ML19269C675

Monthly Operating Rept for Jan 1979

ML19269C675
Person / Time
Site:	Beaver Valley
Issue date:	02/05/1979
From:	Witkowsky F DUQUESNE LIGHT CO.
To:
Shared Package
ML19269C674	List: ML19269C673 ML19269C675
References
NUDOCS 7902120062
Download: ML19269C675 (6)

Text

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THJS DOCUMENT CONTAINS P00R QUAUTY PAGES OPERATING DATA REPORT

! SOCKET NO. 50-334 DATE 2/5/79 COMPLETED BY F. P. Witkowsky TELEPHONE. 412-641- 5023 OPERATING STATUS

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

2. Reporting Period:

3. Licensed Thermal Power (MWt): 2660

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): 800

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

10. Reasons For Restrictions,If Any:. N/A a

This Month Yr.-to.Date Cumulative

11. Hours In Reporting Period 744 744 274144

12. Number Of Hours Reactor Was Critical 366.92 366.92 10562.99

13. Reactor Reserve Shutdown Hours 417.07 417.07 5899.87

14. Hours Generator On.Line 339.16 339.16 9918.86

15. Unit Reserve Shutdown Hours 0 0 0

16. Gross Thermal Energy Generated dH) 787964.87 787964.87 21656359.82

17. Gross Electrical Energy Gen .ated (MWH) 256400 ,_,

256400 6595140

18. Net Electrical Energy Generated (MWH) 234579 234579 6026947

19. Unit Service Factor 45.5 45.5 47.2

20. Unit Availability Factor 45.5 45.5 47.2

21. Unit Capacity Factor (Using MDC Net) 39.4 39.4 41.6

22. Unit Capacity Factor (Using DER Net) 36.9 36.9 38.6

23. Unit Forced Outage Rate 55.2 55.2 40.4

24. Shutdowns Scheduled Over Next 6 Months (Type. Date,and Duration of Each):

Weekend outane in March for a transformer channe out. Refueline outare on 23 of April, 1979.

25. If Shut Down At End Of Report Period. Estimated Date of Startup:

26. Units In Test Status (Prior to Commercial Operation): Forecast Achieved INITIA L CRITICA LITY N/A N/A INITIAL ELECTRICITY N/A N/A COMMERCIA L OPERATION N/A N/A 7 9 0 212 0 O GL (,f77)

AVERAGE DAll UNIT POWER LEVEL DOCKET NO. 50-334 UNIT BVPS Unit #1 DATE 2/5/79 COMPLETED BY _F. P. Witkowsk TELEPHONE 412-643-5023_

MONTH January, 1979 DAY AVERAGE DAILY POWER LEVEL DAY AVERAGE DAILY POWER LEVEL (MWe Net) (MWe-Net) g 801 g7 0 2 804 18 381 3 600 39 0 4 0 20 493 5 0 21 721 6 0 22 808 0 788 7 23 0 829 8 24 9 0 25 821 10 0 26 296 II 0 27 285 0 192 12 28 0 C07 13 29 0 816 14 30 0 759

'45 33 16 0

INSTRUCTIONS On this format. list the average daily unit power leselin MWe. Net for each day in the reporting month. Compute to the nearest whole megawatt.

(9/77)

DOCKETh0. 50-334 UNIT SHUTDOWNS AND POWER REDUCTIONS UNIT NAME BVPS Unit #1 DATE 2/5/79 January, 1979 COMPLETED BY F. P. Witkowsky REPORT MONTil 412-633 5023 TELEPilONE 1

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., .! ? 3 ~ E' E Licensee ,E t, N7, Cause & Cor rectise Date i 3g 4 2g5 Event 3,7 53 Action to 3: $ 35g Report 2 aV 5' v

Prevent Recurrence Q

1 790103 F 347.98 A 3 79-4 HP VALVEX Reactor trip from 99% F.P. and safety injection due to high steam line flow coincident with low steam pressure in the A 6.B loops when C main steam stop valve tripped close.

2 780118 F 25.40 A 3 79-5 HC VALVEX Reactor trip due to high steam flow coincident with low steam pressure and a safety injection signal. Heater

, drain valve [LCV-SD106A] failed open tripping main feed pumps and main steam dump valves cycled open. Heater drain valve [LCV-SD106A] was equalized to preventing open.

3 790120 F 3.57 A 3 79-6 EE CKTBRK Reactor trip from full power caused by loss of the #3 inverter. Failure of the #3 uninterruptible power supply resulted in loss of 1C reactor coolant pump breaker #3 above P8.

I 2 3 4 F: Forced Reason: Method: Exhibit G - Instructions S: Schedu!ed A Equipment Failure (Explain) 14tanual for Preparation of Data B4tairitenance of Test 2-Manual Scram. Entr> Sheets for Licensee C-Refueling J. Automatic Scram. Event Report ILE RI File (NUREG D. Regulatory Restriction 4-Ot her ( Explain) 016I1 l'-Operator Training & License Examination F Adnunistrative 5 G-Operational Esrur (Explaint Eshibit 1 Same' Source P7/77) Il-Other ( E xplain )

DOCKET NO. 50-334 UNIT SHUTDOWNS AND POWER REDUCTIONS UNIT NAME BVPS Unit #1 DATE 2/5/79 January, 1979 COMPLETED BY F. P. Witkowsky REPORT MONTil 412-643- 5023 TELEPilONE

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, .5 g 3 j .E h Licensee ,Eg ' h Cause & Correciise

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4 790126 F 13.14 G 3 None CH ZZZZZZ Reactor trip from 100% F.P. on low pressurizer pressure due to over-feeding the IB steam generator followeil by a feedwater isolation and reactor trip on high steam generator level of IB steam generator.

5 790128 F 11.20 A 3 None CJ VALVEX Reactor trip after reducing power below 10% (P-7) after losing cooling water to the 1C reactor coolant pump.

A blown diaphram on component cooling water trip valve {TV-CCR103C11 was replaced.

6 790129 F 3.55 A 3 None CH VALVEX Reactor trip on Lo-Lo steam generator level due to intermittent failure to feed regulation bypass valve to go close.

1 2 3 4 F: Forced Reason: Method: Exhibit G Instinctions 5: Schedu!cd A Equipment Failure (Explain) 1-Manual for Preparation of Data B. Maintenance of Test 2-Manual Scram. Entr> Sheets for Licensee C Refueling 3 Automatic Scram. Event Repois ill~R) File (NUREG D Regutator) Restriction 4 Other (Explain) 0161) 1:-Operator Training & License Examination F-Administrative 5 G-Operational E:ror ( Explain t Eshibit I - Same'Somce 07/77) ll-Other ( E xplain)

DUQUESNE LIGHT COMPANY Beaver Valley Power Station Narrative Summary Of Operating Experience - January, 1979 Date Event January 1 to January 3 and January 2, the plant was in Operational January 3 Mode 1 at ull power. At 1806 hours0.0209 days <br />0.502 hours <br />0.00299 weeks <br />6.87183e-4 months <br /> on January 3, the 1C Main Steam Trip Valve closed, causing a reactor trip and safety injection. Cause of trip valve closure was determined to have been from moisture, causing shorting of Valve Partial Stroke Test Switch. A plant cooldown was started at 2339 hours0.0271 days <br />0.65 hours <br />0.00387 weeks <br />8.899895e-4 months <br /> on January 3.

January 4 to The plant entered Operational Mode 5 at 1005 hours0.0116 days <br />0.279 hours <br />0.00166 weeks <br />3.824025e-4 months <br /> on January 12 January 4. During this outage period, maintenance was performed on the main steam trip valves, 1C Charging Pump, containment personnel air lock and main turbine.

January 13 to On January 13, at 1009 hours0.0117 days <br />0.28 hours <br />0.00167 weeks <br />3.839245e-4 months <br />, RCS heatup commenced. The January 17 plant entered Operational Mode 4 at 1340 hours0.0155 days <br />0.372 hours <br />0.00222 weeks <br />5.0987e-4 months <br /> on January 14, but startup was placed on hold because of condensate cation conductivity being out of specification.

At 0605 hours0.007 days <br />0.168 hours <br />0.001 weeks <br />2.302025e-4 months <br /> on January 14, the plant entered Operational Mode 3 and reached operating temperature at 2200 hours0.0255 days <br />0.611 hours <br />0.00364 weeks <br />8.371e-4 months <br />.

Startup remained on hold for completion of turbine maintenance.

January 18 On 1/18/79, the reactor was taken critical at 0144 hours0.00167 days <br />0.04 hours <br />2.380952e-4 weeks <br />5.4792e-5 months <br /> and the main unit was synchronized at 0430 hours0.00498 days <br />0.119 hours <br />7.109788e-4 weeks <br />1.63615e-4 months <br />. The reactor tripped on high steam generator level during the synchronizing transient. The reactor was critical at 0507 hours0.00587 days <br />0.141 hours <br />8.382936e-4 weeks <br />1.929135e-4 months <br /> and the main unit synchronized at 0605 hours0.007 days <br />0.168 hours <br />0.001 weeks <br />2.302025e-4 months <br /> with power level increased to full power. At 2205 hours0.0255 days <br />0.613 hours <br />0.00365 weeks <br />8.390025e-4 months <br />, a reactor trip and safety injection occurred from high steam flow when the heater drain tank high level dump valve failed open and load was being removed from the main unit in attempt to balance steam flow to feedwater capability.

January 19 On January 19, the reactor was taken critical at 1725 hours0.02 days <br />0.479 hours <br />0.00285 weeks <br />6.563625e-4 months <br /> and the main unit synchronized at 2329 hours0.027 days <br />0.647 hours <br />0.00385 weeks <br />8.861845e-4 months <br /> and power level increased.

January 20 on January 20 at 1733 hours0.0201 days <br />0.481 hours <br />0.00287 weeks <br />6.594065e-4 months <br />, a reactor trip occurred when No. 3 Vital Bus Inverter failed, giving false indication of a loss of one reactor coolant pump. The reactor was taken critical at 1927 hours0.0223 days <br />0.535 hours <br />0.00319 weeks <br />7.332235e-4 months <br /> and the mein unit synchronized at 2107 hours0.0244 days <br />0.585 hours <br />0.00348 weeks <br />8.017135e-4 months <br /> and power level increased.

Narrative Summary Of Operating Experience - January, 1979 Date Event January 21 to The plant was in Operational Mode 1 at full power.

January 25 January 26 On January 26, the reactor tripped at 0905 hours0.0105 days <br />0.251 hours <br />0.0015 weeks <br />3.443525e-4 months <br /> on high steam generator level while attempting to repair the 1B Fbin Feadwater Regulating Valve positioner. The reactor was taken critical at 1909 hours0.0221 days <br />0.53 hours <br />0.00316 weeks <br />7.263745e-4 months <br />, the main unit synchronized at 2213 hours0.0256 days <br />0.615 hours <br />0.00366 weeks <br />8.420465e-4 months <br />, and power level increased.

January 27 Plant operated between 20% and 50% power level for system load requirements and steam generator chemistry.

January 28 At 1218 hours0.0141 days <br />0.338 hours <br />0.00201 weeks <br />4.63449e-4 months <br /> with plant at approximately 65% power, the inside containment isolation trip valve for component cooling water to the 1C Reactor Coolant Pump failed shut. While decreasing load prior to securing the pump, the reactor tripped on low low steam generator level at 1237 hours0.0143 days <br />0.344 hours <br />0.00205 weeks <br />4.706785e-4 months <br />. The reactor was taken critical at 1402 hours0.0162 days <br />0.389 hours <br />0.00232 weeks <br />5.33461e-4 months <br /> for xenon follow.

After the failed valve diaphragm was replaced, the main unit was started up and synchronized at 2349 hours0.0272 days <br />0.653 hours <br />0.00388 weeks <br />8.937945e-4 months <br /> but the reactor tripped on low low steam generator water level during the transient.

January 29 The reactor was taken critical at 0154 hours0.00178 days <br />0.0428 hours <br />2.546296e-4 weeks <br />5.8597e-5 months <br />, the main unit synchronized at 0333 hours0.00385 days <br />0.0925 hours <br />5.505952e-4 weeks <br />1.267065e-4 months <br />, and power level increased, reaching full power at 0830 hours0.00961 days <br />0.231 hours <br />0.00137 weeks <br />3.15815e-4 months <br />.

January 30 to The plant was in Operational Mode 1 at full power.

January 31 Major Safety Related Maintenance - January, 1979

1. Containment air lock door repairs were started on January 5 and completed on January 7.

2. The rotating element of Charging Pump [CH-P-lC] was replaced between January 5 through January 13 because of low discharge pressure.

3. The 1B and 1C main steam trip valves were opened for internal inspection after tripping closed on January 3. The discs and seats were in good condition. The rocker shaft seals and packing were replaced to eliminate leakage on all three of the main steam trip valves.