ML20002A749
| ML20002A749 | |
| Person / Time | |
|---|---|
| Site: | Summer  |
| Issue date: | 10/09/1980 |
| From: | SOUTH CAROLINA ELECTRIC & GAS CO. |
| To: | |
| Shared Package | |
| ML20002A746 | List: |
| References | |
| EOP-13, NUDOCS 8011210468 | |
| Download: ML20002A749 (10) | |
Text
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SOUTH CAROLINA ELECTRIC AND GAS COMPANY VIRGIL C. SUMMER NUCLEAR STATION
~ NUCLEAR OPERATIONS TJC _iA.1 0?E RA",'0.'.'S
. 0i 1:01VATOT ONLY EMERGENCY OPERATING PROCEDURE E0P-13 NATURAL CIRCULATION REVISION O OCTOBER 9, 1980 SAFETY RELATED Reviewed by:
ORIGINATOR (of this revision)
Date i
T ALIFIED REVIEWER-Date Approved:
~U71 RATIONS SUPERVISOR Date Date Issued:
Fort AP-101-2 (1/80) 8011210f/si
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E0P-13 Page i Revision 0 10/09/80 LIST OF EFFECTIVE FAGES PAGE REVISIOIT i
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E0P-13 PAGE I REVISION O 10/9/80 1.0-PURPOSE 1.1 _This procedure'irovides guidance t'o'the operator 'on how toi place'
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the reactor' coolant sys' tem in a~ stable condition utilizing natural circulation in the event of a loss of forced -reactor coolant flow.
Its intent is-to. insure adequate core cooling and prevent possible core damage due to overheating.
2.0 REFEREF9ES AND GLOSSARY 2.1 References 2.1.1 V. C. Summer Technical Specifications 2.1.2 V. C. Summer GOP-4, Power Operation 2.1 3
- 7. C. Summer GOP-5, Plant Shutdown from minimum load to Hot Standby 2.1.4 V. C. Summer E0P-1, Safety Injection 2.1.5 V. C. Summer E0P-4, Station Blackout 2.1.6 V. C. Summer E0P-5, Reactor Trip 2.1 7 Westinghouse generic procedure A-4 2.1.8 Westinghouse generic procedure A.6 2.1.'9 Westinkhouse 'Precautio:n, Limitation Setpoints' study for.
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C. Summer Nuclear ' Station. -
2.2 GLOSSARY 2.2.1 NATURAL CIRCULATION - The flow of coolant through the reactor coolant system utilizing a thermal driving head.
'2.2.2 ADEQUATE CORE COOLING - Adequate core cooling exists when:
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A.
Pressurizer pressure-is ma'intained above:(2000-). psia.'
The desired control band is'betwee'n (2200) psia and (2300) psia.
B.
Pressurizer level is maintained at or above programmed no-load level.
x C.
Average core coolant exit ~ temperature is being msintained at (600*F) or below by steam dump to the condenser and is slowly decreasing.
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E0P-13 PAGE 2 REVISION O 10/9/80 D.
Charging flow, letdown-flow and seal injection flow are. normal.
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E.:. Emergency feedwate.r pumps are in operation' delivering-to the active steam generators.
F.
Steam generator water level is being maintained above the top of the tube bundle by operator positioning of the Emergency feedwater flow control valves.. The desired control point is the no-load programmed level in each steam generator.
To cool down steps 7 & 8 are additionally required.
G.
Reactor coolant boron concentration in the active portions of the system is as necessary to provide the shutdown reactivity margin required by the Plant Technical Specifications when calculated on the basis of homogeneous distribution or boron within the total coolant mass.
H.
Reactor makeup control is in automatic and set to deliver at the required boron concentration.
2.2 3 ABBREVIATIONS BOP
- Balance of Plant CST
- Condensate Storage Tank E0P
. Emergency Operating Procedure dOP
- General Operating. Procedure KV
- Kilovolt MCB
- Main Control Board MSIV
- Main Steam Isolation Valve NR
- Nuclear Recorder PORY.
- P'ower. Operated Relief Valve.
- Reactor S/G-
- Safety Injection
E0P-13 PAGE 3 REVISION O 10/9/80
-S0P - System Operating Procedure
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- Hot Leg' Temperature' 30 SYMPTOMS 3.1 Rx Coolant low flow alarms actuated for all three loops.
32 Rx Coolant pump motors indicate O Amps and a green light.
33 Rx Coolant loop flow indicators indicate little or no flow.
34 Loss of BOP 7 2 K7 electrical buses.
4.0 AUTOMATIC ACTIONS 4.1 Ex Trip 4.2 Turbine Trip 43 Generator Trip (after 30 second time delay) 50 IMMEDIATE OPERATOR ACTIONS 51. Verify Reactor Trip / Turbine Tlip.
Manually. trip the reactor if power lev'e1 is,,below P-7 (10% Rx Power.). '
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5 1.1 Verify all control and shutdown rods are fully'inse hed by digital rod position indication and rod bottom lights.
A.
If the reactor has not tripped:
1.
Manually trip the Rx and turbine from the MCB.
3.
If.the'Rx does not trip place ISW1B1 and 1C1 BUS.
4 T'IE BKR in MANUAL and OPEN ISW1B1' a'nd '1C1'FDR f
EKR.
NOTE:
Bus 1b1 and 101 may be re-energized when rods are inserted.
5 1.2 EMERGENCY E0 RATE approximately 17 minutes (100 ppm) for each control or shutdown rod not fully inserted.
513 Verify Rx Power decreasing and transfer NR-45 recorder to one source-range and one intermediate channel.
E0P-13 PAGE 4 REVISION O 10/9/80 5 1.4 verify Turbine Trip:
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Tri'p turbine from MCB or turbine front standard'
_O_R 2)
Stop EHC Pumps A and B Cg 3)
Close all main steam isolation valves.
52 Verify pressurizer pressure and level are beginning to recover from the transient.
5 2.1 If not recovering evaluate conditions for safety injection systems.
If necessary safety inject and go to E0P-1, Safety Injection.
53 Verify main generator trip approximately 30 seconds after turbine trip.
531 Generator output breaker open.
532 Generator field breaker open.
533 Turbine speed decreasing.
5.4 Announce condition over paging system.
6.0 FOLLOW UP ACTIONS-NOTE:
Check or initial steps indicated sm they are I.
completed.
6.1 Verify all automatic and immediate actions have been completed.
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CAUTION:
If at any time it is determined that adequate core cooling does not exist, Safety Inject and go to 1
. EOP-1, Safety. In j ec.t. ion.
s NOTE:
At anytime. conditions permit and the requirements for starting a reactor coolant pump are satisfied as per SOP-101, restart at least ene reactor ecolant pump and use-normal plant recovery procedures.
NOTE:
This procedure may be used concurre":ly with E0P-1, Safety Injection; E0P-4 Station Blacrout; and E0P-5 Reactor Trin.
6.2 If the condenser is available, transfer STEAM DUMP SELECT switch to STM PRESS MODE position.
6.2.1 Verify STEAM DUMP pressure controller is set for 1092 peig.
20P-13 i
PAGE 5 REVISION O 10/9/80 6.3 If the condenser is not.available switch the MS LINE I
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631 ' Verify the controller for7each valve is. set for 1090 psig.
6.3 2 If the S/G POR7's 'are not operable from the MCB they can be operated with local manual hand wheels.
A.
Establish communication between the control room and the operator at the valve (s).
B.
Slowly open the valve until the desired steam flow to maintain 1092 psig is established.
633 If a S/G PORY sticks open it must be closed locally by operation of the manual hand wheel or by manually closing the isolation valve upstream of the S/G PORV.
6.4 Start or verify auto starting of the Emergency Feedwater Pumps.
NOTE:
Based on conditions both motor driven emergency feedwater pumps and the turbine driven emergency feedwater pump may have started.
It is preferable to use the two motor driven emergency feedwater pumps for cooldown operations.
6.4.1 Verify;, emergency feedwater flow to al.1 S./G's.
-6.5 If feedwater flow is unavailable, implement 20?-14, Inadequate Core Cooling, concurrently with this procedure.
6.6 Monitor condensate storage tank level throughout this procedure and:
6.6.1 If CST level reaches the low-low level alarm switch to service water backup:
.A.*
For motor driv.en emergency feedwater.. pumps open
~1.
MVG-1001A-EF 1
2.
MVG-1037A-EF 3
MVG-10013-EF 4
MVG-10373-EF B.
For turbine driven emergency feedwater pump open 1.
MVG-1002-EF and IVG-1037B OR 2.
MVG-1008-EF and XVG-1037A i
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l 6.6.2 If Emergency Feedwater Pump Suction Low alarm is received l
Verify automatic switch over to service water supply.
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E0@-13 PAGE 6 REVISION O 10/9/80 6.7 Adjust Emergency Feedwater flow to establish and. maintain stable
.yn,p/G levels of - between 25 an.d.30,g%..of. narrow range span.
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.g 6.7.1 Place TFV-3531, 3541, 3551 inLRESET than MANUAL.
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G.7 2 Ad'just HCV-3531, 3541, 3551 for desired flow.
6.7 3 Stop the Turbine Driven Emergency Feedwater Pump when S/G low level alarms clear.
6.7 Trip all operating Main Feedwater Pumps.
6.8 Monitor system parameters to verify that natural circulation is being established and that. plant conditions are stabilizing.
6.8.1 Verify steam generator pressures are stabilized at setpoint pressure (
1092 psig).
6.8.2 Verify TH is < 600*P and stable or decreasing.
6.8 3 Verify TH minus TC is between 15*F and 50*F.
6.8.4 Verify pressurizer pressure is recovering to normal operating pressure (
2235 psig).
pressurizer level is recovering to normal no-load 6.8 5 Verify (25% of span).
level 6.8.6
'i'erify. that RCS s.ubcooling exists,(> 50*F).
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decay heat from the'cose (Tg above 600*P or jncreasing) reset the MS LINE POWER RELIEF controller to a lower setpoint.
6.10 If Tg - TC T is greater than 50*F reduce emergency feedwater flow to raise TC. OR 6.10.1 Decrease steam dump flow.
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- 6. I t If pressurizet press.ure. is increasing de-e,ner61se pressur,iz'er.
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. heater ; groups' to stabilize.
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CAUTION:
Normal pressurizer spray is inoperable.
6.12 If pressuriser level is increasing adjust charging and letdown as necessary.
6.13 If pressurizer pressure and level continue to decrease slowly evaluate for an RCS leak and implement E0P-12, Loss of Reactor Coolant without Safety Injection, concurrently with this procedure.
E0P-13 PAGE 7 REVISION O 10/9/80.
6.14.TH TC reading will indicate. trends and may be irratic.
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6.1'41 Using the steam tables convert S/G pressure to saturation temperature and use as T -
C 6.14.2 Use the incore thermocouple to determine T.
This can H
be done on the plant computer.
A.
Push In-Core T/C map B.
Push Numerical 0 and Valve 1 C.
Push Valve 2 and Start 6.15 Maintain the reactor coolant system in a stable natural circulation mode while completing any concurrent emergency procedures.
T,Tr S/G 6.15 1 Initiate a log of Pressurizer Pressure, H
C pressure at 15 minute intervals.
NOTE:
The following sections will cool down the reactor coolant system utilizing natural circulation.
Do this section only if forced reactor coolant flow cannot be reestablished without cooling down.
6.16 Slowly decrease either the STEAM DUMP PRESSURE or S/G PORY controller (s) in 100 psig increments maintaining the minimum P
between steam generators.
6.17 Adjus.t ', emergency'* fe'edwater ' flow as necesshry to maintain stable 8/G l'evels.
6.18 Plot RCS temperature versus pressure on a Reactor Co71 ant System - Pressure / Temperature Limits curve using TH instead of T vg-a 6.19 Decrease pressurizer pressure to maintain < 1600 psid across the steam generator tubes.
6.19.1,De-energize.pressurtz,er heaters.
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6192 Cycle pressurizer PORV's.
CAUTION:
Verify pressurizer PORVS reset or close the associated isolation valve.
6.20 Wait between pressures decreases until natural circulation heat removal at the new pressure is confirmed and stabilized.
6.20.1 Tg has decreased and stable.
E0P-13 PAGE 8 REVISION O 10/9/80 6.20.2 Tg'.Tc is between 15' and 50*P.
i.'~l.:M 4 g.;2d d. Re Nt b CobNt nas'i.mi'nfmum ~of' 5 *P.?subeadlkndl $d I-%Midhi 6.21 Borate the reactor coolan't system as necessary to maintain the required shutdown reactivity margin as per 30P-106, Section 4.4.
6.21.1 Monitor nuclear instrumentation to confirm the conti.nued subcritical conditionjof, core.
6.21.2 Sample for boron.concintration to insure mixing.
A.
(All three hot legs B.
Pressurizer liquid volume C.
Letdown 6.22 Bypass steam dump interlock at 593*F by turning both INTERLOCK switches to Bypass Interlock.
NOTE:
Due to no flow in the RTD manifold it will be necessary to defeat the Tavg Interlock whenever Tavg indicates 553*F 6.23 Continue cooldown as per steps 6.16 through G.20 until reactor coolant system is at 350*F and 400 psig.
6.24 Reference GOP-6, Section 5.0 for additional actions.
7.0. F'INAS dONDItiONS.
7.1 The reactor coolant system is stable at 600*F in a free convection heat transfer mode or 7.2 The reactor coolant system has been cooled down to 350*F and depressurized to 400 psig and ready for RHR operation.
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