ML20002A748

Emergency Operating Procedures EOP-5,Revision 2, Reactor Trip.

ML20002A748
Person / Time
Site:	Summer
Issue date:	10/06/1980
From:	SOUTH CAROLINA ELECTRIC & GAS CO.
To:
Shared Package
ML20002A746	List: ML20002A745 ML20002A747 ML20002A748 ML20002A749 ML20002A750
References
EDP-5R2, EOP-5, NUDOCS 8011210467
Download: ML20002A748 (9)

Text

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[1-SOUTH CAROLINA ELECTRIC AND GAS COMPANY VIRGIL C. SUMMER NUCLEAR STATION ,

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NUCLEAR OPERATIONS NUCLEAo ove-

$/ \ ' [jf f EMERGENCI OPERATING PROCEDURE I

E0P-5 REACTOR TRIP ,

REVISION 2 j OCTOBER 6, 1980 l SAFETT RELATED Reviewed by:

9 ORIGINATOR-lof this revision) Date QUALIFIED REVIEWER . Date Approved:

OPERATIONS SUPERVISOR Date Date Issued: [ j e i Fors AP-101-2 (1/80) ll l'

.i 801121 O Y67 l

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0 30P-5 -

Page i ,

REVISION 2~

10/06/80 LIST OF EFFECTIVE PAGES

, PAGE -

. REVISION -. ,

i' 2' 1 2 2 2 3 2 ,

4 2 ATTACHMENTS REVISION I 2 II 2 4

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EOP-5 '

PAGE 1 REVISION 2 10/6/80 1.0 PURPOSE 1.1 The purpose.of this procedure is to place the unit in a stable confeition after a reactc~ trip to allow evaluation and possible return to power operatica.

2.0 REFERENCES

AND GLOSSARY 2.1 Reference 2.1.1 V. C. Summer Technical Specification - 2.1.2 V. C. Summer General Operation Procedures A. GOP-2, Plant Startup from Hot Shutdown to Power Operation B. GOP-6, Plant Shutdown from Hot Standby to Hot Shutdown C. GOP-7, Plant Shutdown from Hot Shutdown to Cold Shutdown 2.1.3 E0P-13, Natural Circulation 2.1. 4 SOP-214 r Heater Vents and Drains  !

I 2.2 Glossary None 30 CONDITIONS 31 Symptoms '

J.1.1 Any one of the 23 reactor trip first out annunciators indicating Attachment I conditions.

4.0 AUTOMATIC ACTIONS 4.1 Reactor trip 4.2 Turbine trip 4 3 . Generator trip (after 30 second time delay) 50 IMMEDIATE OPERATOR ACTION 51 Verify Reactor Trip / Turbine Trip

- 5 1.1. Verify all contro) and shutdown rods fully inserted by d.igital rod position indication and rod botton lights. j

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E0P-5 PAGE 2 REVISION 2 10/6/80 A. IP reactor has not tripped:

1) ' Trip the reactor and' turbine manually from'the main control board.

2) IF reactor does not trip, place Bus 1B1 and 101 BUS TIE BKR in MANUAL and open 1B1 and 101 FDR BKRS from the main control board.

NOTE: Bus 1B1 and 101 may be re-energized when rods are inserted.

5.t.2 Emergency borate 17 minutes (approximately 100 ppm) for .

each control or shutdown rod not fully inserted by  !.

opening MVT-8104 and verify flow on FI-110.

513 Verify Reactor power decreasing and transfer NR-45 recorder to one source range and one intermediate range channel.

5 1.4 Verify turbine trip:

A. IF, turbine has not tripped:

1) Manually trip the turbine from the main control board OR

2) Stop EHC Pumps A and B and pull to lock oil 3)- Manually trip the turbine from the turbine front standard 52 Verify one Reactor Coolant Pump running, IF NOT proceed to E0P-13 for establishing natural circulation.

53 Verify RCS temperature iecreasing to no load Tave by operation of steam dumps.

54 Verify pressurizer level and pressure commence recovering from transient. t A. If not recovering, evaluate conditions for safety injection symptons. If necessary, safety inject and go to E0P-1, Safety Injection.

i 55 Verify generator trip approximately 30 seconds after turbine l trip.

5.5 1 Generator output breaker open.

552 Main Generator field breaker open.

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-5.5.3 Main turbine speed decreasing.

56 Announce Reactor trip over paging system.

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E0P-5 PAGE 3

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REVISION 2 10/6/80 6.0 FOLLOW-UP ACTION NOTE: Check or initial steps as indicated when satisfactorily completed.

6.1 Verify all automatic and immediate action steps have been completed.

6.2 Verify feedwater isolation at Tavg 563*F. Reduce feedwater pump speed to minimum governor speed.

63 7erify Tavg at or approaching no-load value of 557*F.

631 If cooldown rate is uncontrollec, start emergency boration by OPENING MYT-8104 and verifying flow on FI-110

AND

6.3 2 Evaluate conditions for safety injection symptoms and go 1

to E0P-1, Safety Injection, if necessary.

6.4 When Tavg reaches 557*F, place both Steam Dump Interlock Switches to RESET then BYP INTLK and transfer STEAM DUMP MODE SELECTOR switch to STM PRESS mode.

6.4.1 Verify steam pressure mode controller is set to maintain 1092 psig.

6.4.2 If condenser is not available:

A. Switch the MS LINE SD/PWR RLF valves (IPV2000, 2010,

- 2020) to POWER RELIEF position.

B. Verify the MS POWER RELIEF Controllers are set to maintain 1090 peig.

65 If the PZR POWER RELIEF VALVES (PCY 444B, 445A, 445B) actuated during the transient, verify their closure when pressurizer drops below 2335 psig.

, 6 5.1 If a pressurizer, power operated relief valve fails to close, CLOSE the associated. RELIEF ISOLATION valve' -

(MVG-8000A, B OR C).-

6.6 Shutdown and isolate BTRS system to prevent inadvertent dilution of the reactor coolant system:

6.6.1 OPEN BTRS Bypass Flow Valve, HCV 387 6.6.2 Place BORON THERMAL REGEN SELECT to 0FF.

6.7 Verify Source Range High Voltage comes on as intermediate power range drops below P-6 (10-10 amps). Select both source range channels on N45 6.7.1 IF NOT RESET Source Range Train A and Train B.

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E0P-5 PAGE 4 -

REVISION 2 10/6/80 6.8 Verify main suction oil pump and turning gear oil pump start at approximately 1700 rpm. (Turbine speed) 69 Start motor dr'ven i emergency feedwater pumps A and 'B and throttle emergency feedwater flow to maintain steam generator at nc load level of 25% narrow range span.

6.10.1 The flow control valves must be RESET and returned to MANUAL before they can be throttled.

6.10 Trip all operating main feedwater pumps.

6.11 Notify load dispatcher.

6.12 As turbine speed apprcaches 900 rpm verify turbine rotor lift pumps are running.

6.13 Adjust main turbine oil cooler ITV-4211 to maintain oil temperature of 90*P as indicated on TI-4211.

6.14 Stop condensate and feedwater booster pumps as desired for plant conditions. .

6.15 Open turbine system drain valvec as per SOP-214, Section 6.1 3.E.

6.16 Obtain boron sample and verify SD margin.

6.17 Verify turbine turning gear engages when turbine is at zero speed.

6.17 1 IF NOT secure Seal'S.t,5.am and Break Condenser Vacuum.

6.18 Complete Attachment II to determine subsequent action for achieving final conditions.

6.19 complete STP-345 001, Punctional Test of P-4 interlock both before and after resetting Reactor Trip breakers.

NOTE: Test performed by I & C Technicians. j l

70 FINAL CONDITIONS - -

J 7.1 If a normal startup and return to power is permissible proceed with start-up as per GOP-2 as determined by existing conditions.

7.2 If cause of reactor trip cannot be determined or corrected, unit may be maintained in hot shutdown condition or placed in a cold shutdown condition per GOP-6 'and GOP-7, at the discretion of the Shift Supervisor after consultations with the Operations Supervisor or Plant Manager.

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30P-5 ATTACHMENT I PAGE 1 of 1 REVISION 2 REACTOR TRIPS AND SETPOINTS

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1. MANUAL

2. SAFETY INJECTION Any of 5 signals 3 SOURCE RANGE HIGH FLUX 102 CPS

4. INTERMEDIATE RANGE HIGH FLUI -

Current = 25% Power 5 POWER RANGE HIGH FLUX (LOW SETPOINT) 25% Power 6.- POWER RANGE HIGH FLUI (HIGH SETPOINT) 109% Power 7 POWER RANGE POSITIVE RATE +5%/2 Sec

8. POWER RANGE NEGATIVE RATE -5%/2 Sec 19 OVERTEMPERATURE AT 118% + Penalties

10. OVERPOWER AT 109% ! Penalties

11. LEVEL HIGH PRESSURIZER 92% Span

12. PRESSURE HIGH PRESSURI"ER 2380 PSIG 13 PRESSURIZER LOW PRESSURE (RATE SENSITIVE) 1870 PSIG

14. SINGLE LOOP LOSS OF FLcW <90% Plow in 1 of 3 loops 15 TWO LOOP LOSS OF FLOW <90% Flow in 2 of 3 loops

16. RCP BUS LOW VOLTAGE 4830 Volts 17 LOW LOW S/G WATER LEVEL Programmed

18. S/G PEEDWATER MISMATCH Programmed 19 TURBINE TRIP-(above 15% Rx Power) 800 psig EHC Press or 4/4 Stop Valves Closed

20. RCP. Low Frequency 57.5 HZ I

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E0P-5 ATTACEMENT II Pa6e'1 of 2 REVISION 2 -l REACTOR TRIP RECOVERY EVALUATION I. Event.

1.. Time /Date of Reactor Trip:

2. Operating parameters at time of Reactor Trip:

A. Reactor Power  %

• F (Tave)

B. Reactor Coolant Temperature:

1- C. Reactor Coolant Pressure: psig ..

3. Operation (s) in progress at-time of Reactor Trip: (i.e., normal operation, load changing, surveillance testing, boration or.

dilution, etc.)

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4. Cause of Reactor Trip

II. Event Evaluation.

l (Detail all Yes answers)

1. Has any Safety Limit (Tech Spec 2.1) been exceeded? YES NO l

j 2. Has any Limiting Safety Setting (Tech Spec 22) been exceeded?

YES NO i

3. Does condition (s) which' caused the trip still exist? YES NO l

4. Are there any Tech Spec LCO actio'.1 statements outstanding that preclude a return to power? YES NO I i 5. Does the event require prompt notification to the NRC as defined in Tech Spec Section 6 91.8. IES NO 4

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Eo?-5 ATTACEMENT II Page 2 of 2 REVISION 2

6. If questions above are answered NO, a normal startup and

, ret :rto power is permissabl.a. Notify the Operations Supervisor or Plant Manager no later than the first normal working day following the reactor trip.

7. If any question is answered YES notify the Operations Supervisor or Plant Manager immediately.

A. If question 1 is answered YES proceed to COLD SEUTDOWII as per GOP-6 and GOP-7 E. If questions 2 cnr 3 are answered YES remain in HOT STANDBY or HOT SEUTDOWN as per GOP-5 until the conditions which i caused the trip or exceeding the Limiting Safety System '

Settings have been evaluated and corrected.

C. If questions 4 is answered YES proceed to the mode of operation required by the appropriate Tech Spec action statement until the LCO has been satisfied.

D. If question 5 is answered YES subsequent action will be at the discretion of the Shift Supervisor after consultation with the Operations Supervisor or Plant Manager.

t III Action Taken.

i Senior Reactor Operator /

4 Signature Date

. Shift Supervisor . / '

Signature

• Date ,

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