ML19253B628

Monthly Operating Rept for Sept 1979

ML19253B628
Person / Time
Site:	Beaver Valley
Issue date:	10/04/1979
From:	Spitznogle A DUQUESNE LIGHT CO.
To:
Shared Package
ML19253B626	List: ML19253B625 ML19253B628
References
NUDOCS 7910160550
Download: ML19253B628 (5)

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OPERATING DATA REPORT DOCKET NO. 50-334 DATE m /4 /7o COMPLETED BY A.E.Soitznogle

, TELEPHONE. 412-643-5023 OPERATING STATUS

1. Urdt Name: Beaver Valley Power Station, Unit #1 Notes

2. Reporting Period: Seotember. 1979

3. Licensed Thermal Power (MWt): WO

4. Nameplate Rating (Gross MWe): 923

5. Design Electrical Rating (Net MWe): 852

6. Maximum Dependable Capacity (Gross MWe): 845

7. Maximum Dependable Capacity (Net MWe): 817

8. If Changes Occur in Capacity Ratings (Items Number 3 Through 7) Since Last Report, Give Reasons:

9. Power Level To Which Restricted.If Any (Net MWe): None

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10. Reasons For Restrictions,If Any:. N/A This Month Yr.-to-Date " Cumulative

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!!. Hours In Reporting Period 720 6,551 29,255

12. Number Of Hours Reacto: Was Critical 633.81 2,146.19 12,342.26

13. Resetor Reserve Shutdown Hours 0 0 4,482.8

14. Hours Generator On Line 630.65 2,076.67 11,680.84 IS. Unit Reserve Shutdown Hours 0 0 0

16. Gross Thermal Energy Generated (MWH) 1,419,642.12 4.626,960.30 25,495,355.25

17. Gross Electrical Energy Generated (MWH) 448,900 1,483,400 7,822,140

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18. Net Electrical Energy Generated (M1/H) 416.063 1.345.256 7.167,624 19.' Unit Srvice Factor 87.6 32.8 42.4

20. Unit Availability Factor 87.6 32.8 42.4

21. Unit Capacity Factor (Using MDC Net) 70.7 25.1 35.8

22. Unit Capacity Factor (Using DER Net) 67.8 24.1 34.3

23. Unit Forced Outage Rate 12.4 68.4 50.0

24. Shutdowns Scheduled Over Next 6 Months (Type. Date.snd Duration of Eschi:

November, 1979 - Major Modification and Refue~1ine Outage (acoroximately six months scheduled duration).

25. If Shut Down At End Of Report Perind. Estimated Date of Startup: N/A

26. Units In Test Status (Prior to Commercial Operation): Forecast Achieved INITIAL CRITICA LITY N/A N/A INITIAL ELECTRICITY N/A N/A COMMERCIAL OPERATION . N/A N/A 79101 606 Bo N 7)

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AVERAGE DAILi UNIT POWER LEVEL

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DOCKET NO. 50-334 UNIT BVPS Unit #1 DATE 10/4/79 t

COMPLETED BY A.E.Soitznocle TELEPHONE 412-643-5023_

MONTH September, 1979

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DAY AVERAGE DAILY POWER LEVEL DAY AVERAGE DAILY POWER LEVEL (MWe Net) (MWe-Net) g 780 g7 783 2 771 18 775 3 771 gg 783 4 775 20 139 -

5 775 0 21 6 771 0 22

. 7 783 23 0

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8 787 338 24 9 791 360 25 10 787 376 26

771 368 27 12 770 360 28 13 762 360 29 14 767 372 30 15 763 3g ---

16 788 INSTRUCTIONS On this formst. list the average daily unit power lesel in MWe Net for each day in the reporting month. Compu.e to the nearest whole megawait.

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DOCKET NO. 50-334 UNITSilUTDOWNS AND POWER REDUCTIONS UNIT NAM E IIVPS Unit #1 DATE 10/4/79 COMPLETED IlY A. E. Soltznogle REPORT MONTil September, 1979 412-643-5023 TELEPilONE

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, .$ g 3 jY5 Licensee jg f' , Cause & Correcti e 3g j .3 s 5 Even: 3, 2

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Action to

• i jE 4 5 ;f, = lleport a wU g '?

E Psevent Recurrente

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14 790920 F 89.35 A 3 79-39 ED GENERA Loss of No. 4 Inverter caused reactor

• trip with a safety injection.

Replaced output fuses and returned invertei to service. Unit placed back on the line.

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F: Forced

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, ) Reason: Method: Exhible G. Instrucilons j ) S: Schedu!cd A Eiguipment Failure (Explain) 1 Manual for Pseparation of Data '

D-Maintenance ei Test 2 Manual Drae - Entr> Shecis for 1.icensee

" C Refueling 3 Automatie Scram. Event Repose Ill:lu File (NUREG

, D Itegulatory ltestriction Olher (Explain) 01611

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IDOperator Training & License Examination F Administrative .*

G Oper.iiional Esini II:.xplain t E shibii ! - Same' Source 07/77) 11 Other (Esplain)

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DUQUESNE LIGHT COMPANY Beaver Valley Power Station Unit No. 1 Docket No. 50-334 Narrative Summary Of Operating Experience - S2ptember, 1979 Date Event September 1 to Station in Operational Mode 1 at a nominal 100% power.

September 9 September 10 to Station in Operational Mode 1 at a nominal 100% power.

September 13 The LA Low Head Safety Injection Pump was declared out of service at 1300 hours0.015 days <br />0.361 hours <br />0.00215 weeks <br />4.9465e-4 months <br /> on September 10 when the surveillance test flow criteria were not met. The check valve in the recirculation flow and test line was replaced and the pump returned to service at 1257 hours0.0145 days <br />0.349 hours <br />0.00208 weeks <br />4.782885e-4 months <br /> on September 13.

September 14 to Station in Operational Mode 1 at a nominal 100% power.

September 16

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September 17 to Station in Operational Mode 1 at a nominal 100% power.

September 18 Removed the No. 1 Emergency Diesel Generator from service at 1025 hours0.0119 days <br />0.285 hours <br />0.00169 weeks <br />3.900125e-4 months <br /> to repair a leak in the diesel generator cooling water line and returned the diesel generator to service at

• 0130 hours0.0015 days <br />0.0361 hours <br />2.149471e-4 weeks <br />4.9465e-5 months <br /> on September 18. At 0215 hours0.00249 days <br />0.0597 hours <br />3.554894e-4 weeks <br />8.18075e-5 months <br />, removed the No. 4

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Inverter from service and placed the No. 4 Vital Bus on its auxiliary power supply.

September 19 to Station in Operational Mode 1 at a nominal 100% power. The September 20 No. 4 Inverter was returned to service at 0139 hours0.00161 days <br />0.0386 hours <br />2.29828e-4 weeks <br />5.28895e-5 months <br /> on September 20. At 0502 hours0.00581 days <br />0.139 hours <br />8.300265e-4 weeks <br />1.91011e-4 months <br />, failure of the inverter caused a reactor trip and safety injection due to momentary opening of the steam dump valves when.the No. 4 Vital Bus e de-energized and re-energized during the inverter ra11ute.

The Station was then placed into a stable Operational Mode 3 condition. At 1108 hours0.0128 days <br />0.308 hours <br />0.00183 weeks <br />4.21594e-4 months <br />, an attempt was made to place the No. 4 Inverter back into service, causing another reactor trip (shutdown banks only) and safety injection. The vital bus was de-energized during the transfer, causing the high steam flow bistables to trip. The reactor plant was in a slightly cooled-down condition and had just passed through the low-low Tavg limit. The operator transferred the vital bus before blocking the safety injection signal, de-energizing the steam flow bistables and causing the reactor trip and safety injection.

At 1200 hours0.0139 days <br />0.333 hours <br />0.00198 weeks <br />4.566e-4 months <br />, the 1A Low Head Safety Injection Pump was removed from service to inspect the discharge line check valve.

At approximately 1400 hours0.0162 days <br />0.389 hours <br />0.00231 weeks <br />5.327e-4 months <br />, the No. 4 Inverter was placed into service.

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Beaver Valley Power Station, Unit No. 1 Docket No. 50-334 Narrative Summary Of Operating Experience - September, 1979 Continued)

Date Event September 21 to Station in Operational Mode 3 with Tavg approximately 545F.

September 23 Maintenance was being performed on the 1A Low Head Safety Injection Pump, the "A" River Water Header and the Nuclear Instrumentation System from September 21 through September 23.

At 2240 hours0.0259 days <br />0.622 hours <br />0.0037 weeks <br />8.5232e-4 months <br /> on September 21, the main steam trip valves were returned to service after replacement of the operating rupture discs. The Boron Injection Tank was returned te service at 0805 hours0.00932 days <br />0.224 hours <br />0.00133 weeks <br />3.063025e-4 months <br /> on September 22. At 1530 hours0.0177 days <br />0.425 hours <br />0.00253 weeks <br />5.82165e-4 months <br />, t he fuses to the condenser steam dump bistables providing for fast valve operation by bypassing the electrical-pneumatic signal converters were removed as an interim measure to prevent a recurrence of the previous plant trip. The reactor was critical at 1913 hours0.0221 days <br />0.531 hours <br />0.00316 weeks <br />7.278965e-4 months <br /> on September 23, the main turbine roll-off commenced at 2048 hours0.0237 days <br />0.569 hours <br />0.00339 weeks <br />7.79264e-4 months <br />, and the main unit output circuit breakers were closed at 2223 hours0.0257 days <br />0.618 hours <br />0.00368 weeks <br />8.458515e-4 months <br /> with 50 MWe load.

September 24 Station in Operational Mode 1. Increasing power and reached '

50% power at 0116 hours0.00134 days <br />0.0322 hours <br />1.917989e-4 weeks <br />4.4138e-5 months <br />.

September 25 Station in Operational Mode 1 at a nominal 50% power.

• September 26 to Station in Operational Mode 1 at a nominal 50% power. Placed

. September 27 the LA Heater Drain Pump on clearance for repacking at 0020 hours2.314815e-4 days <br />0.00556 hours <br />3.306878e-5 weeks <br />7.61e-6 months <br />. At 0200 hours0.00231 days <br />0.0556 hours <br />3.306878e-4 weeks <br />7.61e-5 months <br />, the hoisture Separator Reheaters were placed into service for testing. The Moisture Separator Reheaters were isolated at 2100 hours0.0243 days <br />0.583 hours <br />0.00347 weeks <br />7.9905e-4 months <br />.

September 28 to Station in Operational Mode 1 at a nominal 50% power.

September 30 Major Safety Related Maintenance - Seotember, 1979

1. Re-aligned and re-coupled the 1C Charging Pump.

2. Repaired leaks in the cooling water lines to the No. 1 Emergency Diesel Generator. At first, the flanges were tightered; but, when the leakage continued, a section of piping was replaced.

3. Replaced the rupture discs on the main steam trip valves' pneumatic operators after the discs were ruptured during the reactor trip and safety injection on Septe=ber 20.

4. Performed various repairs to the No. 4 Inverter. The initial problem was frequency drift, which was corrected by replacing the oscillator card during September 18-20. The No. 4 Invert ?r .:ailure was investigated af ter the reactor trip. The output fuses had blown but no reason could be determined.

The fuses were replaced and the unit was returned to service on September 20.

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