 2-60325 (Spare)

   ,            8.4.26 Breaker 2-60326 (Battery Charger 2AB): Momentarily open and reclose breaker.

8.4.27 Breaker 2-60327 Spare. 8.4.28 Breaker 2-60328 Spare. 8.4.29 Breaker 2-60329 Spare. 8.4.30 Breaker 2-60330 Spare.

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Pago 22 of 49 ST. LUCIE UNIT 2 0FF-NORMAL OPERATING PROCEDURE NO. 2-0960030 REVISION 1 DC CROUND IS0tATION f r i

8.0 INSTRUCTIONS

(Cont.) 8.4 (Cont.) 8.4.31 Moisentarily remove and replace the DC Bus 2AB undervoltage w. _ % relay fuses in DC Bus 2AB. 8.4.32 Momentarily remove and replace the DC Bus 2AB ground relay fuses in DC Bus 2AB. I 1 l

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FCg3 23 of 49 ST. LUCIE UNIT 2 0FF-NORMAL OPERATING PROCEDURE No. 2-0960030, REVISION 1 DC GROUND ISOLATION [& \.

8.0 INSTRUCTIONS

(Cont.) 8.5 Isolate a ground on 125V DC Bus 2C as follows: 8.5.1 Breaker 2-60601 (Spare) 8.5.2 Breaker 2-60602 (125V DC PP-133 SGBTF): Momentarily open and reclose breaker. (Ensure Unit 1 feed is closed.) 8.5.3 Breaker 2-60603 (4160V Tie Swgr. 2A4): Monentarily open and close breaker. 0 8.5.4 Breaker 2-60604 (4160V Tie Swgr. 2B4): Momentarily open and reclose breaker. 8.5.5 Breaker 2-60605 (Battery Charger 2C): Momentarily open and reclose breaker. 8.5.6 Breaker 2-60606 (Security Fire Detection Rad. Vital AC Cabinet): Place the SUPS on its alternate source prior to opening 2-60606. Return SUPS to normal operation if ground did not clear. /R1 8.5.7 Breaker 2-60607 (Air Side Seal Oil Backup Pump): Verify pump is not running. Momentarily open and reclose breaker. 8.5.8 Breaker 2-60609 (Emergency 011 Pump): Verify pump is not-running. Momentarily open and reclose breaker. /R1 NOTE: Annunciator window C-56 will alara. l j

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Page 24 of 49 ST. LUCIE UNIT 2 0FF-NOR!!AI, OPERATING PROCEDilRE No. 2-0960030, REVISION 1 .-. DC CROUND ISotATION ([ d APPENDIX E ', t V I PP 218 CKT. 7 RTCB- ,, TB CWD REV. O f'" 8.2.7 Bkr. 6010 FUSE NO. I,INE NO. LOAD CONDITIONS REQUIRED TO DE-ENERGIZE t CWD TAG TITLE l Ckt. I 1004 Isol. Term. Cab. 1 Loss of many Class Ann. I Ckt. 3 1701 480V LC 2A5 Ckt. 4 929 akr. Test Sta. 2A2-2B2 Out of service 4160V Swgr. l l Ckt. 5 740 L.P. lit r. 2-3A and 2-4 A Reverse current valves will attempt to Reverse Current Valves close against flow, flow holds open Ckt. 6 1696 PACB-2 Ckt. 7 740 ti.P. litr. 2-5A Reverse Reverse current valves will attempt to Current Valves close against flow, flow holds open Ckt. 8 1696 PACB-2 Ckt. 9 638 Aux. FW P2C I-SE-08-1 Local Control Station l Ckt. 13 1213 Sequence of Events Window F-37 will alara Recorde r-Annunciator Ckt. 14 1638 RA-ST-1 . Ckt. 15 Feeder to Re. 26-5 Ckt. 17 Feeder to Ra. 26-6 4

/R1

Page 25 of 4 ST. LI!CIE UNIT 2 OFF-NORttAL OPERATING PROCEDLIRE NO. 2-0960030, REVISION 1 ,! DC GROllND ISOIATION APPENDIX E DC LP 227 CKT. II RTGB- TB CWD REV. O FIISE NO. LINE No. II)AD CONDITIONS REQUIRED TO DE-ENERGlZE CWD TAG TITLE Ckt. 1I Control Roors Emerg. No effeet Lighting l d f I

f-~ ,'t . Page 26 o Af'i l 1 ST. LUCIE UNIT 2 e OFF-NORMAL OPERATING PROCEDURE.No. 2-0960030, REVISION 1 DC CROUND ISOLATION APPENDIX E PP DC 2A CKT. 15 RTGB- 205 TB T8 CWD 645 REV. O FUSE NO. LINE NO. LOAD CONDITIONS REQIIIRED TO DE-ENERGlZE CWD TAG TITLE F1 FlP 157 Letdown Containment Fail closed, lose indication F2 F2N Isolation Valve F3 i F3P 159 V-2505 RCP Controlled Bleedoff Fall closed, lose indication F4 F4N Isolation F5 FSP 159 V-2650 Boric Acid Tank 2A Fall closed, lose indication F6 F6N Recire. F7 F7P 159 V-2651 Boric Acid Tank 2B Fall closed, lose indication F8 F8N Recirc.

           'F9          F9P            163     FCV-2210Y   Boric Acid Flow           I Fall closed, lose indication F10         F10N Fil         FilP           194     V-2523      Charging Line Isol Valve   Fall open, lose indication F12         F12N 1

F13 F13P 176 I-SE-02-02 Charging Line 2A Valve Fail open, lose indication, manually reset F14 F14N 1-SE-02-02 its-1-SE-02-02 RTGB-205 FIS I FISP 563 V-6341 RDT Cont. Isol. Valve Fall closed, lose indication, manually , F16 F16N reset HS-6341 RTGB-205 F17 F17P 564 V-6750 Waste Gas Cont. Isol. Fall closed, lose indication, manually FIS FISH Valve reset IIS-6750 RTGB-205

   -        F19         F19P           576     LCV-07-IIA  Reactor Sump Isol. Valve   Fall closed, lose indication, must l        F20         F20N                                                          open/ reset CS-1/576 when fuse restored                     l to re-open F21         F21P          1528     I-SE-05-lE  SI Tanks Sample Valve      Fall closed, lose indication

5 Page 27 o w s,, ST. LUCIE UNIT 2 4 0FF-NORMAL OPERATING PROCEDURE NO. 2-0960030 REVISION 1 f* DC CROUND ISOLATION J APPENDIX E PP DC 2A CKT. 19 RTCB- 206 TB T2 CWD 646 REV. 0 8.2.19 j I Bkr. 2-66.113 J FIJSE NO. LINE NO. LOAD CONDITIONS REQlIIRED TO DE-ENERGlZE CWD 1 TAG TITLE FI FlP 202 HCV-14-8A Comp. Cool. Wtr. Normal Fall closed, lose indication F2 F2H Supply ?ldr. Isol. Valve F3 F3P 202 HCV-14-8B Comp. Cool. Wtr. Normal Fail closed, lose indication F4 F4N Supply lidr. Isol. Valve F5 PSP 211 IISE-14-3A Comp. Cool. Wtr. from Fall open, lose indication, reset to close F6 F6N llCV-14-3A F7 F7P 212 IICV 1 Comp. Cool. Wtr. to Fall closed, lose indication, reset to F8 F8N i Reactor Cool. Pumps open F9 l F9P 212 HCV-14-2 Comp. Cool. Wtr. from Fall closed, lose indication, reset to F10 F10N Reactor Cool. Pumps open l Fil FilP 242 I- SE-03-1 B SI Tank 2A2 Fill and Fall closed, lose indication F12 Drain F13 F13P ' 242 1-SE-03-I A SI Tank 2A2 Fill and Fall closed, lose indication F14 F14N l Drain FIS F15P 256 V-3612 St Tank 2A2, N2 to SI Fail closed, lose indication Fl6 F16N Tank Fl7 F17P 256 V-3622 St Tank 2A1, N2 to SI Fall closed, lose indication FIS F18N l Tank.

 "Fl9         F19P              280     IICV-3618           Check Valve Leakage       Fail closed, lose indication F20         F20N                                          Drain to RWT F21         F21P              281     HCV-3628            Check Valve Leakaga       Fail closed, lose indication F22         F22N                                          Drain to RWT l                                                                                                                   I

ST. LUCIE. UNIT 2 1 0FF-NORtlAL OPERATING PROCEDlRE No. 2-0960030 REVISION I h DC CR0l!ND ISOLATION r APPENDIX E PP DC 2A CKT, 19 RTCB- 206 T3 T2 CWD 646 REV. 0 8.2.19 I Bkr. 60119 FUSE HO. LINE No. LOAD CONDITIONS REQtilRED TO DE-ENERGlZE CWD 1 TAG TITLE ' 1 F23 F23P 289 FCV-07-IA Containment Spray Valve Fall open, lose indication , F24 ' F24N l l 4 F25 F25P 312 IICV-08-I A Hain Steam Isol. Valve Lose indication, valve will stay open if F26 F26N air supply is uninterrupted F27 l F27P 317 HCV-18-1 Instrument Air Isolation Fall closed, lose indication F28 F28N Valve F29 F29P 319 FCV-23-3 Steam Cen. 2A Blowdown Fail closed, lose indication F30 FF30N Isol. Valves F31 F31P 319 FCV-23-5 Steam Cen. 2A Blowdown Fall closed, lose indication F32 ' F32N Isol. Valves F33 F33P 320 FCV-26-2 Containment Radiation Fall closed, lose indication F34 F34N 320 Sample Isol. Valves F35 , F35P 461 FCV-23-7 Steam Cen. 2A and 28 Fall closed, lose indication F36 l F36N FCV-23-9 Blowdown Sample Isol. Valves (A) F37 F37P 536 HCV-25-1 Drain Valves to Reactor Fail closed, lose indication F38 F38N thru 25-7 Auxiliary Bldg. Sumps F39 F39P 578 V-5200 Primary Coolant Sample Fall closed, lose indication I F40 F40N Valve

                        )                       .

{ F41 F41P 579 V-5201 Press Surge Line Sample Fall closed, lose indication F42. F42N Valve 1

Page 29 of AS<"**%w ST. LIICIE UNIT 2 4 OFF-NORMAL OPERATING PROCEDURE NO. 2-0960030, REVISION I [~h DC GROUND ISOLATION APPENDIX E PP DC 2A CKT. 19 RTCB- 206 TB T2 CWD 646 REV. 0 . 8.2.19 Bkr. 60119 FUSE No. LINE NO. LOAD CONDITIONS REQllIRED TO DE-ENERGIZE CWD i TAG TITLE l F43 F43P 580 V-5202 Press. Sta. Space Fail closed, lose indication, reset to F44 F44N Sample Valve open F45 T45P 1520 V-3495 Minimus Flow Isol. Fail closed, lose indication, valve F46 F46N Valve re-opens when fuse restored F47 i F47P 1519 To RWT Val. St Tank Test Line Fall closed, lose indication, reset F48 F48N 1-SE-03-2A 11S-1519-1 to re-open F49 F49P 1519 V-3572 Hot Leg HPSI Line Check Fall closed, lose indication, reset F50 F50N Valve Leakage Drain 11S-3572 to re-open Loop 2A F51 F51P 243 V-3613 SI Tank 2A2 Vent Fail closed, lose indication F52 F52N F53 F53P- 243 V-3623 SI Tank 2Al Vent Fall closed, lose indication

                                       *F54>             F54N l

F55 ' F55P 1528 I-SE-05-lE SI Tanks Sample Valves Fail closed, lose indication, reset F56 F56N llS-03-1 to re-open F57 F57P 247 V-3737 SI Tank 2B1 F58 1 F58N F59 F59P 247 V-3739 SI Tank 2B2 F60 F60N F61 F61P 655 HCV-09-IA Main Feedwater Isolation Window P-6 will alarm F62 F62N Valve F63 F63P -671 HCV-09-2A Hain Feedwater Isolation Window P-26 will alarm 1 F64 i F64N l

Page 30 of 49 ST. LUCIE UNIT 2 s ,, OFF-NORMAL OPERATING PROCEDURE No. 2-0960030, REVISION 1 lg DC GROUND ISOLATION ] APPENDIX E PP DC 2A CKT. 27 RTGB- IIVCR TB Wl-LTA CWD 1239 REV. 0 , . 8.2.27 ,s ., Bkr. 601 1 .' FUSE NO. LINE NO. LOAD CONDITIONS REQUIRED TO DE-ENERGI* CWD ! TAG l TITLE i F25 F25P 511 FCV-25-1 Reactor Containment I Fall closed, lose indication

,     F26        F26N                       FCV-25-3      Purge 1801. Valves FCV-25-5 i     F27        F27P        '

317 HCV-18-1 Instrument Air F28 F28N Isolation Valve F29 F29P 1160 FCV-25-20 continuous containment / Fail closed, lose indication F30 F30N liydrogen Purge Isol. Valve F31P4 1239 FCV-25-7 Containment Vacuum Fail closed, lose indication F32N4 Relief Valve F33 F33P 1164 FCV-25-26 Continuous containment / Fall closed, lose indication F34 F34N Hydrogen Purge 1801. Valve F35 F35P 455 Fuel Pool Rad. Fuel llandling Building Ventilation is 1 F36 F36N Monitoring shifted to Shield Building ventilation Fans / Shield Building Ventilation is isolated I

/R1

Page 31 of 49 ST. LUCIE UNIT 2 ' 0FF-NORt1AL OPERATING PROCEDURE NO. 2-0960030 REVISION 1 '3

                              .                                                                    DC CROUND ISOLATION                                          ,

j APPENDIX E PP DC PP-238 CKT. 32 RTCB- TB CWD REV. 0 8.2.32 Bkr. 6013 D FUSE NO. LINE NO. LOAD CONDITIONS REQUIRED TO DE-ENERGi7. % CWD i TAG TITLE ' r. i Ckt. I l 2-60651 l l Spare j l Ckt. 2 l 2-60652 l 640 l l Reflash Module RA-T-4 l Window F-42 will alarm l l Ckt. 3 l 2-60653 l 640 l l Reflash Module RA-T-5 l Window C-4 will alarm l l Ckt. 4 l 2-60654 l 640 l l Reflash Module RA-T-6 l Window G-24 will alarm l l Ckt. 5 l 2-60655 l l l Spare l l l Ckt. 6 l 2-60656 l1564 l l Reflash Module RA-RAB-17l Windows R26, P23, PIS, F37, E30 will alarm l l Ckt. 7 l 2-60657 l Spare l l Spare l l l Ckt. 8 l 2-60658 l 986 l l Reflash Module RA-T-7 lWindowB-7willalarm l l Ckt. 9 l 2-60659 l1551 l lReflashModuleRA-RAB-2lWindowB-29willalarm l l Ckt. 10 l 2-60660 l Spare l l Spare l l l Ckt. 11 l 2-60661 l Spare l l Spare l l l Ckt. 12 l 2-60662 l 131 l lReflashModuleRA-RAB-3lWindowB-9willalarm l l Ckt. 13 l 2-60663 l Spare l l Spare l l l Ckt. 14 l 2-60664 l 584 l lReflashModuleRA-RAB-6lWindowN-6willalaru l l Ckt. 15 l 2-60665 l1007 l l Reflash Module RA-T-9 lWindowE-32willalarm l l Ckt. 16 l 2-60666 l Spare l l Spare l l l Ckt. 17 l 2-60667 l 990 l lRA-RAB-19 l l l Ckt. 18 l 2-60668 l 188 l lReflashModuleRA-RAB-8lWindowN-23willalarm l j' l Ckt. 19 l 2-60669 l1634 l l I-SE-09-5 Relay (B2C 73)l l l 'l I I I I I l 1 I i l I l

/R1

Page 32 of 4 % ST. LUCIE UNIT 2 '$ OFF-NORMAL OPERATING PROCEDURE NO. 2-0960030, REVISION 1 ' DC GRollND ISOLATION i j APPENDIX E i , PP DC PP-238 CKT. 32 RTGB- TB CWD REV. 0 8.2.32 i Bkr. 60132 -- FUSE NO.' LINE NO. LOAD CONDITIONS REf}llIRED TO DE-ENERGI7.E CWD I TAG TITLE Ckt. 20 2-60670 1001 Reflash Module RA-RAB-Il Window B-20 will alarm Ckt. 21 2-60671 1701 RA-RAB-25 22 2-60672 Spare Spare 23 2-60673 Ckt. 24 2-60674 596 Reflash Hodule i RA-RAB-28 O

/R1

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Page 33 of ~*N ST. LUCIE UNIT 2 I 0FF-flORMAL OPERATING PROCEDURE NO. 2-0960030, REVISION I. DC GROllND ISOLATION APPENDIX F PP DC LP-228 CKT. 02 RTCB- TB CWD REV. O "

8. 3. 2

Bkr.f.-60202 FUSE NO. l.INE NO. LOAD CONDITIONS REQllIRED TO DE-ENERGIZE CWD 1 TAG I TITLE 1

Ckt. 1 N/A Control Rooni Daergency No effect without loss of A/C lighting DC Lighting 9

l l t Page 34 of 49 ST. LUCIE UNIT 2 OFF-NORMAL OPERATING PROCEDURE NO. 2-0960030, REVISION 1 gmg [ DC GROUND ISOLATION f , l l APPENDIX G PP DC PP-219 CKT. 13 RTCB- TB CWD REV. 0

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8.3.13 Bkr. 60213 _ FUSE NO. LINE NO. LOAD CONDITIONS REQlIIRED TO DE-ENERGIZE

;                                              CWD l       TAG                      TITI.E                                                          l l                 l                                                                           l PP-238                 Ckt. 23             444                        Rad. Ilonttoring            Closes sample isolation valve I-SE-26-1 Panel No. I                 to component coollag water radiation monitoring skid #1 (RS-26-1) l Ckt. 1             l 2-60551           l1694      l                l PACB-2                     l                                               l Ckt. 2                2-60552              931                        Breaker Test Station for    Test Station out of service 2A3 and 2B3 4160V l                               Switchgear               I                                                l Ckt. 3                2-60553             1579*                       RTGB-201, 203, 205 and      Backup Power Supply llCVB Annunciators Ckt. 4                2-60554              933                        Breaker Test Station for    Test Station out of service l                               2AB 4160V Switchgear Ckt. 5                2-60555              740      LP litr 2-3B      Reverse Current Valves      Will close reverse current valve and 2-4B     I                             l  SC-10-3B and 48 l Ckt. 6             l 2-60556          l1004 l                     l Isolation Term Cabinet 2l Loss of many annunciators                         l Ckt. 7                2-60557              587                        Waste Management Local      Backup Power Supply Annunciator ("Y")

l Ckt. 8 l 2-60558 l1704 l l480VLC285 l l Aux FW P2C I-SE-08-2 Ckt. 9 2-60559 638 l l Local Control Station I l l Ckt. 10 l 2-60560 l 740 l HP lite 2-5Bl Reverse Current Valve lWillclosereversecurrentvalveSC-10-5B l l Ckt. 11 l 2-60561 l 638 l l Aux FW P2C RA-ST-3 l l Ckt. 14 2-60564 1639 RA-ST-2 l l \ l

/R1

Page 35 of 49 ST. LUCIE UNIT 2

OFF-NORMAL OPERATING PROCEDURE No. 2-0960030 REVISION 1 DC CR0llND ISOLATION l

APPENDIX 11 PP DC 28 CKT. 27 RTCB- 205 TB T6 CWD 657 REV. 0 8.3.27 Bkr. 6022 i FUSE NO. LINE NO. LOAD CONDITIONS REQlIIRED TO DE-ENERGlZLT-CWD TAG TITLE t. FI FlP 157 V-2515 Letdown Stop Valve Falls closed, lose indication F2 F2N F3 F3P 159 V-2524 RCP Controlled Bleedoff F4 F4N Isol. Valve F5 FSP 176 1-SE-02-01 Charging Line 2B1 Valve Falls open, lose indication, reset to F6 F6N close F7 F7 P 194 V-2522 Letdown Containment Fails closed, lose indication F8 F8N ' Isol. F9 F9P 163 V-2512. I Makeup Stop Valve Falls closed, lose indication F10 F10N l Fil FilP 194 V-2523 Charging Line Isol F12 F12N Valve F13 F13P 564 V-6718 Waste Cas Containment Falls closed, lose indication, manually F14 F14N 1s01. Valve reset HS-6718 to open FIS FISP 563 V-6341 RDT Cont Isol. Valve F16 F16N F17 I F17P 576 V-5750 Waste Gas cont. Isol F18 F18N Valve F19 F19P 190 LCV-07-llA Reactor Sump Isolation F20 F20N Valves I

/R1

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Page 16 of 49 ST. LUCIE UNIT 2 g) OFF-NORMAL OPERATING PROCEDURE No. 2-0960010, REVISION 1 DC CROUND ISoIATION APPENDIX H PP DC 23 CKT. 27 RTCB- 205 TB T6 CWD 657 REV. O I 8.3.27 ,.

                       .                                                                                Bkr. 60227          l FUSE NO. LINE NO.            LOAD                                         CONDITIONS REQlllRED TO DE-ENERGIZE CWD   1    TAG    I           TITLE

ST. LUCIE UNIT 2 0FF-NORMAL OPERATING PROCEDURE NO. 2-0960030, REVISION I Page*17 D)1 IC CROUND IS01ATION - I APPENDIX I PP DC 239 CKT. 28 RTCB- TB CWD REV. 0 6.3.28 Bkr. 2-6022

        ~ FUSE NO.      BREAKER           I.0AD                                           CONDITIONS REQUIRED TO DE-ENERG1ZE CWD 1      TAG   1            TITLE Ckt. 1    '

2-60701 882 l l Re flash Module RA-RAB-18) Window C-31 will alann l Ckt. 2 l 2-60702 l l l Spare l l l Ckt. 3 l 2-60703 l l l Spare l l l Ckt. 4 l 2-60704 l l l Spare l l l Ckt. 5 l 2-60705 l1553 l l Re flash Module RA-RAB-1 l Windows A-4, A-9 will alarm l l Ckt. 6 l 2-60706 l 259 l l Reflash Module RA-1-2 l Window C-57 will alarm l l Ckt. 7 l 2-60707 -l1007 l lReflashModuleRA-CC-1 l Window E-32 will alans l l Ckt. 8 l 2-60708 l l l Spare l l l Ckt. 9 l 2-60709 l l l Spare l l l Ckt. 10 l 2-60710 l1008 l l Reflash Module RA-RAB-4 l Window B-33 will alarm l l Ckt. 11 l 2-60711 l1558 l lReflashModuleRA-RAB-7l l l Ckt. 12 l 2-60712 l 875 l lReflashModuleRA-T-1 l l l Ckt. 13 l 2-60713 l l l Spare l l

    .l   Ckt. 14   l 2-60714       l        l          l Spare                      l                                               l l   Ckt. 15   l 2-60715       l        l          l Spare                      l                                               l l   Ckt. 16   l 2-60716       l        l          l Spare                      l                                               l l   Ckt. 17   l 2-60717       l 992 l             lRA-RAB-20                   l                                               l l   Ckt. 18   l 2-60718       l  188 l            lReflashModuleRA-RAB-9l                                                      l l   Ckt. 19   l 2-60719       l1803 l             l Re flash Module RA-RAB-29l                                                 l l             l               l        l          l                            l                                               l
                                                                                                                            /R1

Pagp/38 9 ST. LUCIE UNIT 2 ' l c 0FF-NORMAL OPERATING PROCEDURE No. 2-0960030, REVISION 1 ! DC GHOUND ISOIATION APPENDIX J t ) PP DC 2B CKT. 31 RTGB- 206 TB T28 CWD 646 REV. O j 8.3.3.)

                                                                                                                  , Bkr. 2-60231 FUSE NO. LINE NO.               LOAD                                                  CONDITIONS REQUIRED TO DE-ENERGIZE CWD         TAG        '

TITLE I F1 FlP 202 HCV-14-88 Component Cool Wtr. Fail closed, lose indication F2 F2N Normal Supply lidr. 1801. Valve F3 F3P 202 HCV-14-10 Component Cool. Wtr. Fall closed, lose indication F4 F4N Normal Return lidr. Isol. Valve F5 F5P 1 211 IISE-14-38 Component Cool. Utr. Fail open, lose indication F6 F6N HCV-14-3B f rom Shutdown lit Exch 2B i l F7 F7F 212 HCV-14-7 Component Cool. Wtr. to Fail closed, lose indication F8 F8N Reactor Cool. Pumps F9 F9P 212 HCV-14-6 Component Cool. Wtr. Fall closed, lose indication F10 F10N . from Reactor Cool. Pumps Fl! FilP 176 V-3661 Recirc. Draw Line Drain Fail closed, lose indication F12 F12N to Reactor Drain Tank F13. F13P 242 1-SE-03-lC Safety injection Tank Fall closed, lose indication F14 F14N Fill and Drain Valve FIS FISP 242 1-SE-03-ID Safety Injection Tank Fail closed, lose indication F16 F16N Fill and Drain Valve , F17 F17P i 256 V-3632 S1 Tank 281 Fail closed, lose indication i FI8 F18N F19 F19P 256 V-3642 S1 Tank 2B2 Fail closed, lose indication

 . F20      F20N

4 ST. LUCIE UNIT 2 - OFF-NORMAL OPERATING PROCEDURE NO. 2-0960030, REVISION 1 DC GROUND ISOLATION 1 I APPENDIX J PP DC 2K CKT. 31 RTCB- 206 TB T28 CWD 646 REV. 0 ' 8.3.3.1 Bkr. 2-602 1 FUSE NO. LINE NO. LOAD CONDITIONS REQUIRED TO DE-ENERGIZE GWD 1 TAG ' TITLE F21 F21P 282 HCV-3638 Check Valve. Leakage Fall closed, lose indication F22 F22N Drain to RWT F23 F23P 283 HCV-3648 Check Valve Leakage FALL closed, lose indication F24 F24N Drain to RWT F25 I F25P 289 FCV-07-1B Containment Spray Valve Fall open, lose indication F26 F26N F27 F27P 316 HCV-08-1B Main Steam Isol. Valve, Solenoid test valves fall open, stroke I F28 F28N Opening, Closing and test valve f ail open, lose indication, Solenoid Test P49 will alarm F29 F29P 319 FCV-23-4 Steam Cen. 2A Blowdown FALL closed, lose indication F30 F30N Isol. Valve F31 F31P 319 FCV-23-6 Steam Gen. 2B Blowdown l Fail closed, lose indication F32 F32N Isol. Valve F33 F33P 320 FCV-26-1 Containment, Suction Fail closed, lose indication F34 F34N FCV-26-3 Return Rad. Sample Isol. FCV-26-5 Valve F35 F35P 578 V-5203 Primary Coolant Sample Fail closed, lose indication, local and F36. F36N Valve remote F37 F37P 579 V-5204 Press. Surge Line l Fall closed, lose indication, local and F38 F38N Sample Valve remote F39 F39P 580 V-5205 Press. Steam Space Fail closed, lose indication, local and i F40 F40N Sample Valve remote i

                            .      ~       . ~:

Page 40 of ST. LUCIE UNIT 2 0FF-NORMAL OPERATING PROCEDURE No. 2-0960030 REVISION 1 DC GR0llND ISOIATION I I APPENDIX J PP DC 2B CKT. 31 RTGB- 206 TB T2M CWD 646 REV. 0 8.3.3.1 i Bkr. 2-60231 FUSE NO. LINE NO. LOAD CONDITIONS REQUIRED TO DE-ENERGIZE CWD ' TAG TITLE F41 1 F41P 586 HCV-25-1A Drain valves to Reactor All. valves this circuit fait closed. F42 F42 thru 25-7A to Auxiliary' Bldg. Sumps lose indication F43 F43P 1520 V-3496 Minimuu Flow Isol. Fail closed, lose indication, F44 F44N Valve Annunciator P-2 will alarm F45 F45P 1519 V-3571 llot Leg IIPSI Line Check Fall closed, lose indication F46 F46N Valve Leakage Drain Loop 2B F47 F47P 275 V-3738 SI Tank 2B1 Vent Valve Fall closed, lose indication F48 F48N F49 F49P 275 V-3740 SI Tank 2B2 Vent Valve Fall closed, lose indication F50 F50N F51 F51P 849 HCV-15-1 Primary Water Isol. Fall closed, lose indication F52 F52N Valve

 . F53        F53P          1527        I-SE-05-1A    SI Tank 2Al Sample          Fail closed, lose indication F54        F54N                                    Valve F55'     i F55P          1527   I I-SE-05-1B    SI Tank 2A2 and 2Al         Fati closed, lose indication at local F56        F56N                      I-SE-05-1A    Sample Valve                station F57        F57P          1527        I-SE-05-1B    SI Tank 2A2 Sample          Fail closed, lose indication at local F,58       F58N                                    Valve                       station F59      I F59P          1527        I-SE-05-IC    St Tank 2B1 Sample          Fati closed, lose indication at local F60        F60N                                    Valve                       station l
                                                                                                                                /R1

Page 41 of 49 ST. LUCIE UNIT 2

OFF-NORMAL OPERATING PROCEDURE NO. 2-0960030, REVISION I IX: GROUND ISOLATION APPENDIX J PP DC 2n CKT. 31 RTGB- 206 TB T28 CWD 646 REV. 0 8'.3.3.1 Bkr. 2-6023 FUSE NO. LINE NO. LOAD CONDITIONS REQlllRED TO DE-ENERGIZE CWD l TAG TITIE l F61 F61P 1527 I-SE-05-ID SI Tank 2B2 Sainple Fall closed, lose indication at local F62 F62N Valve station F63 F63P 1519 I-SE-0 3-2 B SI Tank Test Line to Fail closed, lose indication F64 F64N RWT/VCT F65 ,

F65P 656 HCV-09-lB Main Feedwater Isolation Window P-16 will alarm F66 F66N Valve F67 F67P 672 HCV-09-2B Hain Feedwater Isolation Window P-36 will alarm F68 F68N Valve e 4 = 1 1

Page 42 of 49 ST. LUCIE UNIT 2 ' OFF-NORMAL OPERATING PROCEDURE No. 2-0960030, REVISION 1 DC GROUND ISotATION

APPENDIX K PP DC 28 CKT. 38 RTCB- IIVCB TB W8-RTE CWD 1239 REV. 0 8.3.38 FUSE No. LINE NO. LOAD Bkr. 2-60238 j CONDITIONS REQilIRED TO DE-ENERGIZE CWD i TAG TITLE F25 ' l F25P 153 V-2581 Letdown to RAD Honitor F26 F26N l F27 F27P Spare F28 F28N F29 F29P Spare F30 F30N F31 F31P Spare F32 F32N 'l h l i

/R1

Page 43 of 49 ST. LUCIE UNIT 2 OFF-NORMAL OPERATitlG PROCEDURE NO. 2-0960030, REVISION 1 % DC GROIIND ISOLATION APPENDIX L PP DC 2An CKT. I RTCB- 201 TB CWD 800 REV. 5 8.4.1 2-60301 FUSE NO. LINE NO. LOAD CONDITIONS REQUIRED TO DE-ENERGIZE - CWD ' TAG I TITLE l F51 887 KWil Meter Output Contact HPS, lose indication F52 887 KWH Heter Output Contact HPS, lose indication F53 871 Cross HW Recorder Contact MPS, lose indication F54 871 Digital IfW Recorder Contact HPS, lose indication F55 744 PT-12-30 None F56 744 FT-16-2 None All other ekts are spares

                                  , . . . . a . :. .

Page 44 of 49 ST. LIICIE UNIT 2 OFF-NOICIAL OPER4 TING PROCEDURE NO. 2-0960030, REVISION 1 DC GROUND ISOLATION i APPENDIX M PP DC 2AR CKT. 02 RTCB- 201 TB Wl3 RTF CWD 1241 REV. O FUSE NO. LINE NO. LOAD CONDITIONS REQlIIRED TO DE-ENERCTZ

CWD TAG TITI.E Fil F11P 543 V-6342 RDT Cont. Isol Valve F12 F12N H F13 F13P 512 V-6565 Waste cas stop valve F14 F14N I FIS ' FISP Spare F16 F16N F17 F17P 566 V-6728 Resin Disch Stop Valve F18 F18N

                                                                                                                       /R1 4

l

Page 45 of 49 ST. LUCIE UNIT 2 OFF-NGR!iAL OPERATING PROCEDURE No. 2-0960030 REVISION 1 DC CR0i!ND ISOLATION APPENDlX N FP DC 2AB CKT 03 RTCB- 205 TB T2 CWD 645 REV. O l l 8.4.3 Bkr. 2-0 J303 FUSE NO. LINE NO. LOAD CONDITIONS REQUIRED TO DE-ENERG12E CWD TAG l TITLE FI FIP 151 Letdown Press. anit Loss of indication PCV-220!P, Q F2 F2N Intermediate Letdcwn On RTGB-205 Temp. Channels ' F3 F3P 158 LCV-2110P Letdown Throttle Valves Lose indication only, valves still j

         - F4        F4N                               LCV-2110Q                                   function F5       F5P                      160       V-2513      Volume Control Tank Vent        Fall closed, Lose indication F6       F6N F7       F7P                     163                    Not on indicated CWD*                                                                                              l F8       F8N                                                                                                                                                                 l I

F9 F9P Spare F10 F10N Fil FilP 563 V-6300 RDT Vent Stop Valve Fall open, lose indication F12 F12N F13 F13P 564 V-6565 Waste Gas Stop Valve Fail closed, lose indication F14 F14N FIS FISP 565 V-6739 Spent Resin Tank to Fall closed, lose indication F16 F16N Drumming Station F17 F17P 566 V-6728 Resin Disch Stop Valve Fall closed, lose indication F18 F18N F19 F19P 543 Remetor Drain Pump 2B Loss of pump alternator l F20 F20N 1 F21-F32 Spares Spares l

Page 46 of 49 ST. LUCIE UNIT 2 " j .- 0FF-NORMAL OPERATING PROCEDURE No. 2-0960030, REVISION 1 DC CROUND ISOLATION i' APPENDIX 0 PP DC 2AR CKT. 04 RTGB- 205 TB T10 CWD_645 REV. 0, 8.4.4

Bkr. 2-603 4 FUSE NO. LINE NO. LOAD CONDITIONS REQUIRED TO DE-ENERGIZE-~ CWD TAG TITLE V .. FI Fl? 151 PCV-220lP Letdown Pressure Control Loss of indication only F2 F2N PCV-2201Q F3 F3P 160 V-2500 volume control Tank If de-energized opens to VCT F4 F4N Inlet F5 FSP 160 V-2513 Volume Control Tank Vent Fail closed, lose indication F6 F6N F7 .F7P 160 V-2507 RCP Controlled Bleedoff F8 F8N _{ , F9 l F9P 163 V-2512 Makeup Stop Fall closed, lose indication F10 F10N Fil F11P 563 V-6300 RDT Vent Stop Valve 1:11 open, lose indication F12 F12N F13 l F13P 564 V-6565 Waste Gas Stop Valve Fail closed, lose indication j F14 F14N , FIS FISP. 562 LCV-6604 Flash Tank Level Vs1ve - F16 F16N F17 F17P 562 V-6307 Flash Tank Diverter

                     ' FIS         'F18N                                      Valve i
                      -F19             F19P;            562      V-6308       Flash Tank N 2 Stop Valve F20         - F20N                                   L AllotherfusesthisT.B.shownassparesF21thruF32
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                                                                                                                                                                   .             OFF-NOPHAL OPERATING PROCEDURE No. 2-0960030 REVISION I                                                                                            -

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Page 49 of 49 ST. LUCIE UNIT 2 OFF-NORtlAL OPERATING PROCEDURE NO. 2-096G030, REVISIOli 1 ' DC CROUND ISOLATION APPENDIX R PP 240 CKT. 24 RTCB- TB PD & HD 64J REV. 0 8.4.24 Bkr. 2-6'124 FUSE NO. I.INE NO. LOAD CONDITIONS REQUIRED TO DE-EttERGIZE l CWD i TAG l TITLE , Ckt. 4 999 Reflash Module RA-T-8 Window D28 will alarm Ckt. 12 , 742 Reflash Hodiale RA-T-3 Window E26 will alarm Ckt. 20 1003 Reflash Module RA-RAB-12 Window A50 will alarm NOTE: All other circuits this panel shown as spares ! . e B 4

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Prg2 1 of 5 r FLORIDA POWER & LIGHT COMPANY [p ST. LUCIE UNIT 2

i 1 0FF NORMAL OPERATING PROCEDURE NO. 2-1600030 REVISION 1 /

                     .                                                                             ?      -

1.0 TITLE

ACCIDENTS INVOLVING NEW OR SPENT FUEL 2.0 REVIEW MD APPROVAL: Reviewed by Facility Review Group March 11 1982 Approved by J. H. Barrow (for) Plant Manager March 11 1981 Revision 1 Reviewed by FRG / Z- 19M Approved by 82/////ML Plant Manager h- 2 -19 f 3 3.0 PURPOSE AND DISCUSSION: 3.1 This procedure provides instructions to be followed in the event a new or spent fuel element is dropped or involved in a collision during fuel handling operations.

3.2 Discussion

1. The dropping or collision of a new fuel element nay result in an alpha radiation hazard if the fuel element cladding is breached and the uranium oxide fuel pellets are exposed to the surrounding atmosphere.

2. Breaching of the fuel element cladding should be assumed to have accompanied an accident involving fuel until subsequent radiation monitoring and sampling indicates that no radioactive release has occurred.

3. The damaging of a spent fuel element can result in a serious

    ,                    radiation hazard if the integrity of the fuel rod cladding is breached. The radiation hazard is caused by the release of the fission product gases 1131, Xe133, and Kr85, normally held in the fuel rod voids between the fuel pellets and the cladding, to the Containment or Spent Fuel Pool atmosphere.                               ,

4. Once the initial release of fission product gases through the breached cladding has occurred, further significant release of fission product gases from the fuel pellets themselves is not expected due to the low temperature of the fuel during fuel handling operations.

FDG uw- .v e-ngT10il ONLY This document is r.et comt.ehd. aofere use.

                                      ,,,;{y informatica with a controned documen{

Page 2 of 5 ST. LUCIE UNIT 2 0FF NOFliAL OPERATING PROCEDURE No. 2-1600030, REVISION 1 ACCIDENTS INVOLVING NEW OR SPENT FUEL f ,

)

4.0 SYMP' OMS: /} / 4.1 Damage to a spent fuel element, the cladding of which has been , breached, may be acconpanied by. 1-4.1.1 Area Process or Containment air high radiation alarms. 4.1.2 Cas bubbles originating from the damaged element. 4.2 The alpha radiation hazard associated with a damaged new fuel element will not cause actuation of the Area or Process Radiation Monitor high radiation alarms.

Pags 3 of 5 ST. LUCIE UNIT 2 0FF NORMAL OPERATING PROCEDURE No. 2-1600030, REVISION 1

ACCIDENTS INVOLVING NEiJ OR SPENT FUEL ,

3

f'\ L !!

5.0 INSTRUCTIONS

j/ 5.1 Immediate Automatic Actions: j/' ' 5.1.1 For damage to new fuel - none. [ ] 5.1.2 If damage to spent fuel occurred inside Containment, then a Containment Isolation Actuation Signal (CIAS) may occur. 5.1.3 containment evacuation alarm may actuate. 5.1.4 If damage to spent fuel occurred in the Fuel Handling Building (FHB), then a high radiation signal may alarm in the Control Room which will isolate the FHB and activate the Shield Building Ventilation System (SBVS). /R1 5.2 Immediate Operator Action: 5.2.1 Inform Control Room personnel of the accident. 5.2.2 If the accident occurred inside the Containment:

1. Sound the Containment Evacuation Alarm.

2. Stop 2-HVE-8A and 2-HVE-8B (Containment Purge Fans) if running. /R1

3. Verify I-FCV-25-1 through I-FCV-25-6 (Containment Purge valves) have closed. /R1 4 Evacuate the Containment and check for personnel contamination.

5. Notify Health Physics Department to perform a complete

  ,                         radiological evaluation.

6. Monitor applicable Process and Area Radiation Monitor channels for an increase in radiation levels inside Containment.

5.2.3 If the accident occ cred in the Fuel Pool Area:

1. Evacuate the Fuel Fool Area and remain on the landing outside the north door until monitored for contamination.

2. Notify Control Room personnel.

3. Monitor applicable Area Radiation and Process Monitor channels for an increase in radiation levels inside the Fuel Pool Area.

5.2.4 Notify the Duty Call Supervisor and the Health Physics Supe rvisor. ' l

Ptga 4 of 5 ST. LUCIE UNIT 2 , OFF NORMAL OPERATING PROCEDURE NO. 2-1600030 REVISION 1 - 1 ACCIDENTS INVOLVING NE'4 OR SPEYr FUEL s.

                                                                                                            #}  i

a. - : '

5.0 INSTRUCTIONS : (Cont.) < 5.3 Subsequent Action: 5.3.1 Accident occurring in the Containment:

1. Health Physics personnel shall evaluate airborne particulate and gaseous samples from the Containment i atmosphere and survey the surrounding area.

2. If radiation levels or sampling results indicate that the damaged fuel element cladding has been breached resulting in release of significant radioactivity:

a. Upon recommendation of the Chemistry Department, verify the Continuous Containment Purge System and its associated filter train is is service and adjust flowrate to the value prescribed by Chemistry Department personnel.

b. When airborne radioactivity levels have been reduced to a level that would allow a normal containment purge, obtain a new gas release permit and start 2-HVE-8A or 2-HVE-8B to purge Containment. /R1

c. Continue purging the Containment until the Health Physics Department determines that a safe re-entry can be made.

3. If there are no indications that the fuel element cladding has been breached, re-establish the Containment in accordance with OP 2-0530021, " Controlled Gaseous Batch Release to Atmosphere". /R1 4 Upon verification by Health Physics personnel that radiation levels in the Containment are safe, refueling personnel shall enter the Containment and visually inspect the spent fuel element for damage.

5. After visual inspection and upon approval by the Reactor

, Engineer, the element shall be transferred to the Spent Fuel Pool and stored away from the remaining fuel elements. y

Pega 5 of 5 ST. LUCIE UNIT 2 0FF NORMAL OPERATING PROCEDURE NO. 2-1600030, REVISION 1 . ACCIDENTS INVOLVING NEW OR SPENT FUEL Y ( '

5.0 INSTRUCTIONS

(Cont.) "' J 5.3 (Cont.) 5.3.2 Accident occurring in the Spent Fuel Pool:

1. Health Physics Department shall evaluate airborne particulate and gaseous samples from the Spent Fuel Pool atmosphere.

2. If radiation levels or sampling results indicate that the damaged spent fuel element cladding has been breached:

a. Operate the Shield Building Ventilation System to provide filtered / monitored ventilation of the Fuel Pool Area.

b. Continue ventilation and sampling the Spent Fuel Pool atmosphere until Health Physics personnel determine that safe entry can be made.

3. Upon verification by the Health Physics Department that radiation levels in the Spent Fuel Pool Area are normal, refueling personnel shall enter the area and visually inspect the spent fuel element for damage.

4. After visual inspection and upon approval by the Reactor Engineer, the element shall be moved and stored away from the remaining fuel elements in the Spent Fuel Pool.

6.0 REFERENCES

6.1 St. Lucie Unit 2 FSAR, Section 6.2.3.2.2, " Shield Building Ventilation System"; Section 9.1.4, " Fuel Handling System"; 3 Section 9.4.2, " Heating, A/C, and Ventilation Control"; and Sections 12.1 and 12.2, " Radiation Monitoring System" /R1 6.2 St. Lucie Unit 2 Technical Specifications, Section 3/4.9, Refueling Operations /R1 6.3 10 CFR20,' Appendix B, " Concentrations in Air and Water Above Natural Background" 6.4 St. Lucie Plant Radiation Protection Manual 7.0 RECORDS, REPORTS, AND NOTIFICATIONS:

  ,              7.1  Normal log entries

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4.0 SYMPTOMS

5.0 INSTRUCTIONS

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1.0 TITLE

3.0 PURPOSE

3.2 Discussion

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8.0 INSTRUCTIONS

8.0 INSTRUCTIONS

8.0 INSTRUCTIONS