ML20151R092

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Rev 8 to OP-C.13A, Remote Shutdown
ML20151R092
Person / Time
Site: Rancho Seco
Issue date: 04/15/1988
From:
SACRAMENTO MUNICIPAL UTILITY DISTRICT
To:
Shared Package
ML20151Q793 List:
References
GCA-88-248, NUDOCS 8804270238
Download: ML20151R092 (45)
v • d • e


Text

EFFECTIVE DATE 02-24-88 Rev. 8 HP4219P 0-0216P OP-C.13A REMOTE SHUT 00HN 1.0 PURPOSE To provide the operators with the necessary response and recovery 1.1 actions to mitigate the consequences of a plant shutdown from outside the Control Room.

ROIE:

The Control Room is considered uninhabitable due to fire and Offsite Power may or may not be available.

2.0 RESPONSE 2.1 BEEH the decision is made to evacuate the Control Room, IREM 2.1.1 TRIP the Reactor (confirm all rods in).

2.1.2 TRIP P-317A Main Feed Pump "A".

2.1.3 TRIP P-3178 Main Feed Pump "B".

2.1.4 TRIP the Main. Turbine (confirm Throttle / Governor valves closed).

2.2 If time permits, IEEH perform the following:

2.2.1 INITIATE AFH on H1SS(E) by depressing 101H AFW pushbuttons for the EFIC Channel A Initiate / Test Matrix.

8-~

2.2.2 OPEN SFV-25003, DHR Pump A Suct from BHST (H2SFA).

2.2.3 CLOSE the following valves:

Valve No.

Descriotion Location SFV-22009 Letdown Isol. Outside RB H2SFB SFV-24013 RCP Bleed Off Isol. Outside R8 H2SFB HV-20597 Main Steam "A" to Reheaters H2YS HV-20598 Main Steam "B" to Reheaters H2YS HV-20560 Main Steam "B" to Aux Steam H2YS HV-20565 Main Steam "A" to Aux Steam H2YS HV-32243 Pegging Steam to FH Htrs H2YS

'WV.

O OP CIN8MOCEDURE/ MANUAL IS DISTRIBUTED TH seo427o23e eso415 THE Mall BY DOCUMENT CONTROL PROCEDUR PDR ADOCK 05000312 P

PDR MAY NOT REFLECT THE LATESTVISION.

ASSIGNED TO MANUAL L 2-i

~

RESPONSE (Continued) 2.3 EVACUATE THE CONTROL ROCH 2.4 The Shift Supervisor is to perform the actions of Enclosure 5.2. "Shif t Supervisor Actions."

8-2,5 Direct Control Room Operator #1 to proceed to the West 480 volt Switchgear Room to obtain the following from the Emergency Communications and Emergency Lighting Cabinet and the Remote Shutdown Procedure Cabinet:

Clipboard with ENCLOSURE 5.3 Portable Lantern Walkie Talkie (solected to channel #1)

MQ proceed with his assigned duties.

2.6 Proceed to the West 4160 Volt Switchgear Room and perform the following:

2.6.1 01 sable the Cardox System.

2.6.2 Block OPEN the door.

4.6.3 Place to ' ISOLATE HS-PAI' "Control Room Page Override" in panel H7T3655.

2.7 Announce on the Plant Paging System the following:

2.7.1 "Attention Station Personnel - Reactor Trip"

- Repeat-2.7.2 "Fire in the Control Room - Control Room Evacuation"

- Repeat-2.7.3 (IF APPLICABLE) "Loss of Offsite Power"

-Repeat-2.7.4 "All operators assemble at the West 4160 Volt Switchgear Room."

-Repeat-2.7.5 Perform Steps 2.7.1 thru 2.7.4 a second time, then continue.

2.8 At H2SD, place to CLOSE the Turbine Bypass Valves Manual Close switch HS-20561.

Rev. 8 OP-C.13A-2

RESPCNSE (Continued) 2.9 IE the sound powered phone system is used, IJiER isolate the following circuits in terminal box H7T240.

Device Action 0S-113 Place to 0FF 0S-114 Place to 0FF 05-115 Place to 0FF 0S-209 Piace to 0FF 05-210 Place to 0FF All H250 Shutdown Panel Indicators fail low.

N_QITI:

The Shutdown Panel door is removable.

2.10 Scan the Shutdown Panel indientors and check for propsr operation.

1 Instrument Descriotion Range Increment TI-21025E Loop "A" TC 5'J-650 10*F TI-21031C Loop "A" TH 120-920 10*F PI-21051 RC Press 0-3000 100 psig PI-21050 RC Press 0-3000 100 psig TI-21024C Loop "B" TC 50-650 10*F TI-21032C Loop "B" TH 120-920 10*F LI-20509 "A" OTSG Level 0-619 25 inches PI-20547 "A" 0TSG Pressure 0-1200 20 psig LI-215030 PZR Level 0-320 5 inches LI-21503B PZR Level 0-320 10 inches LI-23502C HU Tank Level 0-100 1 inch LI-20510 "B" OTSG Level 0-61 9 25 inches PI-20548 "B" OTSG Pressure 0-1200 20 psig 2.11 Obtain a walkie talkie (selected to Channel #1) from the Emergency 8-Communication Equipment Cabinet H7T262 gr use the base station radio located in junction box H7T566 next to the Shutdown Panel.

Rev. 8 OP-C.13A-3

RESP 04SE (Continued) 8-2.12 Direct the Control Room Operator #2 and Operators #3, #4, #5, and #6 to obtain the following:

Clipboard with appropriate ENCLOSURE (Appendix R Shutdown Equipment Locker)

Halkie Talkie (selected to channel #1) (Emergency Communication Equipment Cabinet)

Portable Lantern (Emergency Lighting Cabinet)

Keys (Operator #3 and #4) (Appendix R Shutdown Equipment Locker) 8-~

ARQ proceed with their assigned duties.

2.13 BdEH valve control is transferred to the Shutdown Panel (BLPB LIGHTS ON),

IEEH perform the following:

I 8--

2.13.1 Verify OPEN SFV-25003 (OHR Pump A Guct from BHST) 2.13.2 Verify OPEN SFV-23508 (MU TNK. Isol.)

EQII:

If the Control Room EFIC system has not been disabled by a fire 8HQ the RCPs are tripped IREN EFIC will automatically increase OTSG 1evels to 317 inches.

2.14 Prevent possible damage to the RCPs seal package by DEENERGIZING 6900 volt bus 6B and 6A as follows:

Device Descriotion Action 6B01 Unit Auxiliary 1.

TRIP breaker Trans. No. 1 2.

DEENERGIZE Control Power 6304 Startup Trans 1.

TRIP breaker No. I 2.

DEENERGIZE Control Power 6A01 Unit Auxiliary 1.

TRIP breaker Trans No. I 2.

OEENERGIZE Control Power 6A04 Startup Trans 1.

TRIP breaker No.1 2.

DEENERGIZE Control Power i

i Rev. 8 OP-C.13A-4 3

RESPONSE (Continued)

EQlE:

Hold points are stopping points in this procedure as listed in ENCLOSURE 5.1 (Procedure Hold Points). Certain actions are performed prior to releasing these hold points.

2.15 BBili the various Operators report the releasing of a hold point, IEEli refer to ENCLOSURE 5.1 (Procedure Hold Points)

MiQ notify the appropriate Operator (s) of the release.

EQII:

Release of hold point (0) DELTA indicates the following plant status:

EFIC Cabinets are isolated from the Control Room.

AFH HOV isolation valves are isolated from the Control Room with HV-20578/20581 OPEN AND HV-20577/20582 CLOSED.

HV-20517, "A" side ADV isolation valve, is isolated from the Control Room and is OPEN.

Bus S4A2 is energized.

P-319, AFH pump, is operating.

Under these conditions, AFH flow will be provided' to the "B"

)

OTSG. AFH flow to the "A" OTSG and operability of the ADVs may not be available due to spurious valve operation caused by the Control Room fire.

Release of hold point (E) ECHO will signify proper alignment of all AFH and ADV valves.

2.16 BEEli hold point (D) DELTA is released, IBifi:

2.16.1 Check ADVs operate in AUTO to control BOTH OTSG pressures at 1020 psig.

EQIE:

Initial feed up to the "Loss of 4 RCPs" level (317 inches) is Rate Limited to between 2.3 and 8 inches per minute depending on OTSG pressure.

2.16.2 Check FV-20527 is operating in AUTO to increase / maintain the "A" OTSG level to 317 inches.

2.16.3 Verify FV-20328 is operating in AUTO to increase / maintain the "B" OTSG level to 317 inches.

8-~

2.16.4 Notify Operator #5 that Hold Point (D) DELTA has been released.

2.17 TRIP any operating HPI pump QR Hakeup pump on 4A.

Rev. 8 OP-C.13A-5

RESPONSE (Continued)

M:

Release of hold point (E) ECHO signifies proper lineup of valves and power supplies for Emergency Feedwater and ADV isolation valves.

M:

IE at any time EFIC does not provide proper Secondary Plant Control in AUTO, M place affected components in MANUAL control per A.51

)

section for "Hanual Operation of EFIC Controlled Components" BliRE continuing with this procedure.

2.18 M hold point (E) ECHO is released, M:

2.18.1 Verify BOTH OTSG pressures at 1020 psig with AUTO control of the ADV auto / hand station.

2.18.2 Verify OTSG 1evels increasing to/ maintaining 317 inches.

M:

Release of hold point (G) GOLF signifies a recire, path for the "A" HPI/Hakeup pump has been established.

2.19 M hold point (G) GOLF is released AN_Q M the "A" HPI/Hakeup pump is electrically isolated by Control Room Operator #1, M:

2.19.1 Verify OPEN SFV-25003 (DMR Pump A Suct. from BHST) 2.19.2 Verify OPEN SFV-23508 (HL TNK isol.)

2.19.3 Direct the Control Room Operator #1 to START the "A" HPI/Hakeup pump at 4A04/4A02.

8-~

2.19.4 Direct Operator #3 to increase RCP seal injection flow to 12 gpm total flow over (5) five minutes, by manually THROTTLING OPEN FV-23606.

(use FI-23606A) 2.19.5 Throttle SFV-23811 to maintain Corrected Pressuri::er level greater than 100 inches, but less than 200 inches. Refer to ENCLOSURE 5.9 (Pressurizer Level Correction).

M:

Release of hold point (H) HOTEL signifies that the alternate HPI/Hakeup pump recirc path to the BHST has been established. This allows the Makeup Tank to be isolated.

2.20 m hold point (H) HOTEL is released, M:

2.20.1 CLOSE SFV-23508 (HU TNK isol).

8-~

2.20.2 Notify Operator #4 that Hold Point (H) HOTEL has been released.

Rev. 8 OP-C.13A-6

1 RESPONSE (Continued)

STATUS OTSG pressure is being controlled by the Atmoshperic Dump Valves at 1020 psig.

The "A" HPI/Hakeup pump is providing 12 gpm total seal injection and any l

additional requirements through SFV-23811 to maintain 100-200 inches in t

the pressurizer. The recirc flow path is back to the BHST.

i Auxiliary Feedwater Pump P-319 is providing flow to both OTSG's to increase to/ maintain a level of 317 inches.

The recirc flow path is back to the condenser hotwell.

2.21 Check for indication of Natural Circulation as follows:

RCS subcooled (50*F-100*F)

RCS AT less than 100'F l

TH and TC Track changes in OTSG secondary side TC slightly higher than OTSG Tsat 2.21.1 IE RCS Subcooling margin decreases to 1 50*F Q8 RCS AT approaches 100*F 4

IHEN GQ IQ E.01, "Immediate Actions."

i 1

HQIE:

Pressurizer level will continue to increase 30 inches per hour due to Reactor Coolant Pump seal injection.

2.22 Cooldown using the Atmospheric Dump Valves to maintain pressurizer level at 100-200 inches. Do not reduce RCS Tave below 525'F.

1 Rev. 8 OP-C.13A-7 i

RESPONSE (Continued) 2.23 Check off the following after the various Operater Actions are completed:

Initials / Time Ooerator Enclosure Actions Comoltigd Control Room Operator No.1 5.3

/

Remarks:

Control Room Operator No. 2 5.4

/

Remarks:

8-Operator No. 3 5.5

/

Remarks:

Operator No. 4 5.6

/

Remarks:

i Operator No. 5 5.7

/

Remarks:

l Operator No. 6 5.8

/

~

Remarks:

3.0 RECOVERY j

3.1 BBIH all Enclosures per Step 2.23 above are complete, IEEH GQ IQ OP-C.138 "Remote Cooldown".

4.0 REFERENCES

4.1 IMPLEHENTING REFERENCES 4.1.1 EPIP-5001, Recognition and Classification of Emergencies 4.1.2 EPIP-5010, Notification / Communication 4.1.3 EPIP-5345, Onsite Radiological Monitoring 4.1.4 EPIP-5430, Control Room Dose Calculation 4.1.5 Fire Pre Plans, Vol. I 4.1.6 OP-C.138, Remote Cooldown 4.1.7 E.01. Immediate Actions Rev. 8 OP-C.13A-8

4.2 OEVELOPMENTAL REFERENCES 4.2.1 10CFR50 Appendix R 4.2.2 B & H Appendix R Evaluation 4.2.3 8 & H Doc ID 86-1152757-00 Depressurization Through

-Pressurizer Heat loss 4.2.4 8 & H Doc ID 51-1153689-00 Natural Circulation Cooldown 4.2.5 8 & H Doc ID 32-1157288-00 RCP Seal Thermal Analysis 4.2.6 8 & H Doc ID 32-1158380-00 SBLOCA Analysis 4.2.7 8 & H Doc ID 51-1156621-00 Breaker Evaluation 4.2.8 B & H Doc ID 51-1156749-00 Source Range Qualification 4.2.9 B & H Doc ID 86-1157247-01 Cycle 7 Boration Data 4.2.10 B & H Doc ID 32-1158433 BHST Boration Shutdown 4.2.1),

IMPELL Calc No. Z-FPP-H2089 Cl3A & B Changed Due to Plant Hodification 4.2.12 RJR-527 Letter to the NRC, Alt. Shutdown Capability 4.2.13 Licensee Event Report #87-02 5.0 ENCLOSURES 5.1 Procedure Hold Points 5.2 Shift Supervisor Actions 5.3 Control Room Operator No. 1 Actions 5.4 Control Room Operator No. 2 Actions 8-5.5 Operator No. 3 Actions 5.6 Operator No. 4 Actions 5.7 Operator No. 5 Actions 5.8 Operator No. 6 Actions 5.9 Pressurizer Level Correction 5.10 Saturated Pressure / Temperature Table 5.11 Normally Deenergized Appendix R. Valves Rev. 8 OP-C.13A-9

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ENCLOSURE 5.2 SHIFT SUPERVISOR ACTIONS E:

EPIP-5001 Tab 12 (Loss of Control Room) QR Tab 17 (Fire) will normally be the initiating event; Site Area Emergency will normally be the action level unless other more restrictive initiating events occur.

E:

The actions of this enclosure will be carried out in the West 4160V Switchgear Room.

8-E:

Emergency Communication equipment is available in junction box H7T566 located next to Shutdown Panel.

1.

Review current plant conditions and the Emergency Plan EPIP-5001 for declaration of an emergency classification.

2.

Direct security to:-

1.

Fall open all security doors.

B 2.

Restrict access of Turbine Deck, Turbine Building, and Tank Farm area to all personnel except operators.

3.

Relocate Design City personnel to the main SMUD building on S Street.

4.

Close the Visitors Center.

E:

The Chemistry Technician can be used as the Plant Assembly Point Coordinator.

3.

Select an assembly point upwind of the cooling tower plume.

4.

The Emergency Siren is not available. Repeat the page system notification ANNOUNCEMENT (3) three times.

5.

The Coverage / Sample HP not being used as a member of the Fire Brigade should perform onsite radiological monitoring in accordance with EPIP-5345. Cooling Tower plume direction should be used to determine survey area.

6.

If additional people are available, M a Technical Report Coordinator can be assigned.

7.

M hold point (A) ALPHA is released, 8--

M Operator #6 shall assume the position of Communicator.

8.

Direct the Communicator to make the notification calls in accordance with EPIP-5010 to the State, Counties and NRC. You will ffQI be able to maintain constant communications with the NRC.

9.

Direct the Communicator to use the 111 number, requesting Galt and Herald Fire Department support.

ENCLOSURE 5.2 PAGE 1 0F 2 Rev. 8 OP-C.13A-11

+-

y p

t

-+

w---

ENCLOSURE 5.2 (Continued)

SHIFT SUPERVISOR ACTIONS

10. Direct the Dispatcher or Phone Operator to make the callouts required for full activation of the E0F.
11. Ensure The Fire Brigade has assembled and is combating the fire.

Refer to the Fire Pre Plans, Vol I, Zone 4A/48.

12. BBEM the Onsite Radiological Monitoring HP reports back with dose information, IHEM notify the required offsite agencies of the dose determination based on field measurement in accordance with EPIP-5430.

l I

ENCLOSURE 5.2 PAGE 2 0F ?

Rev. 8 OP-C.13A-12

ENCLOSURE 5.3 CONTROL ROCH OPERATOR NO. 1 ACTIONS EQII:

Identification tags associated with this enclosure will be a light green color.

8-~

EDII:

The Shutdown Panel telephone extension is X4286.

Device Descriotion Action 480 VOLT WEST SWITCHGEAR ROOM 1.

2A183 2A1 Equipment Isolation Panel Place to ISOLATE the following:

1. SFV-23508
2. SFV-25003
3. HV-20517 2.

2A121 Hakeup Pump Recire. Isolation Place breaker OFF SFV-23645 3.

2A108 Loop "A" ADV Isolation Valve

1. Verify breaker ON HV-20517
2. Verify valve OPEN 4.

2A144 RB Spray Pump P-291A Dis Place breaker OFF i

Valve SFV-29107 i

5.

Disconnect EHOV PSV-21511 OPEN disconnect i

l switch 6-3 in H3CRR rear 6.

Disconnect Pegging Steam Solenoids OPEN disconnect switch 3-3 in H3CRR front 7.

3C35 Control Rod Drive Power

1. TRIP breaker
2. Turn control power OFF 1

8.

1E12 Turb. Misc Control Place breaker 0FF (Reheater Panel Power) i ENCLOSURE 5.3 PAGE 1 0F 6 Rev. 8 OP-C.13A-13

ENCLOSURE 5.3 (Continued)

CONTROL ROOM OPERATOR NO. 1 ACTIONS Device Descriotion Action HEST DC BUS ROOM 9.

H7ISFV23811 SFV-23811 Isolation Switch Place to ISOLATE

10. 72-C03 SFV-23604 Place breaker OFF 11.

72-C05 SFV-23809 Place breaker OFF

12. 72-A04 Diesel Eng GEA Control Cab Verify breaker ON
13. 72-A08 4160V SHGR Bus 4A Verify breaker ON
14. 72-A07 Diesel Gen GEA Control Cab Verify breakDr ON EAST DC BUS ROOM
15. 72-D03 SFV-23810 Place breaker OFF 16,72-005 SFV-23812 Place breaker OFF
17. 72-801 SFB Solenoids Place breaker OFF
18. Contact the Assi'stant Shift Supervisor and state "HOLD POINT (B) BRAVO IS RELEASED", and continue with this Enclosure.

HEST 4160 VOLT SWITCHGEAR ROOM 19, 4A00 Bus Loading / Shedding Control Place isolation switch Circuitry isolation to ISOLATE l

ENCLOSURE 5.3 PAGE 2 0F 6 Rev. 8 OP-C.13A-14

, - - ~,.-

l ENCLOSURE 5.3 (Continued)

CONTROL R00H OPERATOR NO. 1 ACTIONS HQII:

IE Offsite power IS NOT available, IHIH release of hold point (C) CHARLIE signifies the "A" Diesel Generator is running.

8Q11:

IE Offsite power IS available, IH1H release of hold point (C) CHARLIE signifies the "A" Diesel Generator is isolated.

Device Descriotion Action

20. STOP, BHIH hold point (C) CHARLIE is released, IHEH continue.
21. 4A01 Nuclear Services Supply Trans
1. Place Brkt 52-4A01 X74 Iso. Switch 43 to -ISOLATE
2. OPEN all test disconnect switches
3. IE breaker 4A01 is CLOSED

&HQ Offsite Power is available, 181H verify Diesel Generator output breaker 4A08 is OPEN

4. IE breaker 4A01 is CLOSED

&HD Offsite Power is NOT available, IBIH TRIP breaker 4A01.

22. 4A10 Startup No. 2 Transformer X94
1. TRIP breaker
2. DEENERGIZE control

-i power i

23. 4A08 Diesel Generator GEA
1. Place H2ES panel isolation control switch to ISOLATE
2. OPEN all test disconnect switches
3. IE Offsite Power is not available IBIN verify breaker 4A08 CLOSED ENCLOSURE 5.3 PAGE 3 0F 6 i

Rev. 8 OP-C.13A-15

ENCLOSURE 5.3 (Continued)

CONTROL R00H OPERATOR N0. 1 ACTIONS Device Descriotion Action

24. 4A0s Station Service Transformer
1. Place Control Room X43A isolation switch to ISOLATE
2. Verify breaker CLOSED
3. OPEN all test disconnect switches
25. 4A05 Decay Heat Removal Pump P-261A
1. Place Control Room isolation switch to ISOLATE
2. Verify breaker OPEN
3. OPEN all test disconnect switches
26. 4A07 NS Raw Hater Pump P-472A
1. Place Control Room isolation switch to ISOLATE
2. Verify braaker CLOSED
3. OPEN all test disconnect switches
27. IE P-238A HPI injection pump is Under Clearance QR IS NOT Operable 1H18 perform this step, otherwise continue.

4A02 Reactor Make-Up Pump P-236 alt

1. Place Control Room isolation switch to ISOLATE
2. OPEN all test disconnect switches
3. GO TO Step 31
28. 4A04 HP Injection Pump P-238A
1. Place Control Room isolation switch to ISOLATE
2. OPEN all test disconnect switches
29. 4A02 Reactor Make-Up Pump P-236 alt
1. Place Control Room isolation switch to ISOLATE
2. TRIP breaker
30. Notify the Assistant Shift Supervisor that the "A" HPI/ Makeup pump is electrically isolated.

ENCLOSURE 5.3 PAGE 4 0F Rev. 8 OP-C.13A-16

ENCLOSURE 5.3 (Continued)

CONTROL ROOM OPERATOR NO. 1 ACTIONS

31. Ei!iEH hold point (G) GOLF is released, IliEfi you will be directed to start the "A" NPI/ Makeup pump. 00 NOT WAIT for this hold point to be released. Continue with this enclosure, 1

EAST 4160 VOLT SHITCHGEAR

32. 4804 Nuclear Service Transformer X74
1. TRIP breaker
2. DEENERGIZE control power
33. 4801 Startup No. 2 Transformer X94
1. TRIP breaker
2. DEENERGIZE control power DIE:

The purpose of the remainder of this enclosure is to isolate any running PCH, CCH, CRD, and Condensate pump j

if Offsite Power is available. This will prevent damage to secondary plant components.

34. IE 4160 Volt bus 4D is deenergized OR the PCW pump A M the CCH pump breakers are OPEN i

IliEH isolate the bus as follows.

1. 4D10 Unit Aux TFHR No. 2 X84
1. TRIP breaker
2. DEENERGIZE control power l
2. 4001 Start-Up Trans No. 2 X94
1. TRIP brtaker
2. DEENERGIZE control power
35. IE 4160 Volt bus 4C is deenergized QB the PCH pump A E the CCH pump breakers are OPEN IliEM isolate the bus as follows (West 4160 Volt Switchgear Room):
1. 4C10 Unit Aux. TFHR No. 2 X84
1. TRIP breaker
2. DCENERGIZE control power
2. 4C01 Start-up Trans No. 2 X34
1. TRIP breaker
2. DEENERGIZE control power MII:

Control and protection of the primary plant takes' priority over the secondary plant.

36. IE the Assistant Shift Supervisor does not require your support at this time to control the plant IBIH complete the remainder of this enclosure.

ENCLOSURE 5.3 PAGE 5 0F 6 Rev. 8 OP-C 13A-17

ENCLOSURE 5.3 (Continued)

CONTROL ROOH OPERATOR NO. 1 ACTIONS Qggitg Descriotion Action

37. IE 4160 Volt bus 4C A!!Q 40 are fatr9'Zid at this time, IHIH Deenergize bus 40 as follows (E2st 4160 Volt Switchgear Room):
1. 4010 Unit Aux. TFHR No. 2 X84
1. TRIP breaker
2. DEENERGIZE control power
2. 4001 Start-Up Trans No. 2 X94
1. TRIP breaker
2. DEENERGIZE control power
38. IE 4160 Volt bus 4C QR (40) is still eneraized at this time, IHIH perform the following:
1. 4C10 (4010) Unit Aux TFHR No. 2 X84
1. TRIP breaker
2. DEENERGIZE control power
2. 4C09 (4D08) Station Service TFHR
1. TRIP breaker
2. DEENERGIZE ~

control power

3. 4C04 (4007) Heater Drain Pump
1. TRIP breaker
2. DEENERGIZE control power 4.

(4D04) X4303 Reservoir HCC

1. TRIP breaker
2. DEENERGIZE control power 8-~
5. TRIP breaker AND DEENERGIZE control power for all load breakers on energized switchgear 3C2 QR (3D2) except HCC 2C4/(204) supply breakers 3C43/(3024).
6. Periodically check continued operation of the PCH, CCH, Condensate, and CRD pumps.
39. Standby in the aren until you are notified to start the "A" HPI/HU Pump.

8-~

40. 8818 the "A" HPI/MU Pump is running, IBIH notify the Assistant Shift Supervisor that Control Room Operator No. 1 Actions are complete.

AHD follow his directions.

ENCLOSURE 5.3 PAGE 6 0F 6 R9v. 8 OP-C.13A-18

\\

~

l

ENCLOSURE 5.4 CONTROL ROOH OPERATOR NO. 2 ACTIONS HQIE:

Identification tags associated with this enclosure will be a light orange color.

8-~

HQII:

The Shutdown Panel telephone extension is X4266.

HEST 4160 VOLT SWITCHGEAR Device pascriotion Action 1.

H85HV-20581 HV-20581 "A" Steam Gen Aux

1. Place isolation Feedwater Valve switch to ISOLATE
2. OPEN valve.

2.

H8SHV-20578 HV-20578 "B" Steam Gen Aux

1. Place isolation Feedwater valve.

switch to ISOLATE

2. OPEN valv,e EAST 4160 VOLT SWITCH (iEAR 3.

H8SHV-20582 HV-20582 "8" Steam Gen Aux

1. Place isolation Feedwater Valve switch to ISOLATE
2. CLOSE Valve 4.

H85HV-20577 HV-2057/ "A" Steam Gen Aux

1. Place isolation

~

Feedwater valve, switch to ISOLATE

2. CLOSE valve NEST NSEB HEZZANINE ELEVATION 5.

A EFIC isolation Isolation Switch Place to ISOLATE switch 43-3 at For EFIC indications H7IFHA1 6.

A EFIC isolation Isolation Switch Place to ISOLATE switch 43-2 For EFIC Controls at H7IFHA1

& ADV Control 7.

A EFIC isolation Isolation Switch Place to ISOLATE switch 43-1 for EFIC control at H71 FHA 1 ENC 10$t;RE 5.4 PAGE 1 0F 5 Rev. 8 OP-C.13A-19 i

.,m__

ENCLOSURE 5.4 (Continued)

CONTROL ROOH OPERATOR NO. 2 ACTIONS Device Descriotion Action NSEB HEZ[ANINE ELEVATION EAST 8.

B EFIC isolation Isolation Switch Place to ISOLATE switch 43 at For EFIC Indication H7IFHB1

& ADV Control NSEB GPADE ELEVATION EAST 4160 VOLT ROOM 9.

2B301 HV-31826 Aux Feedwater X-tie Place to 0FF NSEB GRADE ELEVATION WEST 4160 VOLT ROOM

10. SOA205 4160 Switchgear 4A2 Control Verify breaker ON
11. SOA207 4160 Switchgear Verify breaker ON '

0/U voltage relays

12. SOA211 480V Load Center 3A2 Verify breaker ON 13.

SCA202 Diesel Generator A2 Verify breaker ON Engine Control Panel

14. SOA204 Diesel Generator A2 Verify breaker ON Engine Control Panel
15. SOA206 OSL Gen Cont PNL Verify breaker CN H20GA2 field flash
16. SOA208 Diesel Generator Verify breaker ON Control Panel H2DGA2
17. 4A202 TDI Diesel Generator Supply 1. Place "DG GEA2 Cont.

Breaker Rm CKTS" isolation SH 43 to ISOLATE (Ref 4.2.13) 8-

2. Verify "Isolation Switch" 43A is positioned to ISOLATE.

18, 4A203 Startup Xfmer #2

1. Place 125 VDC iso.

Supply Breaker SH 43 to ISOLATE (Ref 4.2.13)

2. TRIP breaker
19. 4A201 Bus Loading /Shed Cont, iso Place the isolation switch to ISOLATE (Ref 4.2.13) 1 ENCLOSURE 5.4 PAGC 2 0F
  • Rev. 8 OP-C.13A-20

-l

ENCLOSURE 5.4 (Continued)

CONTROL ROOH OPERATOR NO. 2 ACTIONS Device Descriotion Action 20, 4A207 Startup Xfmer #1 Supply Place isolate switch Breaker 43 to ISOLATE (Ref 4.2.13)

21. Verify 4A2 bus is energized from Startup Xfmer #1 QR frcm GEA2 TOI Diesel Generator.

22, 4A205 P-319 Aux Feedwater Pump

1. Place 43 isolation switch to ISOLATE (Ref 4.2.13)
2. Verify breaker CLOSE0
3. OPEN all test disc switches.
23. Contact the Assistant Shift Supervisor and state "RELEASE HOLD POINT (0)

DELTA."

24. 4A204 4160 Volt bus 4A2 to
1. Place the iso switc'h 480 Volt bus 3A2 43 to ISOLATE (Ref 4.2.13)
2. Verify breaker CLOSED
3. OPEN test disc switches.

25, 4A210 HISS Panel Isolation

1. Place-the isolate switch for Aux feedwater switch to ISOLATE. (Ref 4.2.13)

X-tie HV-31827

26. 3A202 480 Volt bus 3A2 from 4A2
1. Place the isolate switch to ISOLATE (Ref 4.2.13)
2. Verify breaker CLOSED
3. OPEN test disc switches 27, 3A206 HCC 2A2 Supply
1. TRIP breaker
2. PULL control power

)

fuses 28, 3A210 "A" CR/TSC ESS

1. TRIP breaker
2. PULL control power fuses i
29. 2A301 Aux Feedwater X-Tie
1. Verify valve OPEN.

HV-31827

2. Verify 0FF.

1 ENCLOSURE 5.4 PAGE 3 0F 5 l

Rev. 8 i

OP-C.13A-21 l

ENCLOSURE 5.4 (Continued)

CONTROL ROOH OPERATOR NO. 2 ACTIONS Device Descriotion Action NSEB GRADE ELEVATION EAST 4160 VOLT ROOM

30. 48203 Startup Transf
1. TRIP breaker No. 2
2. PULL control power fuses 31, 48207 NSS Transf X74
1. TRIP breaker
2. PULL control power fuses 32.

SOB 203 HV-30801 AFH Pump P-318 Turbine Inlet Valve Place breaker OFF

33. S08205 Control Power to 482 Switchgear Place breaker OFF
34. SOB 207 Power to UV Relays for j

482 Bus Place breaker OFF

35. S08211 Control Power to 382 Switchgear Place breaker OFF 36.

S08202 DG GEB2 Engine Control

~~

Panel (H20EB2) "A" Power Place breaker OFF

37. S08204 DG GEB2 Engine Control Panel (H20EB2) "B" Power Place breaker OFF
38. 508206 DG GEB2 Field Flashing (H20GB2)

Place breaker OFF

39. 508208 DG GEB2 Generator Control Panel Place breaker OFF ENCLOSURE 5.4 PAGE 4 0F Rev. 8 OP-C.13A-22

ENCLOSURE 5.4 (Continued)

CONTROL ROOH OPERATOR NO. 2 ACTIONS Device Descriotion Action NSEB 40' ELEVATION EAST -

40. GB-107 Mag Tape Place breaker "0FF"
41. GB-109 EL & TSC Consoles Place breaker "0FF"
42. GB-111 EFI "0" H4 FWD Verify "0N"
43. GB-115 PCI-10IS of I/O Cab Place breaker "0FF"
44. GB-117 Mag Disc Place breaker "0FF"
45. GB-119 Hod Comp CPU Place breaker "0FF"
46. GB-121 H20EB2 Cont Pwr Place breaker "0FF"
47. GB-125 H2DGB2 Gen Cont Pn1 Place breaker "0FF"
48. GB-106 Analog input Place breaker "0FF" i
49. GB-108 Mag Tape Place breaker "0FF"
50. GB-110 TSC Consoles Place breaker "0FF" i
51. GB-112 Main Steam Train B Place breaker "0FF" pressure instr.
52. GB-114 Display Gen Place breaker "0FF"
53. GB-116 Printer Term Place breaker "0FF" i
54. GB-118 Mag Disc Place breaker "0FF"
55. GB-120 Bailey interface Place breaker "0FF" i
56. Notify the Assistant Shift Supervisor that Control Room Operator No. 2 j

Actions are complete.

57. IE no further directions are given, i

IBIN report to the Shutdown Panel.

i ENCLOSURE 5.4 PAGE 5 0F 5 Rev. B OP-C.13A-23

ENCLOSURE 5.5 OPERATOR NO. 3 ACTIONS HQIE:

Identification tags associated with this enclosure will be a light orange color.

8-~

EQII:

The Shutdown Panel telephone extension is X4286.

Device Descriotion Action AUXILIARY BUILDING GRADE LEVEL 1.

20430 Letdown to MU or Flash Tank Place breaker OFF

. Valve HV-23004 2.

HV-23004 Letdown to HU or Flash Tank OPEN to Valve Flash Tank AUXILIARY BUILDING -20' ELEVATION 3.

PLS-049 Supply to Decay Heat Pumps OPEN Valve P-261A and B NEST 000LER ROOM 4.

STOP BREN hold point (B) BRAVO is released, IHIM continue.

5.

SFV-23809 HP Injection Supply to A Verify CLOSED Loop 6.

SFV-23604 RCS System makeup Isolation CLOSE Valve l

EAST COOLER ROOM 7.

FV-23606 RCP seal injection flow

1. Run hand wheel in Control Valve to prevent additional opening
2. ISOLATE air supply and OPEN vent on regulator
3. CLOSE Valve 8--

8.

FI-23606A Seal Inject Flow Meter Place in service ENCLOSURE 5.5 PAGE 1 0F 3 Rev. 8 OP-C.13A-24

ENCLOSURE 5.5 (Continued)

OPERATOR NO. 3 ACTIONS Device Descriotion Action 9.

SFV-23810 HP Injection Supply to 8 Verify CLOSED Loop

10. SFV-23812 HP Injection supply to B Verify CLOSED Loop 11.

SFV-24013 Seal return isolation Verify CLOSED outside

12. SFV-22009 Letdown isolation outside Verify CLOSED MAKE UP PUMP ROOM
13. H8SFV-23508 SFV-23508 Key Selector Place to (normal JUNCTION BOX Switch power supply) ON
14. SFV-23645 HPI/Hakeup pump mini flow Verify OPEN,
15. STOP M hold point (F) FOXTROT is released M continue.
16. SFV-23646 HPI/Hakeup Pump Miniflow Verify OPEN
17. Contact the Assistant Shift Supervisor and state "RELEASE HOLO POINT (G)

GOLF."

EAST COOLER ROOM

18. SFV-26040 DH Cooler E-2608 Outlet Verify OPEN
19. HV-26047 DH B to A Loop Crosstie OPEN valve
20. HV-26046 OH A to B Loop Crosstie Verify CLOSED 21.

OHS-033 DH A and B Loop Test Line OPEN valve to BWST

22. SFV-23616 RCP Seal Supply Isolation Verify OPEN 1

Valve

23. SFV-29108 8 Loop Butiding Spray Verify CLOSED Injection ENCLOSURE 5.5 PAGE 2 0F 3 Rev. 8 OP-C.13A-25

ENCLOSURE 5.5 (Continued)

OPERATOR NO. 3 ACTIONS Dev. ice Descriotion Action

24. Contact the Assistant Shift Supervisor and state "RELEASE HOLD POINT (H)

HOTEL."

25. STOP, BREH notified by the Assistant Shift Supervisor to begin increasing RCP injection flow to 12 gpm total flow,

)

IREN continue.

26.

FV-23606 RCP Seal Injection Flow Over a (5) five Control Valve minute period increase seal injection to 12 gpm total (use FI-23606A)

27. Check proper operation of the operating "A" HPI/HU pump:

bearings not hot to touch vibration not excessive steady discharge pressure 2500 - 3000 psig suction pressure greater than 10 psig a

8-~

28. Notify the Assistant Shift Supervisor that Operator No. 3 Actions are f

complete.

29. If no further directions are given IHEN report to the grade level of the Auxiliary Building controlled area i

and perform a whole body frisk, AND report to the Shutdown Panel.

ENCLOSURE 5.5 PAGE 3 0F 3 Rev. 8 OP-C.13A-26

ENCLOSURE 5.6 OPERATOR NO. 4 ACTIONS E0ll:

Identification tags associated with this enclosure will be a light orange color.

l 8--

NOTE:

The Shutdown Panel telephone extension is X4286.

Device Descriotion Action i

HEST 480 VOLT SWITCHGEAR ROOM 1.

2A102 HP Injection PP P-238A

1. Place isolate switch L0 Pump to ISOLATE
2. START pump j

2.

2A138 LP Injection to Loop A Place breaker OFF SFV-26005 3.

2A140 Cooling Htt to OH Clr Place breaker 0FF l

E-260A SFV-26017 4.

2A141 Cooling Htr from DH Clr Place breaker OFF E-260A SFV-26019 5,

2A147 C1g Htr to RB Emerg Place breaker OFF C1g A500A SFV-50005 6,

2A148 C1g Htt to RB Emerg Place breaker OFF

)

t C1g A500C SFV-50007 7.

2A149 Clg Htr from RB Emerg Place breaker OFF Clg A500A SFV-50009 8.

2A150 Clg Htt from RB Emerg Place breaker OFF Clg A500C SFV-500ll 9.

2A160 OTSG E205B to Aux Stm Place breaker OFF j

Hdr HV-20560

10. 2A164 Decay Heat Crosstie A Place breaker OFF HV-26046 i

ENCLOSURE 5.6 PAGE 10F 3 Rev. 8 OP-C.13A-27

-,9,,e

ENCLOSURE 5.6 (Continued)

OPERATOR NO. 4 ACTIONS Device Descriotion Action j

11, 2A101 Hakeup pump P.236 L 0

1. Verify breaker Pump (alt)

CLOSED

2. START pump 12.

3A05 Station Service TFMR X43A

1. Place Control Room isolation switch to ISOLATE
2. Verify breaker 1

CLOSED 13, 3A09 Reactor Bldg Spray Pump

1. TRIP breaker P-291A
2. OEENERGIZE control power 14.

3A10 Nuclear Service Air Cooler

1. CLOSE breaker i

A-500A

2. OEENERGIZE control p,ower 15, 3A14 Nuclear Service Air Cooler
1. CLOSE breaker A.500C
2. DEENERGIZE control power 16.

3A18 Nuclear Service C1g Htr

1. CLOSE breaker w F 1824
2. DEENERGIZE control power EAST 480 VOLT SWITCHGEAR ROOM 17.

3805 Station Service

1. TRIP breaker Transformer X43B
2. DEENERGIZE control power
18. Contact the Assistant Shift Supervisor and state "RELEASE HOLD POINT (F)

FOXTROT."

AUXILIARY BUILDING GRADE LEVEL l

19.

STOP, M hold point (H) HOTEL is released M continue.
20. PLS-044 Supply to Hakeup Tank CLOSE valve Stop-Check Valve ENCLOSURE 5.6 PAGE 2 0F 3 Rev. 8 OP-C.13A-28

l ENCLOSURE 5.6 (Continued) i OPERATOR NO. 4 ACTIONS Device Descriotien Actiort i

EAST COOLER ROOM 1

21. HV-26008 DH to HP Injection Pump Verify CLOSED P-2388 WEST COOLER ROOM
22. SFV-26017 DH Removal Cooler E-260A Verify THROTTLED NSW Inlet Valve
23. SFV-26019 DH Removal Cooler E-260A Verify THROTTLE 0 NSW Outlet Valve
24. HV 20611 OTSG Drain Isolation Verify CLOSED i

Outside RB

25. SFV-29107 A Loop Building Spray Verify CLOSED Injection
26. SFV-50005 RB Emergency Cooling Unit Verify OPEN A-500A NSH Inlet Valve
27. SFV-50011 RB Emergency Cooling Unit Verify OPEN A-500C NSW Outlet Valve
28. SFV-50007 RB Emergency Cooling Unit Verify OPEN A-500C NSH Inlet Valve
29. $FV-50009 RB Emergency Cooling Verify OPEN Unit A-500A NSW Outlet Valve AUXILIARY BUILDING GRADE LEVEL
30. MCC 2C4 Motor Control Center Place all breakers (except 2C401) to "0FF"
31. MCC 2D4 Motor Control Center Place all breakers (except 2D401) to "0FF" 8--
32. Notify the Assistant Shift Supervisor that Operator No. 4 actions are complete.
33. IE no further directions are given, Illiti perform a whole body frisk AtiQ report to the shutdown panel.

ENCLOSURE 5.6 PAGE 3 0F 3 Rev. 8 OP-C.13A-29

ENCLOSURE 5.7 OPERATOR NO. 5 ACTIONS HQII:

Identification tags associated with this enclosure will be a light orange color.

8-~

NOTE:

The Shutdown Panel telephone extension is X4286.

Device Descriotion Action OUTSIDE THE "B" DIESEL GENERATOR ROOM 1.

H8PG8868 "B" Diesel Generator Remote DEPRESS pushbutton Emergency stop pushbutton "A" DIESEL GENERATOR ROOM. PANEL H2DGA 2.

"H2SFA Panel Isolation Switch Place to ISOLATE Isolation Control Switch 43A" 3.

"H2ES Panel Isolation Switch Place to ISOLATE Isolation Control Switch" 4.

"Control Room P-888A Fuel Oil Transfer Place to ISOLATE Isolation Switch Pump Isolation Switch 43B" 5.

IE a loss of offsite power has occurred 6HQ the "A" Diesel Generator is not running, IHEN

1. On the Generator panel HEOGA placa che reDcte-local control switch to LOCAL:
2. On the Engine panel H7J272 DEPRESS the maintenance start push button.
3. Check the "A" Diesel Gensrator STARTED.
4. IE the "A" Diesel Generator has HQI STARTED, IBIH notify the Assistant Shift Supervisor.

6.

Contact the Assistant Shift Supervisor and state, "RELEASE HOLD POINT 1

(C) CHARLIE."

TAMK FARM HEZZANINE 7.

STOP, HREN hold point (F) FOXTROT is released, IHER continue, 8.

HV-20518 B Loop ADV Isolation Verify OPEN l

AUX FEEDHATER PUMP MISSILE CAGE f

9.

STOP, WHIH hold point (D) DELTA is released, IHIH continue.

ENCLOSURE 5.7 PAGE 1 0F 3 i

Rev. 8 1

OP-C.13A-30 v

s W--

eyw-----

,,,3__.

ENCLOSURE 5.7 (Continued)

OPERATOR NO. 5 ACTIONS Device Descriotion

&ttlan

10. HV-31826 Auxiliary Feed Header Verify OPEN Cross Connect Isolation
11. P-318 Steam Drive Aux Feedwater TRIP overspeed device Pump 8-
12. Contact the Assistant Shift Supervisor and state, "RELEASE HOLO POINT (E) ECHO" and continue with this Enclosure.

TRANSFORMER AREA GRADE

13. 4E13 Start Up XFMR2
1. TRIP breaker
2. OEENERGIZE control power
14. 4E07 Unit Aux. XFMR2
1. TRIP breaker 1
2. OEENERGIZE control power
15. 4E06 Start Up XFMR2
1. TRIP breaker
2. OEENERGIZE control power
16. 4E01 Bus 4E Normal Supply
1. TRIP breaker
2. DEENERGIZE control power lialjf, FEED PUMP CONSOLES 17.

"B Turbine Trip Trip Indication Check ON Light" 18.

"A Turbine Trip Trip Indication Check ON Light" i

19. LE Both Main Feed Pu;nps are NOT tripped 181H for any non-tripped MFP:
1. OEPRESS the Turbine Trip Button
2. Check Turbine Trip Light ON.

i ENCLOSURE 5.7 PAGE 2 0F 3 Rev. 8 OP-C.13A-31 l

)

ENCLOSURE 5.7 (Continued)

OPERATOR NO. 5 ACTIONS Device Descriotion Action TURBINE BUILDING MEZIANINE

20. HV-20560 "B" Main Steam to Main Verify CLOSED Feed Pump Turbine and to Aux Steam Header
21. HV-20565 "A" Main Steam to Main Verify CLOSED Feed Pump Turbine and to Aux Steam Header B DIESEL FENERATOR RCON
21. EGS-546 Main DC Airstart "CLOSE" valve Isolation Valve
22. EGS-550 Main AC Airstart "CLOSE" valve Isolation Valve
23. Depress "B" Diesel Generator emergency stop pushbutton on panel H7J273.
24. IE the "B" Diesel Generator will not stop J

IBIH pull out the Manual fuel rack lever until the engine stops.

NORTH TURBINE LAYDOWN AREA i

25. C9000 Diesel Air Compressor
1. Verify diesel is running i
2. Verify Instrument air pressure greater than 95 psig (PI-91504 Turbine Bldg. Grade Level near Turbine Lube Oil Coolers.)

i 8-~

26. Notify the Assistant Shift Supervisor that Operator No. 5 Actions are complete.

i

27. IE no further directions are given IH1H report to the Shutdown Panel.

i ENCLOSURE 5.7 PAGE 3 0F 3 Rev. 8 OP-C.13A-32

ENCLOSURE 5.8 OPERATOR NO. 6 ACTIONS 8-~

NOTE:

The Shutdown Panel telephone extension is X4286.

JURBINE DECK 1.

Manually TRIP the Main Turbine at the front standard.

"B" TDI DIESEL GENERATOR CONTROL ROOM If the "B" TDI Diesel Generator is running 2.

IEN shutdown the Diesel By performing the following at panel H20EB2:

Depress the LOCA RESET pushbutton.

Simultaneously depress both EMERGENCY STOP pushbuttons.

8-~

3.

Contact the Assistant Shif t Supervisor and state, "RELEASE HOLD POINT (A) ALPHA."

4.

Report to the Shift Supervisor in the West 4160 Volt Switchgear Room and assume the position of Comunicator.

l ENCLOSURE 5.8 PAGE 1 0F 1 Rev. 8 OP-C.13A-33

l ENCLOSURE 5.9 l

PRESSURIZER LEVEL CORRECTION EQIE:

The following conversion chart assumes the pressurizer is saturated.

1.

Locate the current RCS pressure on the X axis and the indicated pressurizer level on the Y axis.

The intersection of the two values is actual pressurizer level.

  • indicates out of range value RCS PRESSURE

_12000sia 20000sia 18000sia 16000sia 1200esia 8000 sic 4000 sic 2000sta 310 inches r

300 inches.

290 inches 322 280 inches 311 270 inches 315 299 260 inches 303 288 250 inches 314 290 277 240 inches l

323 302 278 265 230 inches 308 288 266 254 l

220 inches 328 317 294 274 254 242 l

210 inches 326 311 301 279 261 242 231 200 inches 190 inches 323 308 294 285 264 248 230 220 180 inches 304 289 277 269 250 234 218 208 170 inches 284 271 260 252 235 221 206 197 _

i 160 inches 264 253 243 236 221 208 194 185 150 inches 245 235 226 220 206 195 182 174 1

l 140 inches 225 216 208 204 191 181 169 163 l

130 inches 205 198 191 188 177 168 157 151 ENCLOSURE 5.9 PAGE 1 0F 2 l

l Rev. 8 OP-C.13A-34 l

l

i ENCLOSURE 5.9 (Continued)

PRESSURIZER LEVEL CORRECTION

  • indicates out of range value 22000sia 20000sia 1800ctia 1600csia 1200csia 800csia 4000sia 2000sia 120 inches 185 180 174 171

_ 162 155 145 140 110 inches 166 161 157 155 148 141 133 128 100 inches 146 143 140 139 133 128 121 117 90 inches 126 125 123 123 118 115 109 106 80 inches 107 106 106 107 104 101 97 94 70 inches 87 88 89 90 89 88 85 83 60 inches 67 70 72 74 75 75 73 71 50 inches 48 52 55 58 60 62 61 60 J

40 inches 28 33 37 42 45 48 48 49 f

30 inches 8

15 20 26 31 35 36 37 3.2 9.4 16 22 24 26 i

20 inches 1.6 8.3 12 14 10 inches

\\

\\

f i

f l

ENCLOSURE 5.9 PAGE 2 0F 2 flev. 8 OP-C.13A-35 i

i

i ENCLOSURE 5.10 SATURATED PRESSURE / TEMPERATURE TABLE Pressure Temperature Pressure Temperature (PSIG)

('F)

(PSIG)

(*F) 2400 663 1200 569 2350 660 1150 563 2300 657 1100 558 2250 653 1050 552 2200 651 1000 547 2150 647 950 540 2100 644 900 534 2050 640 850 527 2000 637 800 521 1950 633 750 512 1900 630 700 506 1850 626 650 497 1800 622 600 490 1750 618 550 479 1700 615 500 471 1650 610 450 459

]

1600 606 400 449 1550 602 350 435 1500 598 300 42?

1450 593 250 406 1400 589 200 388 1350 583 150 366 1300 579 100 338 1250 573 50 298 ENCLOSURE 5.10 PAGE 1 0F I

Rev. 8 OP-C.13A-36 1

ENCLOSURE 5.11 l

NORMALLY DEENERGIZED l

APPENDIX R. VALVES To meet Appendix R criteria during normal operation, the following valves will be deenergized. Some of the listed valves are deenergized for other precautionary reasons as well.

Valli Valve Position Deanerairgd_At HV-20001 CLOSED 2A171 HV-20002 CLOSED 28107 HV-20003 CLOSED 2A179 HV-20533 CLOSED DSF1-8, H3RPA1 HV-20534 CLOSED OSF1-8, H3RP81 HV-20579 CLOSED DSF1-8, H3RPA1 HV-20580 CLOSED DSF1-8, H3RP81 i

HV-21514 CLOSED 282802 HV-21515 CLOSED 20211 HV-21516 CLOSED 282803 HV-21522 CLOSED DSF1-8, H3RP81 HV-21528 CLOSED OSF1-8, H3RP81 HV-26105 CLOSED 2A142 HV-26106 CLOSED 28151 HV-26511 CLOSED 20226 HV-26512 CLOSED 20227 HV-26513 OPEN 20228 HV-26514 OPEN 20229

)

ENCLOSURE 5.11 PAGE 1 0F 1 END i

Rev. 8 OP-C.13A-37 i

.-.-a

- --- g

-y

.n_

n,

- - + - - - - - - -

yw--

GCA 88-248 1

C 13A Basis for Securing RCPs

)

1 1

1 i

l

GCA 88-248 Page 1 of 7 Review of C.13A Basis For Securing RCPs The B&W Appendix R Evaluation for Rancho Seco (ERPT-E0015) which follows this discussion is the basis document for OP-C.13A.

The B&W Evaluation assumes that "with a fire in the Control Room, equipment that is not provided with isolation switches and not controllable from the Shutdown Panel can spuriously actuate to any position or condition.

In order to assure that control over the plant is obtained, all equipment that is not provided with isolation switches and not controllable from the Shutdown Panel is to be deenergized by tripping / racking out breakers." As a result, the plant operators must trip the RCPs and deenergize their power sources because the RCPs are not provided with isolation switches.

Tripping the RCPs also provides equipment protection as the cooling water supply (CCW) to the RCPs cannat be guaranteed to operate throughout an event.

Operations staffing requirements do not provide manpower to allow the continuous monitoring of CCW operation that would be required to ensure CCW is available.

Thus, securing the RCPs provides assurance that pump damage will not occur and that primary system integrity will not be breached.

In summary, securing the RCPs during C.13A is considered the nost appropriate action considering the plant's design.

Natural circulation is a proven effective means of accomplishing primary side cooling.

Page 2 of 7 APPENDIX R EVALUATION For Sacramento Muncipal Utility District Rancho Seco Nuclear Generating Station June 1985 By Babcock & Wilcox Company Nuclear Power Division P.O. Box 10935 Lynchburg, Virginia 24506-0935 51-1152713-01

Page 3 of 7 Section IV i

Evaluation Program Methodology The methodology used in this evaluation assumes that a fire in the Control Room, coincident with a loss off-site power, represents the worst-case Appendix R scenario for Rancho Seco. This assumption has been substantiated by a fire hazards analysis in I

all but one cr.se. For a fire in the Boric Acid Pump Room, the ability to add concentrated boric acid (7100 ppeB) may be lost. Consequently, the following actions will be taken:

1) If the plant has operated for less than 130 effective full power days, no action is required since the BWST can provide sufficient boron to shutdown the plant and maintain a 1% delta K/K shutdown margin. (89) i
2) If the plant has operated for more than 130 effective full power days, the operators can restrict the Makeup tank outflow to 1200 gallons or repair the system to provide concentrated boric acid addition.

(64 and 89)

For a fire in any other location in the plant, no more than one train of equipment would be lost and the plant shutdown would be accomplished using the other train of equipment. With this in mind, the equipment required to shutdown the plant has been listed by mechanical, train, i.e. Train "A" or Train "B", in tables at the end of each system section. All of the equipment required to properly lineup the "A" mechanical train, for instance, is included under the colunr1 heading "Train A".

Note that this "Train A mechanica', equipment" can be powered from either the "A" or "B" vital electrical bus. To provide additional information regarding when a given component is required, refer again to the tables at the end of each system section. An "X" under a column heading signifies that the component must either be operated to achieve a given mode, i.e. hot shutdown, hot shutdown to cold shutdown, or maintain cold shutdown, or it must be isolated to mitigate the consequences of a spurious actuation (s). Passive equipment which is manually controlled will only be listed for the mode (s) where manual control is required. Conversely, active equipment which can be isolated and operated continuously will be listed in all mode (s) where it is required to operate. Each mechanical train will contain the minimtsn equipment required to shutdown the plant from operation at 100% power to hot shutdown and on to cold shutdown. The evaluation is based on off-site power not returning throughout the entire event. The equipment listed is therefore that equipment which is required to achieve and maintain a cold shutdown condition from either the Control Room or the Shutdown Panel with no off-site power available.

I 4

Page 4 of J For operation of Rancho Seco during an Appendix R event, the 'A' electrical powered equipment has been dedicated to the Shutdown Panel. With a fire in the control root equipment that is not provided with isolation switches and not controllable from the Shutdown Panel can spuriously actuate to any position or condition.

In order to assure that control over the plant is obtained, all equipment that is not provided with J

isolation switches and not controllable from the Shutdown Panel is to be de-energized by tripping / racking out breakers. This will prevent unwanted operation of the uncontrollable equipment. The isolation switches, provided on critical "A" electrical powered equipment, will also block spurious signals from the Safety Features System (SFS). Therefore, once the equipment is electrically isolated, Safety Features equipment cannot receive SFS initiation signals, The plant can be safely shutdown using exclusively the 'A' electrical powered equipment along with manual positioning of valves. No credit has been taken for automatic actuations other than Emergency Diesel Generator start, which is actuated by an undervoltage relay outside of the Control Room. Operator actions, prior to evacuating l the Control Room, have been limited to reactor / turbine trip and main feedwater pump trip.

Instrument indication is provided as necessary to monitor plant conditions and equipment position, aad performance. Electrical power is provided by the Emergency Diesel (s). Equipment control is provided by isolating the equipment electrically in order to prevent spurious actuations caused by the fire or by de-energizing the equipment and operating it manually. Once the equipment is isolated or the breakers are tripped, spurious actuations of the isolated or powerless equipment are not considered to occur. For the spurious actuation evaluation, off-site power is assumed '

to be available for those actuations that would result in a problem associated with cooldown or those that could result in a LOCA.

All equipment is assumed to fail or actuate to its least desired position tiefore being de-energized or isolated.

For a fire in the control room and a loss of off-site power, the basic approach will bc to trip the reactor and turbine, trip the main feedwater pumps, isolate the Reactor Coolant System by de-energizing closed the letdown isolation valve SFV-22009 and the R.C. pump seal return valve SFV-24013, and trip the Reactor Coolant pumps (if not j

tripped by the loss of off-site power). Decay heat from the reactor core will be removed through natural circulation flow with heat transferred to the secondary system l feedwater The steam generators will be fed by the AFW pumps P-318 and/or P-319 with coming f om the condensate storage tank T-358 and exhausting through the steam safety 1 s

Page 5 of 7 steam safety valves. Reactor Coolant System inventory addition will be through the use of the HPI pumps P-238A and/or P-2388, or the makeup pump. Once initial Reactor Coolant System contraction is stabilized, injection will be through the R.C. ptmp seals to cool the seals and maintain the Reactor Coolant System inventory. In order to cool down the plant to cold shutdown and maintain a minimum 15 delta K/K shutdown margin, a repair proceaure will be used to provide a supply of concentrated boric acid (7100 ppm 8). The repair procedure is only required after the 130 effective full power day point in the cycle as the 11 minimum Shutdown margin can be achieved at BOL usir.g only the BWST (1800 ppmB). The plant will be depressurized using ambient heat loss from the pressurizer only, i.e., no auxiliary spray. The cooldown and depressurization is expected to take in excess of 100 hours0.00116 days <br />0.0278 hours <br />1.653439e-4 weeks <br />3.805e-5 months <br /> (64) from the initiation of the cooldown sequence. This slow depressurization will prevent a steam bubble from forming in the reactor vessel head if the ambient heat loss from the head cools the liquid in the head faster than 2.5'F/HR.

The Reactor Coolant System will first be stabilized with only decay heat being removed by heat transfer to the secondary system with steam flow through the steam safety valves. Once control is established over the atmospheric dump valves, the plant cooldown can begin. Cooldom will be monitored by using a steam table and reading R.C. pressure and T hot and charting this against the graph of acceptable depressurization zones.

Once RC system temperature and pressure allow the initiation of the Decay Heat System, primary cooling will be through use of the decay heat pumps (P-261A and P-2618) and the decay heat coolers (E-260A and E-2608), only one train is required. System cooling water will be from the Nuclear Service Water System with heat exchanged to the atmosphere through the Nuclear Raw Water System.

Assumptions 1.

The Reactor Protection System and Safety Features System are r? quired to detect abnomal reactor or reactor building conditions and initiate automatic reactor shutdown or Safety Features actuation, and they are not required for manually tripping the reactor or cooling down the reactor with the loss of off-site power. Consequently, the position is taken that regardless of the single fire area in which a postulated Design Basis Fire may occur, a safe shutdown can always be accomplished by manually initiating a trip of the reactor. Therefore, instrumentation which supplies inputs to the reactor protection or Safety Features automatic actuation systems are not required for safe shutdown.

The instrumentation listed in Section VA.14 is that required for cooldown and shutdown. -

Page 6 of 7 2.

The determination of the consequences of a ' Design Basis Fire' shall includ effects of that postulated fire on the systems and equipment required to shuto the plant from a power operation condition and to bring the plant to 'a hot shutdown condition and on to cold shutdown. Also, systems and equipment located in the areas and zones adjacent to the fires as well as the area or zone in which the fire occurs are evaluated to assure that an unacceptable radioactive release is avoided. An analysis is performed for all areas adjacent to areas containing safety related equipment to assure that a fire in such an area will not spriad.

No fire in any area will result in an unacceptable release of radioactivity off-site. The Fire Hazards Analysis performed by Impe11 Corporation documents the above analysis.

3.

The "equipment required for shutdown and cooldown" is the equipment listed in Tables for each system in Section V and is the minimum equipment required for safe shutdown and cooldown concurrent with the loss of off-site power. All of the systems and equipment listed are redundant systems and equipment and receive their electrical power from the emergency diesel generator backed electrical buses. The non-safety related equipment will be manually positioned.

4.

The normal cooldown method of operating the plant utilizes several systems for removing decay heat from the reactor, i.e., CCW and PCW. However, it is assumed in the Fire Hazards Analysis (FHA) pe ' formed by Impe11 Corporation, that the systems are not functional due to either the loss of all off-site power or as a direct effect of the postulated fire. Even if off-site power is available, this evaluation is based on using diesel backed / battery backed equipment combined with manual operation.

5.

The term "hot shutdown" in this report means that the reactor is subcritical by at least one percent delta K/K and the average reactor coolant temperature is equal to or greater than 525'F.

6.

The term "cooldown" or "cold shutdown" condition in this report means that the reactor is being taken to, or is in, the condition where it is suberiti-cal by at least one percent delta X/K and the average reactor coolant temperature is no higher than 200*F. Ref. (61) Section 3.0 of the USAR.

7.

For control room evacuation, the only operator actions are turbine / reactor j

trip and trip of main feedwater pumps.

8.

Off-site power does not return throughout the event, f.e., from 100% power to cold shutdown.

Off-site power is avat1Cle for spurious actuations and all' equht I

9.

actuates O l'ts least desired c:ndition er puttion,

10. All equipment required for ope ~ ration M11 be isolated from possible spurious actuations. All remaining equipmeni, whose actuation could adversely affect cooldown of the plant will be de-energized by having the breakers tripped /

racked out. *

11. The fire, coupled with a loss of off-site power, will not include any other design base events.
12. Spurious actuations will be addressed for those actuations that could result in a Loss of Primary Coolant, could delay or prevent the plant from achieving a cold shutdown condition, or could result in an undesirable condition resulting in a problem.

If three or more actuations are required to develop a problem, it will not be considered as a credible event. This is a selected criteria based on the fact that only two valves are required for primary isolation.

Abbreviations:

S (Suffix) - System RCS - Reactor Coolant System AFW - Auxiliary Feedwater NSW - Nuclear Service Water System NRW - Nuclear Raw Water System DHS - Decay Heat System hP1 - High Pressure Injection DG - Diesel Generator 0F0 - Diesel Generator Fuel Oil SFS - Safety Features System RPS - Reactor F rotection System CRD - Control Rod Drive System NIS - Nuclear Instrumentation System NNI - Non-Nuclear Instrumentation System MSS - Main Steam System 1

FWS - Feedwater System CCW - Component Cooling Water System PCW - Plant Cooling Water System PLS - Purification and Letdown System SIM - Seal Injection and Make Up HVS - Heat, Ventilation, and Air Conditioning System BVS - Borated Water System CA&RSS - Chemical Addition and Reactor Sampling System i

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