ML19312E579

Steam Generator Tube Rupture, Revised Emergency Procedures

ML19312E579
Person / Time
Site:	North Anna
Issue date:	05/22/1980
From:	Cartwright W, Harvey S VIRGINIA POWER (VIRGINIA ELECTRIC & POWER CO.)
To:
Shared Package
ML19312E567	List: ML19312E566 ML19312E568 ML19312E570 ML19312E574 ML19312E579 ML19312E581
References
2-EP-4, NUDOCS 8006050339
Download: ML19312E579 (25)

Text

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2-EP-4 Page 1 of 11 05-22-80 VIRGINIA ELECTRIC AND POWER COPJANY NORTH ANNA POWER STATION UNIT NO. 2 STEAM GENERATOR TLTE RUPTURE REFERENCI.S:

1. 12050-FM-73A Condensate System

2. 12050-FM-87B Waste Disposal System

3. FSAR Chapter 15

4. 12050-LSK-3-1

5. 12050-FM-93A Reactor Coolant System

6. 12050-LSK-28-5C

7. T.S. 3.4.6.2, 3.7.1.4, 4.4.5.3

8. I.E. Bulletin #79-06A,79-06C REV. 8 PAGE: Entire DATE: 05-22-80 APPROVAL:!d 1

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APPROVED BY: , /l647 W CHAIRMAN STATION NL'C;2AR SAFETY l AND OFERATING COMMITTEE l

DATE: 05-22-80 SAFETY RELATED.

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2-EP-4 Page 2 of 11 05-22-80 VIRGINIA ELECTRIC AND POWER COMPANY NORTH ANNA POWER STATION UNIT NO. 2 STEAM GENERATOR TUBE RUPTURE 1.0 Indications 1.1 HIGH RADIATION LEVEL /ALUtM ON THE AIR EJECTOR DISCHARGE WITH A DIVERT TO THE CONTAINMENT VESSEL.

1.2 High Radiation Level / Alarm in the Steam Generator Blowdown.

1.3 Decreasing pressurizer level.

NOTE: The pressurizer water level indication should always be used in conjunction with other specified reactor coolant system indications to evaluate system response and to initial manual operator actions.

1.4 'ncreasing Steam Generator level.

2.0 Automatic Actions 2.1 Reactor trip due low pressurizer pressure (1870 psig).

2.2 Air djector discharge divert to the containment vessel (TV-SV202-1 opens, and TV-SV203 opens and TV-SV102-2 closes).

l 2.3 Safety Injection Initiation and Phase A Isolation.

2.3.1 Low pressurizer pressure (1765 psig) 2.4 Reactor trip due to overtemperature AT.

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2-EP-4 Page 3 of 11 05-22-80 3.0 Immediate Operator Actions 3.1 2-EP-1 Immediate Actions have been completed.

NOTE: If any required automatic action has not occurred, it shall be mauually initiated.

3.2 Manually initiate Safety Injection 3.2.1 Verify that the emergency busses (H & J) are energized, and both emergency diesels generators running.

3.2.2 Verify phase "A" isolation 3.2.3 Verify feedwater isolation

, 3.2.4 Verify that the auxiliary feedwater pumps (2-FW-P-2, 2-FW-P-3A and 3B) have started and are flowing (FI-FW-200 A, B, and C) 3.2.5 Verify high head and low head safety injection pumps are running and cold leg injection flow is indicated on FI-2961, 2962 and 2963.

3.3 Verify main steam isolation if:

3.3.1 Containment pressure exceeds the intermediate high high setpoint, of 17.8 psia. or, 3.3.2 Safety injection was initiated by high steam flow-low Tave (543*F) or high steam flow - low steam pressure (600 psig).

3.4 Verify containment high-high initiation if containment pressure exceeds 25 psia 3.4.1 Verify quench spray pumps start and are flowing.

3.4.2 Verify phase "B" isolation 3.5 Emergency director to initiate EPIP-1.

2-EP-4 Page 4 of 11 ,

05-22-80 I Znitials 4.0 Long Term Operator Actions l NOTE: Do not under any circumstances close the coolant loop isolation valves.

NOTE: The pressurizer water level indication should always be used in conjuntion with other specified reactor coolant system indications to evaluate system conditions and to initiate manual operator actions.

NOTE: If the reactor coolant system pressure decreases in an uncontrolled manner to less than (1485 psig) secure all reactor coolant pumps.

NOTE: Initiate attachment 2 to verify natural circulation.

NOTE: When the criteria is met for securing Safety Injection, perform step 4.12.

CAUTION: Do not secure seal injection.

CAUTION: During a safety injection when a emergency bus is being carried by its emergency diesel generator, the loading must be 5 3000kw. The emergency bus powered pressurizer heaters shall not be re-energized until the load is <

2730 kw and the pressurizer level is greater than 10%.

Equipment which may be secured to meet this requirement are:

1. Containment Air Recire Fan (s)

2. Rod Drive Cooling Fan (s)

3. Service Water Screen Wash Pump

4. Standby Primary Grade Water Pump r

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2-EP-4 Page 5 of 11 05-22-80 Initials 4.0 Loag Term Operator Actions (cont.)

4.1 Identify the affected steam generator by:

4.1.1 Unexpected increase in one Steam Generator level with auxiliary feedwater flow reduced or stopped.

4.1.2 Unexpected increase in auxiliary feedwater pump discharge pressure to the affected steam generator.

4.1.3 High radiation level / alarm in the steam generator blow-down 4.2 Verify 4A isolation by initiating Attachment 3.

4.3 Isolate auxiliary feedwater flow to the affected steam generator as follows:

4.3.1 To isolate auxiliary feed to "A" steam generator:

Close TV-MS-211A Close TV-MS-211B Close MOV-FW-200D 4.3.2 To isolate auxiliary feed to "B" steam generator:

I Place 2-FW-P-3B in " Pull-To-Lock" i

! Close MOV-FW-200B 4.3.3 To isolate auxiliary feed to "C" steam generator:

Place 2-FW-P-3A in " Pull-To-Lock" l

Close HCV-FW-200C l

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2-EP-4 Page 6 of 11 05-22-80 Initials 4.0 Long Term Operator Actions (cont.)

4.4 Close the MSTV and Bypass associated with the affected steam generator as follows:

4.4.1 To isolate "A" steam generator:

Close TV-MS-201A Close TV-MS-213A 4.4.2 To isolate "B" steam generator: .

Close TV-MS-201B Close TV-MS-213B -

4.4.3 To isolate "C" steam generator:

Close TV-MS-201C Close TV-MS-213C 4.5 Place the controller for the power operated relief valve of the affected steam generator in manual and close.

PCV-MS-201A PCV-MS-201B PCV-MS-201C NOTE: If any steam generator, which is operable, does not have a running auxiliary feedwater pump, or does not have proper flow indication, attempt to correct the problem or refer to 2-AP-22.

I 4.6 Throttle flow to the unaffected steam generators to recover and maintain no-load level (33%). Monitor auxiliary feedwater pump

suction pressures to verify > 4 psig. Maintain 2-CN-TK-1 level l above the lo-lo level alarm point by filling from 2-CN-TK-2, or l

l 1-CN-TK-2 as per 2-0P-31.2.

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2-EP-4 Page 7 of 11 05-22-80 Initials 4.0 Lot g Term Operator Actions (cont.)

4.7 Isolate the condenser hotwell high level divert (LCV-CN-208) by closing 2-CN-141 and verifying closed 2-CN-143.

4.8 Secure steam from the affected steam generator to 2-FW-P-2 by:

. "A" Steam Generator affected Close 2-MS-18 (Steam Supply to 2-FW-P-2)

"B" Steam Generator affected close 2-MS-57 (Steam Supply to 2-FW-P-2)

"C" Steam Generator affected Close 2-MS-95 (Steam Supply to 2-FW-P-2)

NOTE: If the Reactor Coolant pumps are not running, verify natural circulation as per Attachmen't 2.

4.9 Utilizing the steam dump valves (or the power operated relief valves on the unaffected steam generators if the steam dumps are not available), for cooldown not exceeding the tech spec limit for cooldown of 100*/hr and maintain 50 subcooling at all times.

4.10 Depressurize the primary system until the indicated water level in the pressurizer rises above 50% of span or the reactor coolant system pressure decreases to a value equal to the faulted steam generator steam pressure by:

4.10.1 Utilizing pressurizer spray if RCP's are available.

NOTE: During reactor cool' ant system depressurization the criteria established for securing reactor coolant pumps at < 1485 psig does not apply.

4.10.2 If offsite power is not available or the RCP's are not in service, open one pressurizer PORV to depressurize.

NOTE: An increase in pressurizer level is expected waen utilizing a PORV to depressurize. Discontinue depres-surization if indicated level increases to > 50% of span and verify 50' subcooling exist by the cc re cooling monitor and continue the depressurization.

2-EP-4 Page 8 of 11 05-22-80 Initials 4.0 Long Term Operator Actions (cont.)

4.11 Verify that a loss of reactor coolant other than the steam genrstor tube rupture is not in progress by:

4.11.1 If recirculation sump level or a containment sample (if available at this time) are not in the normal pre-event range, request tue STA/SRO to reevaluate the incident.

4.11.2 If PORV was utilized to depressurize, verify that PORV's are closed by the accoustical monitors and the limit switch positions.

CAUTION: If pressurizer relief tank integrity is lost, abno rmal containment could exist and may not be true indications of a continued loss of reactor coolant.

4.12 Safety Injection may be terminated if all of the following criteria are satisfied.

1. Safety Injection flow is greater than the leak as vertfied Yes No by pressurizer level increasing and reactor coolant system pressure increasing at least 200 psi (after shutting the spray valve or verified closure of the pressurizer PORV).

NOTE: Following termination of safety injection, pressurizer pressure will decrease to a value equal to the affected steam generator pressure.

NOTE: If during subsequent recovery actions, pressurizer level cannot be maintained above 20% indi-cated level, manually re-initiate safety injecti,on to re-establish level. If level cannot be re-established, return to Step 4.9.

2. Reset safety injection and establish normal charging and letdown as per Attachment 1.

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2-EP-4 Page 9 of 11 05-22-80 fnitials 4.0 Long Term Operator Actions (cont.)

4.13 Continue running or start one Reactor Coolant pump in an unfaulted loop (preferred A or C for spray.) If the reactor coolant pumps have been secured due to a uncontrolled depressurization to (<1485 psig), it is NOT permissible to restart a reactor coolant pump until the criteria for securing safety injection has been met and plant conditions have been evaluated for starting a teactor coolant pump.

4.14 Verify that the pressurizer heaters are energized and maintain pressure eqv21 to the affected steam generator steam pressure.

4.15 Secure any raste gas release from the site:

4.15.1 Clcse WGDT release valve FCV-GW-101.

4.15.2 Infc?m the other unit to secure containment purge and hogging operations.

4.16 Complete 2-EP-1 long term operator action.

4.17 The emergency diesel generators should not be operated at idle speed or minimum load for extended periods of time. Verify with the system operator that the Vepco power system is stable',

then return the station service electrical systems to normal as per 2-AP-10 and return the emergency busses and emergency diesel generators to normal as per 2-0P-6.

NOTE: In the event of a simultaneous steam generator tube rupture accident and a Loss of Station Power while only one / _'l Emergency Diesel is supplying power to its resy.ctire emergency bus (other emergency diesel being inoperable), DO NOT shut down the last running diesel under any circumstances until ordered by administrative authority after accident has been terminated.

2-EP-4 Page 10 of 11 05-22-80 fnitials 4.0 Long Term Operator Actions (cont.)

4.18 Continue RCS cooldown and depressurization as per 2-OP-3.2 in 2-OP-3.3 and 2-0P-3.4. Addition to the above procedure precau-

~

tions, the following precautions apply.

4.18.1 If offsite power is available, begin a controlled cooldown of the reactor coolant system at a rate of

. bout 50*F/hr by use of the steam dump to the main .

condensers from the non-faulted steam generators.

Control the water levels in the steam generators to maintain steam generator water level' in the narrow range span or in the wide range span at a level > 70%

sufficient to assure that the U-tubes are covered. If offsite power is not available, dump steam from the non-faulted steam generators through the steam generator power operated relief valves to provide a controlled cooldown of the reactor coolant system at a rate of about 50 F/hr.

4.18.2 Simultaneous with the cooldown using the non-faalted steam generators, slowly decrease the faulted steam generator pressure by opening the bypass valve to the l

l condenser (if available), or using the steam generator l power operated relief valve. As pressure is reduced in the faulted steam generator, control the reactor coolant pressure at a value approximately equal to the steam l

l pressure in the faulted sceam generator to minimize 1

flow from the Reactor Coolant system to the Steam Generator or from the steam generator to the Reactor Coolant System.

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2-EP-4 Page 11 of 11 05-22-80 Initials 4.0 Long Term Operator Actions (cont. )

4.18.3 Reactor coolant pressure control should be accomplished by use of the pressurizer heaters and action of one of the following:

a) Normal pressurizer spray (if an RCP is in service), OR b) Use of pressurizer auxiliary spray (if spray is heated by letdown through the regenerative heat exchanger, OR c) Brief intermittent opening of one PORV.

4.18.4 Reduce the Reactor Coolant temperatures < 140*, secure the Reactor Coolant pump and depressurize the steam generator and the Reactor Coolant system in preparation for maintenance on the steam gene- sr.

NOTE: If the cooldown is by natural circulation, continue to monitor and verify natural circulation as per Attach-ment 2.

Completed By:

Date:

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2-EP-4 Attachment #1 Page 1 of 2 05-22-80 Initials Securing Safety Injection i

1. Verify or reset safety injection train A and B by use of the control board reset pushbuttons. ,

2. Secure lowhead safety injection pumps (2-SI-P-1A and IB) and Place the Control Switches to " Auto After Stop".

3. Open MOV-2289A charging line isol. on FCV-2122.

4. Secure the second operating charging pump and place its control switch to " Auto Af ter Stop".

5. Shift FCV-2122 (charging tlow controller) to manual and run it closed.

6. Shift Pqv-2145 low press letdown pressure controller to manual and set to

• 50% open

7. Open TV-2204 letdown line isolation trip valve.

8. Open MOV-2380 and MOV-2381 seal water return isolations.

9. Open LCV-2460A and 2460B letdown isolation valves from "A" loop.

10. Verify blender set for cold shutdown concentration and in auto make up mode.

11. Verify HCV-2310 open.

12. Verify HCV-2311 (aux. spray) closed.

i 13. Open 2289B (charging line isolation on FCV-2122).

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14. Open charging pump recire. valves.

MOV-2275A 2-CH-P-1A I MOV-2275B 2-CH-P-1B l

MOV-2275C 2-CH-P-1C MOV-2373 Common Recire

15. Shift charging pumps suction from RWST to VCT as follows:

15.1 Verify VCT level > 20%.

15.2 Open MOV-2115C and 2115E.

15.3 When MOV-2115C and 2115E are full open verify MOV-2115B :nd 2115D go closed.

2-EP-4 Attachment #1 Page 2 of 2 05-22-80 Initials Securing Safety Injection (cont.)

16. Open FCV-2122 to

• 20% open slowly.

17. Isolate flow thru Unit 1 boron injection tank tur closing the fol-lowing:

MOV-2867A BIT inlet MOV-2867C BIT inlet MOV-2867B BIT outlet MOV-2867D BIT outlet

18. Open HCV-2200A (45 gpm orifice isolation).

19. Control PCV-2145 in manual to maintain 450-550 psig letdown line pressure until letdown line temperature decreases to normal.

20. Slowly adjust letdown line pressure to

• 300 psig tLcr shift PCV-2145 to auto.

NOTE: Monitor letdown radiation readings, reisolate letdown if read-ing exceeds 1000 times original. (could indicate excessive fuel failure)

21. Control FCV-2122 to maintain

• 50% pressurizer level. 60 gpm orifice isolation valves 2200 B and/or 2200C may be required to be open to maintain level.

2-EP-4 Attachment #2 Page 1 of 4 05-22-80 Natural Circulation Verification Initials CAUTION: During the conduct of this instruction, the RWST level should be monitored for switchover to cold leg recir ~

culation, if required.

CAUTION: If the high range readings from the core exit thermo-couples are not available, a condition of inadequate core cooling exists when: the hot leg RTD's are pegged high or five or more incore thermocouples are off-scale above 700*F and SI flow is not being delivered to the RCS and AFW is not being delivered to the intact steam generators.

CAUTION: If during the verification of natural circulation it is determined that the core is not being adequately cooled, proceed to Step 10.0.

CAUTION: Trip the pressurizer heaters, containment Air Recire.

Fan (s) and the Rod Drive Cooling Fan (s) to prevent overloading the Emergency Diesel Generators in the event that a SI occurs anytime during a blackout.

NOTE: Only one bank of backup heaters maybe required to maintain pressurizer pressure during natural cir-culation; there-fore, load reduction will only be required on the diesel which will supply the heaters to be utilized.

i NOTE: The pressurizer heaters are required to be in service i

within 1 hr. of entry into natural circulation.

1.0 All operable steam generators shall be maintained in the narrow range level indication range (tubes covered) by manual control of auxiliary feed flows (prefered

• 33% level).

1.1 Verify steam generators operable by (/) check.

"A" S/G "B" S/G "C" S/G 2.0 The aT (wide range Th - wide range Tc) for reactor coolant loops with operable steam generators should be between 25% and 80% of full power values (15 F to 50 F) as determined from TR-2413 (W.R. Th) and TR-2410 (W.R. Tc).

2.1 "A" Loop W.R. Th (T-2413) - W.R. Tc (T-2410) = AT

• F - *F = *F 2.2 "B" Loop W.R. Th (T-2423) - W.R. Tc (T-2420) = aT

• F- *F = *F

. 2-EP-4 Attachment #2 Page 2 of 4 05-22-80 Natural Circulation Verification (cont.)

Initials 2.3 "C" Loop W.R. Th (T-2433) - W.R. Tc (T-2430) = AT

• F - F = F 3.0 Verify that the wide range Th indications as observed on TR-1413 are stable or decreasing.

4.0 Prvssurizer pressure shall be maintained high enough to assure 2 50 F succooling from the highest wide range operable Th indication from TR-2413, verification shall be dade from the posted saturation graph.

5.0 Pressurizer level shall be maintained in manual level control.

CAUTION: A high energy break in containment can cause up to 40%

indication error in pressurizer leve'l. To secure safety injection under this condition pressurizer level must be 2 50% and maintained there.

5.1 LI-2459 A  %

5.2 LI-2460  %

5.3 LI-2461  %

6.0 Record the incore thermocouple temperatures as required below SWITCH POSITION # CORE LOCATION TEMP. *F 10 J10 17 E10 18 F9 20 D5

'24 E4 33 K5 36 16 45 M9 7.0 Print out A incore thermocouple map (short f o rm-:no s t recient) on utility typewriter (refer to page A-45 of computer codebook if uti-lity typewriter is inoperable).

7.1 Press "Incore T/C Map" pushbutton

T

. 2-EP-4 Attachment r/2 Page 3 of 4 05-22-80 Natural Circulation Verification (cont.)

Initials 7.2 25 value 1 7.3 10 value 2 7.4 1 value 3 7.5 Press " Start" pushbutton NOTE: Verify that the incorp temperatures all show 2 50 F subcooling from saturation, as they are the most reli-able temperature inidication.

NOTE: The incor- thermocouple maps should be run every N 30 min for continued verification of cooldown.

8.0 Verify that the operable steam generator pressures are following the saturation curve for the wide range Tc using the following.

8.1 "A" Steam Generator PI-2474 psig PI-2475 psig PI 2475 psig 8.2 "B" Steam Generator j PI-2484 psig PI-2485 psig 1

( PI 2486 psig 8.3 "C" Steam Generator PI-2494 psig PI-2495 psig PI 2496 psig Make all changes in auxiliary feed water flow, and steam flow slowly

~

l 9.0 to prevent upset to the thermal driving head of natural circulation during plant subsequent cooldown.

10.0 If it has been detecained that the core is not being adequately

, cooled in natural circulation, as verified by increasing core exit l

thermocouple : adings. Commence the following actions as required to restore adequa.e core cooling.

NOTE: If any of the below actions correct the malfunction refer back to Step 1.0 to verify proper cooling.

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2-EP-4 Attachment #2 Page 4 of 4 05-22-80 Natural Circulation Verification (cont.)

Initials 10.1 Increase the steaming rate from the operable steam generators by:

10.1.1 Dumping steam to the main condenser via steam dumps.

10.1.2 Operation of power operated relief valves.

10.2 Open the pressurizer power operated relief valves as required.

9C iE : Open the pressurizer PORV's only if: .

1. SIS or charging is available to deliver to the RCS.

2. RCS depressurization cannot be accomplished by steam t relief from the steam generators'.

3. Feedwater is not available to maintain the steam generator secondary water level at an effective level.

10.3 If no means for RCS depressurization are available, or if the depres-surization did not result in decreasing core exit thermocouple tem-peratures, then start a reactor coolant pump, if pcssible.

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2-EP-4 Attachme'nt 3 Page 1 of 8 05-22-80 Initials VERIFICATION OF $A AND/OR $B CONTAINMENT ISOLATION FROM SI AND/0R CDA i

1. SI ($A) Verification 1.1 Verify Automatic Valve Operation on 'H" Safeguards Panel.

(/) OPEN (RED)

MOV-2867A BIT inlet MOV-2867C BIT outlet MOV-SW-200A SW to Spray header MOV-SW-200B SW to Spray header (J) CLOSED (GREEN)

TV-2884A BIT recire.

TV-2884C BIT recire.

MOV-2380 Seal water return

(/) (J) (/) (4) (/) (/) (/) (l) (/) (/)

BD CV DA LM LM RM SI SS SS SS 200A 250A 200A 200C 201A&C 200A 200A 200A 203 212A BD CV DG LM VG RM MS SS SS IA 200C 250C 200A 200E 200A 200B 209A 201A 204A 201A BD SI LM LM TV MS TV SS SS IA l 200E 201 200A 200G 2519A 210A 2859 202A 206A 202A

~

SV SV 202-1 202-2 Valve Monitor '/3 light off l

t a - , . . . n -

,-a.-, -,,....-.-n...- , - . , , - . - . . , _ , . , - - _ , - , - . , . , , , . .

2-EP-4 Attachment 3 Page 2 of 8

^5-22-80 Initials 1.0 SI ($A) Verification (cont.)

1.2 Verify Automatic Valve Operation on "J" Safeguards Panel.

(J) OPEN (RED)

MOV-2867B BIT inlet MOV-2867D BIT outlet (J) CI.0 SED (GREEN)

TV-2884B BIT recire.

MOV-2381 Seal water return (d) (J) (J) (J) (J) (J) (d) (J) (J) (J)

BD CV DA I.M LM RM SI SS SS SS 200B 250B 200B 200D 201B&D 200C 200B 200B 203B 212B ZD CV DG LM VG RM MS SS SS IA 200D 250D 200B 200F 200B 200D 209B 201B 204B 201B BD SI LM LM MS TV TV SS SS IA 200F 2936 200B 200H 210B 2204 2842 202B 206B 202B SV

.l 203 _

em

2-EP-4 Attachment 3 Page 3 of 8 05-22-80 Initials 1.0 SI ($A) Verification (cont.)

1.3 Verify Automatic Valve Operation on "Benchboard".

(J) OPEN (RED)

MOV-2115D RWST to Chg. pumps MOV-2115B RWST to Chg. pumps (4) CLOSED (GREEN)

MOV-2115C VCT to Chg. pumps MOV-2115E VCT to Chg. pumps MOV-2289A Normal charging header

. MOV-2289B Normal charging header i

t MOV-2373 Common recire.

HCV-2200A Letdown orifice HCV-2200B Letdown orifice HCV-2200C Letdown orifice

(/) CLOSED ON LOW PZR LEVEL (GREEN) (< 15% Level)

LCV-2460A Letdown isolation LCV-2460B Letdown isolation 1.4 Verify Automatic Valve Operation on " Backboard".

(J) CLOSED (GREEN)

. MOV-2275A 2-CH-P-1A Recire.

MOV-2275B 2-CH-P-1B Recire.

• MOV-2275C 2-CH-P-1C Recirc.

2-EP-4 Attachment 3 Page 4 of 8 05-22-80 Initials 1.0 SI ($A) Verification (cont.)

1.5 Verify the following Automatic Actions:

1. 2 Ventilation Panel:

(/) CLOSED (GREEN)

A0D-HV-160-2 Control room vent A0D-HV-161-2 Control room vent

1. 1 Ventilation Panel:

(J) CLOSED (GREEN)

A0D-HV-160-1 Control room vent A0D-HV-161-1 Control room vent 1-HV-F-15 (Tripped) Control room exhaust fan 1.6 Verify auto initiation of the bottled fresh air supply to the control room (PI-HV-1311, PI-HV-2311), and positive pressure in the control room (PDI-HV-100, PDI-HV-200).

1.7 Verify that the containment vacuum pumps trip (2-CV-P-3A, 2-CV-P-3B).

1.8 Verify 1-SW-P-1B and 2-SW-P-1B started and that 1-SW-P-1A or 1-SW-P-4 and that 2-SW-P-1A or 2-SW-P-4 started.

2-EP-4 Attachment 3 Page 5 of 8 Initials 05-22-80 2.0 CDA ($B) Verification (This section is to be completed only if required) 2.1 Verify the following Automatic Operations on "H" Safeguards Panel.

(J) CLOSED (GREEN)

(J) (J) (J) (J) J CC CC CC CC '

205A 202A 204A 201A CC CC CC CC 205B 202C 204B 203A CC CC CC 205C 202E 204C MOV-SW-210A Air recire. cooler MOV-SW-214A Air recire. cooler MOV-SW-208A Component cooling (J) OPEN (RED)

MOV-SW-203A RS HX A supply MOV-SW-203D RS EX D supply MOV-SW-204A RS EX A return MOV-SW-204D RS EX D return MOV-SW-201A RS EX header supply MOV-SW-201C RS EX header supply MOV-SW-205A RS EX header return MOV-SW-205C RS HX header return MOV-QS-200A QS pump suction MOV-QS-201A QS pump discharge MOV-QS-202A From chem. add. tank (5 min. T.D.)

i

,, MOV-RS-256A RS pump discharge MOV-RS-255A RS pump suction 2-QS-P-1A Quench spray pump starts 2-RS-P-1A Inside recire. spray pump starts after 3 k min. T.D. (Verify rotation by blue light lit) 2-RS-P-2A Outside recire. spray pump starts af ter 3 min. T.D.

2-EP-4 Attachment 3 Page 6 of 8 Initials 05-22-80 2.0 CDA ($) Verification (cont.)

2.2 Verify the following Automatic Operations on "J" Safeguards panel.

(J) CI0 SED (GREEN)

(J) (J) (/) (J)

CC CC CC CC 200A 2023 204A 201B CC CC CC CC 200B 202D 204B 203B CC CC CC 200C 202F 204C MOV-SW-210B Air recire. cooler MOV-SW-214B Air recire. cooler MOV-SW-208B Component cooling (J) OPEN (RED)

MOV-SW-203B RS HX A supply 9

MOV-SW-203C RS HX D supply MOV-SW-204B RS HX A return MOV-SW-204C RS HX D return i

MOV-SW-201B RS HX header supply MOV-SW-201D RS HX header supply MOV-SW-205B RS HX header return MOV-SW-20$D RS HX header return MOV-QS-200B QS pump suction MOV-QS-201B QS pump discharge MOV-QS-202B From chem, add. tank (5 min. T.D.)

MOV-RS-256B RS pump discharge MOV-RS-255B RS pump suction 2-QS-P-1B Quench spray pump starts l

2-RS-P-1B Inside recire. spray pump starts after 3 h min. T.D. (Verify rotation by blue light lit) 2-RS-P-2B Outside recire. spray pump starts after 3 \

min. T.D.

i

2-EP-4 l Attachment 3 Page 7 of 8 .

05-22-80 l Initials l

i 2.0 CDA (9) Verification (cont.)

I 2.3 Verify the following Automatic Operations on the bottled air / l casing cooling panel.

(J) l 2-RS-P-3A casing cooling pump starts 2-RS-P-3B casing cooling pump starts MOV RS-200A casing cooling supply open MOV-RS-201A casing cooling supply open l

MOV-RS-200B casing cooling supply open

'OV-RS-201B d casing cooling supply open 2.4 Verify the following Automatic Operations on Ventilation Panel.

2.4.1 "H Bus Powered Section

[ (J) TRIPPED 2-HV-F-1A Air recire. fan 2-HV-F-1C Air recire fan 2-HV-F-37A CRDM cooling fan 2-HV-F-37B CRDM cooling fan 2-HV-F-37C CRDM cooling fan (J) CLOSED (GREEN)

TV-SW-201A Air recire. cooler supply TV-SW-201B Air recire. cooler return MOV-SW-210A Air recire. cooler return MOV-SW-214A Air recire. cooler return l

DIVERT TO IODINE FILTER 1

A0D-HV-107B Aux. Bldg.

A0D-HV-223 Sigd. Bldg.

I l

2-EP-4 Attachment 3 Page 3 of 8 Initials 05-22-80 2.0 CDA (08) Verification (cont.)

2.4.2 "J" Bus Powered Section (J) TRIPPED 2-HV-F-1B Air recire. fan 2-HV-F-IC Air recire, fan 2-HV-F-37D CRDM cooling fan l

2-HV-F-37E CRDM cooling fan 2-HV-F-37F CRDM cooling fan (J) CLOSED (GREEN)

TV-SW-201A Air recire. cooler supply TV-SW-201B Air recire. cooler return MOV-SW-210B Air recire. cooler return MOV-SW-214B Air recire. cooler return DIVERT TO IODINE FILTER A0D-HV-107A Aux. Bldg.

A0D-HV-228 Sfgd. Bldg.

l 2.5 Verify Automatic starts on radiation monitoring panel.

(J) SAMnLE PUMPS RUNNING (After 2 min. T.D.)

(Verify red " low flow" lights not "0N".)

l l 2-SW-P-5 for RS EX 2-RS-E-1A l

l 2-SW-P-6 for RS EX 2-RS-E-1B l

2-SW-P-7 for RS EX 2-RS-E-1C 2-SW-P-8 for RS HX 2-RS-E-1D l

2.6 On the Main Control Board verify t3at the component cooling water pumps trip (J).

2-CC-P-1A 2-CC-P-1B l

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