ML11158A119

2-ECA-0.0, Rev. 7, Loss of All AC Power

ML11158A119
Person / Time
Site:	Indian Point
Issue date:	04/29/2011
From:	Entergy Nuclear Northeast
To:	Office of Nuclear Reactor Regulation
References
NL-11-065 2-ECA-0.0, Rev 7
Download: ML11158A119 (29)

Text

--- Entergy Nuclear Northeast Procedure Use Is:

0 Continuous E3 Reference Control Copy:

Effective Date: j/2g-4

//

0 Information 2-ECA-0.0, Revision: 7 LOSS OF ALL AC POWER I.........BI il -T Approved By:

I.,

t.

+/-

Procedure Sponsor, Team P Procedure Owner RP EDTRA REII Date EDITORIAL REVISION

A.

PURPOSE This procedure provides actions to respond to a loss of all AC power.

B.

SYMPTOMS OR ENTRY CONDITIONS

1) The symptom of a loss of all AC power is the indication that all 480V busses are de-energized.

2) This procedure is entered from 2-E-O, REACTOR TRIP OR SAFETY INJECTION, Step 3, on the indication that all 480V busses are de-energized.

C.

ADVERSE CONTAINMENT CONDITIONS EOP values for adverse containment should be used if either of the following conditions exist:

o Containment radiation levels greater than 1E5 R/hr.

OR -

o Containment pressure greater than 4 psig.

I of 28

STEP ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED NOTE o Steps 1 and 2 are IMMEDIATE ACTION steps.

o CSF Status Trees should be monitored for information only.

FRPs should NOT be implemented.

1.

Verify Reactor Trip:

o Reactor trip breakers OPEN o Neutron flux -

DECREASING o Rod bottom lights -

LIT o Rod position indicators ALL RODS LESS THAN 12.5 INCHES

2.

Verify Turbine Trip:

a.

All turbine stop valves CLOSED Manually trip reactor.

a. Manually trip turbine.

IF turbine will NOT trip, THEN close MSIVs.

IF MSIVs can NOT be closed, THEN manually run back turbine.

2 of 28

3.

ACTION/EXPECTED RESPO tRESPONSE NOT OBTAINED

3.

Check If RCS Is Isolated:

a. Letdown isolation valves -

CLOSED

a. Manually close valve.

o LCV-459 o 200A o 200B o 200C

b.

PRZR PORVs CLOSED

b.

IF PRZR pressure less than 2335 psig, THEN manually close PORVs.

c.

Excess letdown isolation valve CLOSED o 213

4.

Verify AFW Flow -

GREATER THAN

c. Manually close valve.

400 GPM:

a.

Turbine-driven AFW pump -

RUNNING

a. Manually open steam supply regulator valve:

o PCV-1139

b. Manually align turbine-driven AFW pump FCVs as necessary

c.

Adjust steam supply speed control valve as necessary:

o HCV--1118 3 of 28

CAUTION The load on the diesel generators should remain less than 1650 KW but may be increased to 2000 KW for a maximum of 2 hrs in any 24 hr period.

5.

Try To Restore Power to Any 480V Bus:

a.

Energize 480V bus with diesel generator:

1) Check diesel generator(s)

RUNNING

1) Emergency start diesel generator(s):

a) Manually actuate SI.

2) Manually energize 480V bus from running diesel generator.

2) Verify 480V bus -

AUTOMATICALLY ENERGIZED This Step continued on the next page.

4 of 28

IF 480V bus can NOT be energized from diesel generator(s),

THEN perform the following:

a) Locally trip running diesel generator(s).

b) Contact Con Ed DO to determine if 138KV or 13.8KV power readily available.

c)

IF outside power is NOT readily available, THEN perform the following:

1. Dispatch NPO to start IP2 Appendix R DG per:

o 2-SOP-27.6, UNIT 2 APPENDIX R DIESEL GENERATOR OPERATION

2.

IF IP2 Appendix R DG is NOT available, TN CONTACT IP3 CCR to START IP3 Appendix R DG per 3-SOP-EL-013, APPENDIX R DIESEL GENERATOR OPERATION.

d)

IF outside power is readily available, THEN attempt to manually energize 480V bus using the following:

o 2-AOP-138KV-1, LOSS OF POWER TO 6.9KV BUS 5 AND/OR 6.

o 2-AOP-480V.1, LOSS OF 480V BUS.

This Step continued on the next page.

5 of 28

STEP ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED

b. hek 40Vbuses-A LAS

b. Check 480V busses

-AT LEAST ONE ENERGIZED:

o 2A AND 3A OR -

b. Perform the following:

1) Open doors on all control room cabinets.

2) Dispatch NPO to open AFW pump room roll-up door.

3)

Go to Step 6.

OBSERVE CAUTION PRIOR TO STEP 6.

o 5A OR -

o 6A

c. Start one service water pump on the essential header to support running diesel generator

d.

Check CCR & AFW pump room ventilation RUNNING

d.

Perform the following as required:

1) Open doors on all control room cabinets.

2) Dispatch NPO to open AFW pump room roll-up door.

e. Return to procedure and step in effect and implement FRPs 6 of 28

STEP ACIO/'PETE R..-P. NoSE*o, I

FRSOS NOT*

,OBTAr

• INE ft CAUTION o When power is restored to any 480V bus, recovery actions should continue starting with Step 24.

o If an SI signal exists or if an SI signal is actuated during this procedure, it should be reset (refer to Step 18b) to permit manual loading of equipment on a 480V bus.

ft o If a diesel generator is started, a service water pump should be started on the essential header to provide diesel generator cooling.

ftf o If a partial train (bus 2A or bus 3A) is energized, safeguards equipment on the energized bus including RCP seal cooling should NOT be placed in PULLOUT or isolated.

6.

Place Following Eauipment Switches In PULLOUT Position:

o Containment spray pumps o SI pumps o FCUs o Motor-driven AFW pumps o Turning gear oil pump o Bearing oil pump o Turbine auxiliary oil pump o CCW pumps o RHR pumps 7 of 28

SE

• CTION/EfXPECTED,RESPONSE J RESPONSE NOT OBTAINED Wr CAUTION Radiation levels and harsh environment prior to performing local actions.

conditions should be evaluated ft 0 7.

Dispatch Personnel To Locally Restore AC Power:

a. Emergency diesel generator(s) per:

o 2-SOP-27.3.I.1.

21 EMERGENCY DIESEL GENERATOR MANUAL OPERATION o 2-SOP-27.3.1.2.

22 EMERGENCY DIESEL GENERATOR MANUAL OPERATION o 2-SOP-27.3.1.3, 23 EMERGENCY DIESEL GENERATOR MANUAL OPERATION This Step continued on the next page.

8 of 28

ST P ACTION/EXPECTED R S O E]RESPONSE NOT OBTAINED i,,,,,,,

b.

Check 13.8KV feeder 13W92

b.

IF 13.8KV feeder 13W92 can NOT ENERGIZED be energized, THEN perform the following:

1) Contact Con Ed DO to determine if IP3 13.8KV feeder 13W93 is available.

2) IF IP3 13.8KV 13W93 is available, THEN attempt to restore power to 6.9KV via 52GT/BT per:

o 2-SOP-ESP-O01.

LOCAL EQUIPMENT OPERATION AND COMPENSATORY ACTIONS

3)

IF 13.8KV feeder 13W93 is NOT available OR 52GT/BT can NOT be closed, THEN start Appendix R DG per:

o 2-SOP-27.6, UNIT 2 APPENDIX R DIESEL GENERATOR OPERATION

4)

IF Appendix R OG can NOT be started, THEN perform the following as required:

a)

Restore power to ASSS via IP3 Appendix R OG per:

o 2-AOI-27.1.9.2, PROVIDING APPENDIX R POWER FROM UNIT 3 b) Contact Con Ed DO -for available power alignment.

5) Continue with Step 8.

WHEN power source is available, THEN do Step 7c.

This Step continued on the next page.

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c.

Attempt to restore power to busses per the following while continuing with Step 8:

o 2-SOP-27.1.3.

OPERATION OF 13.8KV SYSTEM o 2-SOP-27.1.4, 6900 VOLT SYSTEM.

o 2-AOP-138KV-1.

LOSS OF POWER TO 6.9KV BUS 5 AND/OR 6.

o 2-AOP-13.8KV-1, LOSS OF POWER TO ANY 13.8KV BUS o 2-AOP-480V-1, LOSS OF 480V BUS.

8.

Dispatch Personnel To Locally Close Valves To Isolate RCP Seals:

o RCP seal return isolation valve outside containment:

o MOV-222 o RCP seal injection isolation valves outside containment:

o MOV-250A o MOV-250B o MOV-250C o MOV-250D o RCP thermal barrier CCW return isolation valve outside containment:

o MOV-789 10 of 28

9....

.ECTED RESPOC hcRESPONSE NOT OBTAINED

9.

Check If CST Is Isolated From Hotwell:

a. Verify condenser hotwell isolation valves CLOSED:

a.

IF valve(s) open or position not known, THEN dispatch personnel to locally close valve(s).

IF valve(s) can NOT be closed, THEN locally close associated isolation valve(s):

0 0

0 0

0 LCV-1128 LCV-1128A LCV-1129 CD-6 CT-8 o CT-7 for LCV-1128 and LCV-1128A.

o CD-5 for LCV-1129.

b.

Place condenser hotwell isolation valve controllers in MANUAL:

o LCV-1128 o LCV-1128A o LCV-1129

10.

Check SG Status:

a.

MSIVs CLOSED

b.

Main FW regulating valves -

CLOSED Manually close valves.

IF valves can NOT be manually closed, THEN locally close valves.

Locally close MSIVs as necessary per 2-SOP-ESP-O01, LOCAL EQUIPMENT OPERATION AND COMPENSATORY ACTIONS.

and bypass

c.

Blowdown CLOSED isolation valves -

11 of 28

STEP ACTION/EXPECTED RESPONSE',

I RESPONSE NOT OBTAINE ft ft ft ft ft ft ft ft ft ft ft ft ft ft ft ft ft ft ft ft

,dl

• r t

CAUTION A faulted or ruptured SG that is isolated should remain isolated.

Steam supply to the turbine-driven AFW pump must be maintained from at least one SG.

ft

11.

Check If Any SG Is Faulted:

a.

Check pressures in all SGs o ANY SG PRESSURE DECREASING IN AN UNCONTROLLED MANNER OR -

o ANY SG COMPLETELY DEPRESSURIZED

b. Isolate faulted SG(s):

o Isolate AFW flow o Dispatch NPO to close steam supply header valves to turbine-driven AFW pump from faulted SG(s):

o MS-41 (SG 22) o MS-42 (SG 23) o Verify SG atmospheric steam dumps CLOSED

a.

Go to Step 12.

b. Manually close valves.

IF valves can NOT be closed, THEN dispatch NPO to attempt to locally close valves or associated block valves.

12 of 28

STEP ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED

12.

Check If SG Tubes Are Intact:

o Main steamline radiation recorder (R-28, R-29, R-30 and R-31)

NORMAL o Condenser air ejector radiation recorder (R-45)-

NORMAL o SG blowdown radiation recorder (R-49)

NORMAL o NO SG LEVEL INCREASING IN AN UNCONTROLLED MANNER Try to identify ruptured SG(s).

Continue with Step 13.

OBSERVE CAUTION PRIOR TO STEP 13.

WHEN ruptured SG(s) identified, THEN isolate ruptured SG(s):

o Isolate AFW flow.

o Dispatch NPO to close steam supply header valves to turbine-driven AFW pump from ruptured SG(s):

o MS-41 (SG 22) o MS-42 (SG 23) o Adjust ruptured SG(s) atmospheric steam dump controller setpoint to 74%,

1030 psig.

WHE__N_

ruptured SG pressure less than 1030 psig, THEN verify ruptured SG atmospheric steam dump closed.

IF NOT closed, THEN place controller in manual and close valve. IF valve can NOT be closed, THEN locally isolate open valve.

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t

.f CAUTION City water for AFW pumps will be necessary if CST level decreases to less than 2 ft.

13.

Check Intact SG Levels:

a.

Narrow range level - GREATER THAN 10% (27% FOR ADVERSE CONTAINMENT)

a. Maintain maximum AFW Flow until narrow range level greater than 10% (27% FOR ADVERSE CONTAINMENT) in at least one SG.

o Preferentially RESTORE level to 22 OR 23 SG

b.

IF narrow range level in any SG continues to increase in an uncontrolled manner, THEN isolate ruptured SG(s):

b. Control AFW flow to maintain narrow range level between 10%

(27% FOR ADVERSE CONTAINMENT) and 50%

o Preferentially to 22 OR 23 SG RESTORE level o Isolate AFW flow.

o Dispatch NPO to close steam supply header valves to turbine-driven AFW pump from ruptured SG(s):

o MS-41 (SG 22) o MS-42 (SG 23) o Adjust ruptured SG(s) atmospheric steam dump controller setpoint, to 74%,

1030 psig.

WHEN ruptured SC pressure less than 1030 psig, THEN~

verify ruptured SC atmospheric steam dump closed.

IF NOTr closed, THEN place controller in manual and close valve. IF" valve can NOT be closed, THEN locally isolate open valve.

14 of 28

STEP ACTION/EXPECTED

RESPONSE

RESPONSE NOT OBTAINED i

il i i i

i I

14.

Check DC Bus Loads:

a. Monitor DC power supply:

o Consult TSC and shed selected DC loads if necessary to extend battery life

15.

Check CST Level

- GREATER THAN 2 FT Switch to city water supply:

a.

Open city water header isolation valve:

o FCV-1205A

b. Open AFW pump suction valves as necessary:

o PCV-1187 o PCV-1188 o PCV-1189 15 of 28

S AC*

ONEXPECTEO RESPONSEI E SPONSE NOT

• OfTA*

f ft ftr ft CAUTION o SG pressures should NOT be decreased to less than 200 psig to prevent injection of accumulator nitrogen into the RCS.

o SG narrow range level should be maintained greater than 10% (27% FOR ADVERSE CONTAINMENT) in at least one intact SG.

If level can NOT be maintained, SG depressurization should be stopped until level is restored in at least one SG.

ft dr t

ft ft ft ft ft ft ft

• ft ft ft ft ft

• ft f

ft ft ft ft ft

• r t

ft t

ft ft ft ft ft ft ft f

t ft t

ft NOTE o The SGs should be depressurized at a rate sufficient to maintain a cooldown rate in the RCS cold legs near 1000F/Hr. This will minimize RCS inventory loss while cooling the RCP seals in a controlled manner.

o PRZR level may be lost and reactor vessel upper head voiding may occur due to depressurization of SGs.

Depressurization should NOT be stopped to prevent these occurrences.

16.

DeDressurize Intact SGs To 300 osic:

a.

Check SG narrow range levels GREATER THAN 10% (27% FOR ADVERSE CONTAINMENT) in at least one SG

a.

Perform the following:

1) Maintain maximum AFW flow until narrow range level greater than 1.0% (27% FOR ADVERSE CONTAINMENT) in at least one SG.

o Preferentially RESTORE level to 22 OR 23 SG

2) Continue with Step 17.

WHEN narrow range level greater than 10% (27% FOR ADVERSE CONTAINMENT) in at least one SG, THEN do Steps 16b through 16e.

This Step continued on the next page.

16 of 28

b. Manually dump steam using SG

b.

Locally dump steam using SG atmospheric steam dumps to atmospheric steam dumps:

Mnintnin fAlfllhlf-d rta

• n Drr cold legs -

LESS THAN 1000F/HR o Refer to 2-SOP-ESP-O01, LOCAL EQUIPMENT OPERATION ANI)

COMPENSATORY ACTIONS *For local operation as necessary.

c. Perform the following:

1) Control SG atmospheric steam dumps to stop SG depressurization.

c.

Check RCS cold leg temperatures GREATER THAN 3250F

2)

Go to Step 17.

d.

Check SG pressures LESS THAN 300 PSIG

e. Manually control SG atmospheric steam dumps to maintain SG pressures at 300 psig

17.

Check Reactor Subcritical:

d. Continue with Step 17.

WHEN SG pressures decrease to less than 300 psig, THEN do Step 16e.

e. Locally control SG atmospheric steam dumps to maintain SG pressures at 300 psig:

o Refer to 2-SOP-ESP-O01, LOCAL EQUIPMENT OPERATION AND COMPENSATORY ACTIONS for local operation as necessary.

Control SG atmospheric steam dumps to stop SG depressurization and allow RCS to heat up.

o Intermediate range channels -

0 OR NEGATIVE STARTUP RATE o Source range channels 0 OR NEGATIVE STARTUP RATE 17 of 28

STE AC

[NEPCE REPOS

• NS NO O

CAUT I ON

@t

• Placing key switches to DEFEAT will prevent auto SI actuation.

NOTE Depressurization of SGs will result in SI actuation.

SI should be reset to permit manual loading of equipment on 480V bus.

18.

Check SI Signal Status:

a. SI

- HAS BEEN ACTUATED

a.

Go to Step 22.

WHEN SI

actuated, THEN do Steps

19. 20 and 21.

is

18b,

b. Reset SI:

1) Check all CCW pumps -

RUNNING

1) Place non-running CCW pumps CCR control switches in PULLOUT.

2)

Place controls for main AND bypass feedwater regulating valves to CLOSE

3) Verify Automatic Safeguards Actuation key switches on Panel SB-2 in DEFEAT position:

o Train A SIA-1

• - AND -

o Train B SIA-2

4)

One at a time, depress Safety Injection reset buttons (Panel SB-2):

o Train A o Train B

5) Verify Train A AND B -

RESET

5) Verify Relays reset (Top of Safeguards Initiation Racks 1-1 AND 2-1):

o SIA-1 o SIM-1 o SIA-2 o SIM-2 18 of 28

19.

Verify Containment Isolation Phase A:

a. Phase A - ACTUATED o Train A master relay CA1 (above rack E) o Train B master relay CA2 (above rack F)

b. Phase A valves - CLOSED

c.

IVSW valves -

OPEN:

a.

Manually actuate phase A.

b. Manually close valves.

IF valves can NOT be manually closed, THEN locally close valves.

c. Manually open valves.

o 1410 o 1413 o SOV-3518 o SOV-3519

d.

WCP valves OPEN:

d. Manually open valves.

o PCV o PCV o PCV o PCV 1238 1239 1240 1241

e. Place personnel AND equipment hatch solenoid control switches to INCIDENT on SM panel 19 of 28

sTEP ACTON/XP~rEDRESONS RESPONSE NOT OBTAINEDI

20.

Verify Containment Ventilation Isolation:

a.

Containment purge valves -

a.

Manually close valves.

CLOSED:

IF valves can NOT be closed, o KCV-1170 THEN close valves from fan o FCV-1171 room.

o FCV-1172 o FCV-1173 IF valves can NOT be closed, THEN dispatch operator and HP personnel to close outside valves by isolating instrument air:

o FCV-1171, IA-780 o FCV-1173, IA-779

b. Containment pressure relief

b. Manually close valves.

valves CLOSED:

IF valves can NOT be closed, o PCV-1190 THEN close valves from fan o PCV-1191 room.

o PCV-1192 IF valves can NOT be closed, THEN dispatch operator AND HP personnel to close outside valves by isolating 'instrument air:

o PCV-1191, IA-777 o PCV-1192, IA-778 IF containment pressure relief can NOT be isolated, THEN locally close the following valves (Fan House 88'elev..

inside Pressure Relief Fan Plenum);

o UH-1013, Pressure Relief Fan Inlet Stop o UH-1014, Pressure Relief Fan Outlet stop 20 of 28

STEP ACTION/EXPECTED RESPONSE r ESPONSE NOT OBTAINED I

I "

I

21.

Check Containment Pressure -

HAS Perform the following:

REMAINED LESS THAN 24 PSIG

a. Verify containment spray signal actuated.

IF NOT.

THEN manually actuate.

b.

Verify containment isolation Phase B valves closed.

Ir NOT, THEN manually close valves.

IF valves can NOT be manually closed. THEN locally close valves.

c. Verify IVSW isolation valves open (98'PAB MCC26AA/BB Room):

o SOV-7864 o SOV-7865 o SOV-7866 o SOV-7867

d. One at a time. depress Containment Spray Reset Pushbuttons:

o Spray SYS Reset Train A o Spray SYS Reset Train B

22.

Check Core Exit TCs - LESSTHAN 1200oF IF Core Exit temperatures greater than 1200°F and increasing, THEN go to SACRG-1, SEVERE ACCIDENT CONTROL ROOM GUIDELINE INITIAL

RESPONSE, Step 1.

21 of 28

23.

Check If AC Power Is Restored:

a. Check 480V busses AT LEAST

a. Continue to control RCS ONE ENERGIZED conditions and monitor plant status:

o 2A AND 3A

1) Check status of local

- OR -

actions:

o 5A o AC power restoration.

o RCP seal isolation.

- OR -

o DC power supply.

o 6A

2) Check status of auxiliary boration systems:

o BAST temperature greater than 155 0 F.

IF temperature less than 155 0 F. request TSC to provide emergency power supply for boric acid heat trace to prevent crystallization.

3) Check status of spent fuel cooling:

o Spent fuel pit level greater than low level alarm.

IF level less than low level alarm, THE__NN dispatch NPO to makeup to the spent fuel pit as necessary.

4) Return to Step 11.

OBSERVE CAUTION PRIOR TO STEP 11.

22 of 28

S ACTION/EXPECTED RESPONSE

RESPONSE NOT OBTAINED

24.

Stabilize SG Pressures:

a.

Manually control SG atmospheric steam dumps

a.

Locally control SG atmospheric steam dumps:

o Refer to 2-SOP-ESP-O01, LOCAL EQUIPMENT OPERATION AND COMPENSATORY ACTIONS for local operation as necessary.

N bus should NOT exceed the capacity t

• k

• t*

f t

ft f

t a

a f

t f

t f

t f

CAUTIC The loads placed on the energized 480V of the power source.

25.

Verify Service Water System Operation:

a. Verify at least one pump -

RUNNING ON ESSENTIAL HEADER

b. Service water valves from diesel generator - OPEN

a. Manually start pump.

b. Locally open valves as necessary.

23 of 28

STEP ACTION/EXPECTED RESPONSE RESPONSE NOT OTIE RESPONSE IO OBTAINED1

26.

Verify Following Eguipment Loaded On Energized 480V Bus:

Manually load equipment as necessary.

o Bus 5A:

a.

MCCs:

o MCC 26A o MCC 29A

b.

21 Battery Charger in service

c.

21 Static Inverter on alternate power supply per 2-SOP-27.1.6.

INSTRUMENT

BUS, DC DISTRIBUTION SYSTEM AND PA SYSTEM INVERTER

d.

23 Static Inverter on alternate power supply per 2-SOP-27.1.6 o Bus 2A:

a.

MCCs:

o MCC 24 o MCC 24A

b.

22 Battery Charger in service

c.

22 Static Inverter on alternate power supply per 2-SOP-27.].6

d.

PA System Inverter on alternate power supply per 2-SOP-27.1.6 This Step continued on the next page.

24 of 28

SE CTION/EXPECTED RESPONSEI FRESPONSE NOT OBTAINED o Bus 3A:

a.

MCCs:

o MCC 26C o MCC 211

b.

23 Battery Charger in service o Bus 6A:

a.

MCCs:

o MCC 26B o MCC 27A

b.

24 Battery Charger in service

c.

24 Static Inverter on alternate power supply per 2-SOP-27.1.6 25 of 28

STEP ACTION/EXPECTED

RESPONSE

RESPONSE NOT OBTAINEDI NOTE If RCP seal cooling was previously isolated, further cooling of the RCP seals will be established by natural circulation cooldown as directed in subsequent procedures.

27.

Select Recovery Procedure:

a. Check RCS subcooling based on core exit TCs -

GREATER THAN VALUE OBTAINED FROM TABLE:

a.

Go to 2-ECA-0.2, LOSS OF ALL AC POWER RECOVERY WITH SI

REQUIRED, Step 1.

WR RCS PRESSURE RCS SUBCOOLING OF (PSIG)

(ADVERSE CONTAINMENT) 0 - 400 52 (83) 401

- 800 36 (49) 801 1200 23 (30) 1201

- 2500 19 (26)

b. Check PRZR level GREATER THAN 14% (33% FOR ADVERSE CONTAINMENT)

c. Check if SI equipment -

ACTUATED WITH RESULTANT INJECTION FLOW UPON AC POWER RESTORATION

d.

Go to 2-ECA-0.2.

LOSS OF ALL AC POWER RECOVERY WITH SI REQUIRED.

Step I

-END-

b.

Go to 2-ECA-0.2, LOSS OF ALL AC POWER RECOVERY WITH SI

REQUIRED, Step I.

c.

Go to 2-ECA-O.1, LOSS OF ALL AC POWER RECOVERY WITHOUT SI

REQUIRED, Step 1.

26 of 28

ATTACHMENT I (Attachment page 1 of 1)

CONTAINMENT ISOLATION VALVES

1.

The following valves will close on Phase A isolation:

VALVE NAME CCW from excess letdown Hx CCW to excess letdown Hx Vent header from RCDT Gas analyzer PRT Gas analyzer RCDr Letdown from regenerative HX Letdown oriface control stop valves Make-up to PRT Containment sump pumps to WDS

- hold-up tank Instrument air to containment RCDT to WDS

- hold-up tank SG blowdown and sampling system Radiation monitor return to containment Accumulator samples Sample - pressurizer steam Sample - pressurizer liquid Sample -

RCS loops SJAE to containment Hi-Rad sample system return to containment sump Recirculation pump discharge sample line Accumulator N2 Supply Line Stop VALVE NUMBER(s) 796.

793

798, 791

1786, 1787

548, 549 1788, 1789

201, 202

200A, 2008.

200C 519, 552

1723, 1728 PCV-1228 1702.

1705 PCV-1214, 1.214A PCV-1215, 1215A PCV-1216.

1216A PCV-1217, 1217A PCV--1234.

1235 PCV-1236, 1237 956G. 956H

956A, 9568 956C, 956D 21, 22, 23 MOV-956E, 956F 1229.

1230 MOV-4399.

5132 MOV-990A. 990B 863 2

The following valves will close on Phase B isolation:

VALVE NAME VALVE NUMBER(s)

Component cooling to RCS pumps MOV-769, 797 Component cooling from RCS thermal barrier return MOV-789, FCV-625 Component cooling from RCS motor bearing return MOV-786.

784 Seal water return containment isolation valve MOV-222

-END-27 of 28

ATTACHMENT 2 (Attachment page 1 of 1) 480V EQUIPMENT LOAD RATINGS

1.

Use the following table to determi ne 480V eauiDment load ratinas:

21 DG 22 DG 23 DG EQUIPMENT BUS 5A BUS 2A BUS 3A BUS 6A 21 SERVICE WATER PUMP 22 SERVICE WATER PUMP 23 SERVICE WATER PUMP 24 SERVICE WATER PUMP 25 SERVICE WATER PUMP 26 SERVICE WATER PUMP PRZR CONTROL HEATERS 21 PRZR BU HEATERS 22 PRZR BU HEATERS 23 PRZR BU HEATERS 21 23 21 22 23 24 25 21 22 23 21 22 21 22 AFW PUMP AFW PUMP FAN COOLER FAN COOLER FAN COOLER FAN COOLER FAN COOLER SI PUMP SI PUMP SI PUMP SPRAY PUMP SPRAY PUMP RHR PUMP RHR PUMP UNIT UNIT UNIT UNIT UNIT 282 KW 282 KW 485 KW 250 KW 250 KW 316 KW 350 KW 150 KW 299 KW 228 KW 225 KW 93 KW 282 KW OR 282 KW 282 KW OR 282 KW 485 KW 554 KW 384 KW 250 KW 250 KW 282 KW 282 KW 277 KW 384 KW 250 KW 345 KW 350 KW 303 KW 150 KW 299 KW 228 KW 150 KW (E) 112 KW 316 KW 316 KW 303 KW 150 KW 21 CHARGING PUMP 22 CHARGING PUMP 23 CHARGING PUMP 21 RECIRC PUMP 22 RECIRC PUMP 21 CCW PUMP 22 CCW PUMP 23 CCW PUMP 21 LIGHTING TRANSFORMER 22 LIGHTING TRANSFORMER 23 LIGHTING TRANSFORMER TURBINE AUX OIL PUMP STATION AIR COMPRESSOR 228 KW 150 KW (N) 225 KW END -

28 of 28