ML20058Q366

Revised Unit 2 Monthly Operating Rept for Jul 1990 for San Onofre Nuclear Generating Station,Units 2 & 3

ML20058Q366
Person / Time
Site:	San Onofre
Issue date:	06/30/1990
From:	Sarette T SOUTHERN CALIFORNIA EDISON CO.
To:
Shared Package
ML13309A922	List: ML13309A921 ML20058Q357 ML20058Q366 ML20058Q380
References
NUDOCS 9008220049
Download: ML20058Q366 (4)

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ATTACHMENT A.

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Revised July 1990 Operating Status. sheet:.

SONGS Units 2 and 3' MOR ,

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NRC MONTNLY OPERATING REPORT.

DOCKET NO: 50-361-

~ UNIT NAME: SONGS - 2 DATE:'

COMPLETED BY: T. M. Sarette t TELEPHONE: (714)-368-9335 OPERATING STATUS-

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L 1. Unit'Name: San Onofre Nuclear Generatina Station.= Unit 2i E

2. Reporting Period: June 1990

3. Licensed Thermal Power.(MWt): 3390

4. ' Nameplate Rating (Gross MWe):- 1127 5_. Design Electrical Rating (Net MWe):: 1070 .

6. MaximumDependableCapacity.(GrossMWe):- 1127 l

7. Maximum Dependable Capacity (Net MWe): 1070

8. If Changes occur In capacity Ratings (Items Number 3 Through 7). 1 Since Last Report,.Give Reasons:' NA~ ,  !

9. Power Level To Which Restricted, If Any (Net _ MWe): NA- 4

10. Reasons for Restrictions, If Any: NA-l This Month = Yr.-to-Date- Cumulative-  !

11. Hours'In Reporting Period ..

720.00. ~4.343.00 60.216.00 i

12. Number Of- Hours Reactor Was Critical; 720.00 4.308.17 43 375.01

13. Reactor-Reserve. Shutdown Hours 0.00; 0.00- 0.00= J

14. Hours Generator On-Line- 720.00 4.301.90- 42.444.93 j 115. Unit Reserve Shutdown Hours 0.00 0.00 0.00 1

16. Gross 4 Thermal Energy Generated l(MWH)'.' 2.397.614.87 14.445.737.39 138.380.766.71

17. Gross Electrical- Energy Generated -(MWH). 815.935.00; 4.966.640.00. 46.941.347.00 .

18. - Net' Electrical Energy Generated (MWH) : *778.790.00 *4.741.002.00. *44.483.846.24 , .l

19. Unit Service Factor. 100.00%' :99.05% 70.490 j

20. Unit Availability Factor: -100.00% 99.05%' 70.49%- j

21. Unit. Capacity-Factor (UsingMDCNet) *101.09%: *102.02% 69.04%  !

22. Unit Capacity Factor (Using DER Net) *101.09%:. t*102.02% -69.04%

23. -Unit Forced Outage Rate -0.00% 0.00% -6.06%'

24.. ShutdownsScheduledOverLNext6 Months (Type,10 ate,tand; Duration-of-Each): .  :

A Steam Generator Inspection outaae is scheduled t.' commence on or before July 31.1990. Outaae duration is forecast"for 34 tavs. 1 L '25. If Shutdown At End Of Report Period, Estimated Date of Startup:- NA  ;

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26. Units 1In Test Status (Prior To Commercial Operation): Forecast. Achieved u ,

j INITIAL CRITICALITY- < NA NA INITIAL ELECTRICITY NA NA C0004ERCIAL OPERATION! NA NA

• . Data corrected since previous submi ttal j 1

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L ATTACHMENT B' Challenge to Unit'3 Safety Valve; 3 t

, SONGS Units'21and: 3 MOR' -!

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. =.. T DESCRIPTION OF A CHALLENGE-T0 UNIT 3 SAFETY VALVE On July 15, 1990 at 2257. with Unit 3 in Mode 3 following the Cycle 5 refueling outage, Main Steam Safety-Valve (MSSV) 3PSV8412 lifted for approximatel minutes at approximately 1025 psia. Since Technical Specification (TS)y3.7.1.1 two requires a minimum lift setpoint of 1103 psia for this safety valve, it was declared inoperable and the Power Level-High reactor trip set point was reduced within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> as required per TS Action Statement 3.7.1.1.a.

On July 16, 1990, testing of MSSV 3PSV8412, which had been refurbished by the Crosby-Valve and Gage Company during the Unit 3, Cycle 5 refueling outage, confirmed that it's lift setpoint was approximately 80 psia below the TS minimum lift set point. Since four additional Unit 3 MSSVs had been refurbished by the Crosby Valve and Gage Company during the Cycle 5 refueling outage, these four valves were tested to confirm their lift set points. Each of these valves were found to have lifted between 20 to 30 psia below their TS minimum set points.

Following each valve test, the lift set point was promptly adjusted to the required TS setting.

On July 17, 1990, as a result of SCE's investigation unto the cause of.the low lift set points, it was discovered that the lift setting adjustment anc testing _

performed at Crosby was conducted with the valves in a configuration different than the plant configuration. S)ecifically, the MSSV's lift set points were established without lagging on t1e valves. Thus, the temperature profile of the valves differed from their normally lagged condition.

Also on July 17, 1990, a review of Unit 2 MSSVs identified five additional valves which had been refurbished by Crosby. These five Unit 2 valves had been.

installed with lagging during the Unit 2 Cycle 5 refueling outage and had been considered operable since' December 2, 1989, when the unit first entered Mode 3. Further review identified that three of these valves had their lagging removed on January 25, 1990, for an unrelated reason, and that these valves remained unlagged (i.e. operable). At 1401, the remaining two Unit 2 valves were declared inoperable and TS action statement 3.7.1.1.a was entered. Lagging on these two valves was immediately removed and-at 1700 the valves were declared:

operable.

The reporting of a challenge to a safety valve is required by Section 6.9.1.10 of Appendix- A, Technical Specification to Facility Operating License NPF-15 for San Onofre Unit 3. Additional information on this event is provided in Licensee Event Report 90-008, Docket Nos. 50-361 and 50-362.

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