ML20069A274

Monthly Operating Rept for Jan 1983

ML20069A274
Person / Time
Site:	Beaver Valley
Issue date:	02/04/1983
From:	Holtz J DUQUESNE LIGHT CO.
To:
Shared Package
ML20069A243	List: ML20069A240 ML20069A274
References
NUDOCS 8303150581
Download: ML20069A274 (7)

Text

- - _ _ _

DUQUESNE LIGHT COMPANY

• - Braver Valley Power Station NARRATIVE

SUMMARY

OF MONTHLY OPERATING EXPERIENCE - JANUARY 1983 January 1 Station entered the month operating at approximately 66%

through reactor power as requested by the system operator. At January 3 0600 hours0.00694 days <br />0.167 hours <br />9.920635e-4 weeks <br />2.283e-4 months <br /> on the 3rd a load increase was begun to bring reactor power to a nominal 100%. This was completed by 0700 hours0.0081 days <br />0.194 hours <br />0.00116 weeks <br />2.6635e-4 months <br />.

January 4 Station was in operational mode 1 with reactor power at a through nominal-100% and the reactor coolant system at normal oper-January 6 ating temperature and pressure.

January 7 Station in operational mode 1 with reactor power at a nominal 100%. At 0932 hours0.0108 days <br />0.259 hours <br />0.00154 weeks <br />3.54626e-4 months <br />, received a reactor / turbine trip due to loss of power to the Normal 4KV Busses LA and 1B. All auxiliary systems functioned as designed including the #1 Diesel Generator which started and sequenced on the loads for the 4KV Emergency Bus lAE. All three reactor coolant pumps tripped due to 2/3 bus underfrequency signals, and the Auxiliary Feedwater System started to feed the steam generators. At 0936 hours0.0108 days <br />0.26 hours <br />0.00155 weeks <br />3.56148e-4 months <br />, the 1C Reactor Coolant Pump was started to reinstate forced cooling flow to the reactor.

At 0940 hours0.0109 days <br />0.261 hours <br />0.00155 weeks <br />3.5767e-4 months <br />, steam generator feed flow was transferred from Auxiliary Feedwater to Main Feedwater via the Bypass Feed Regulating Valves. Also, at 0940 hours0.0109 days <br />0.261 hours <br />0.00155 weeks <br />3.5767e-4 months <br />, an Unusual Event, Loss of Off-site Power Capability (Partial), was declared, and the appropriate notifications were made as per the EPP Procedure. After the tripped relays in the Switchyard were reset, the 1A System Station Service Transformer was re-engergized. The Normal 4KV busses lA and 1B were then restored to operable status by closing their respective feeder breakers and the Unusual Event was terminated at 1014 hours0.0117 days <br />0.282 hours <br />0.00168 weeks <br />3.85827e-4 months <br />. The 1B Reactor Coolant Pump was restarted at 1020 hours0.0118 days <br />0.283 hours <br />0.00169 weeks <br />3.8811e-4 months <br />. At 1028 hours0.0119 days <br />0.286 hours <br />0.0017 weeks <br />3.91154e-4 months <br />, the 1A Reactor Coolant Pump failed to restart. At 1047 hours0.0121 days <br />0.291 hours <br />0.00173 weeks <br />3.983835e-4 months <br />, the Emergency 4KV Bus lAE was restored to its normal power supply and the No. 1 Diesel Generator was shutdown. After an investigation which found no problems, the 1A Reactor Coolant Pump was successfully restarted. The main turbine was placed on turning gear.

January 8 Station was in Hot Standby Mode 3. A containment entry was made at 0100 hours0.00116 days <br />0.0278 hours <br />1.653439e-4 weeks <br />3.805e-5 months <br /> to replace Source Range Detector N-32, which had failed to show any indication of reactor count rate when re-energized following the reactor trip on the 7th. The detector was energized and tested successfully at 1600 hours0.0185 days <br />0.444 hours <br />0.00265 weeks <br />6.088e-4 months <br />.

At 1636 hours0.0189 days <br />0.454 hours <br />0.00271 weeks <br />6.22498e-4 months <br />, reactor startup was commenced. The reactor went critical at 1710 hours0.0198 days <br />0.475 hours <br />0.00283 weeks <br />6.50655e-4 months <br />, and at 1912 hours0.0221 days <br />0.531 hours <br />0.00316 weeks <br />7.27516e-4 months <br /> the main unit generator was synchronized to the grid. At 1916 hours0.0222 days <br />0.532 hours <br />0.00317 weeks <br />7.29038e-4 months <br />, the reactor tripped on a high level indication in the 1B steam generator. After the plant was stabilized, reactor startup was commenced at 2028 hours0.0235 days <br />0.563 hours <br />0.00335 weeks <br />7.71654e-4 months <br />. The reactor went critical at 2040 hours0.0236 days <br />0.567 hours <br />0.00337 weeks <br />7.7622e-4 months <br />, and at 2113 hours0.0245 days <br />0.587 hours <br />0.00349 weeks <br />8.039965e-4 months <br /> the main unit generator was synchronized to the grid. Reactor power was increased to 60% as per system instructions.

8303150581 830209 PDR ADOCK 05000334 R PDR

2 NARRATIVE sum!ARY OF MONTHLY OPERATING EXPERIENCE - JANUARY 1983 (Cont.)

• . , 1 January 9 Station in operational mode 1 with reactor power approximately 60%. At 0800 hours0.00926 days <br />0.222 hours <br />0.00132 weeks <br />3.044e-4 months <br />, the load was increased per system request. J This increase was completed at 1030 hours0.0119 days <br />0.286 hours <br />0.0017 weeks <br />3.91915e-4 months <br /> with reactor power at 86%.

l January 10 Station in operational mode 1 with reactor power at 86%. The

1. 1 Battery Charger was declared out of service at 0545 hours0.00631 days <br />0.151 hours <br />9.011243e-4 weeks <br />2.073725e-4 months <br /> 4

due to low voltage output. At 0630 hours0.00729 days <br />0.175 hours <br />0.00104 weeks <br />2.39715e-4 months <br />, the load was in-creased to a nominal 100% at the request of the system operator. At 1100 hours0.0127 days <br />0.306 hours <br />0.00182 weeks <br />4.1855e-4 months <br />, the #1 Battery Charger was returned to operable status following investigation and repair.

January 11 Station in operational mode 1 with reactor power at a nominal through 100% and the reactor coolant system at normal operating January 13 temperature and pressure.

January 14 Station in operational mode 1 with reactor power at a nominal 100%. At 1654 hours0.0191 days <br />0.459 hours <br />0.00273 weeks <br />6.29347e-4 months <br />, oil circuit breaker [0CB-83] tripped, thereby causing the station to lose off-site power capability.

At 1704 hours0.0197 days <br />0.473 hours <br />0.00282 weeks <br />6.48372e-4 months <br /> an unusual event was declared since this is a limiting condition for operation during loss of off-site power sources. .Both diesel generators were started to satisfy the technical specifications for loss of off-site power.

Investigation of the problem found the cause of the breaker trip to be an overexcitation relay [59-109]. At 2204, the unusual event was terminated when [0CB-83] was declared operable following repair of the relay.

January 15 The following load changes took place during this period at through the request of the system operator: At 0000 hours0 days <br />0 hours <br />0 weeks <br />0 months <br /> on the January 26 15th, reactor power was reduced from 100% to 80%. At 0815 hours0.00943 days <br />0.226 hours <br />0.00135 weeks <br />3.101075e-4 months <br /> on the 17th, reactor power was increased to a nominal 100%. At 0020 hours2.314815e-4 days <br />0.00556 hours <br />3.306878e-5 weeks <br />7.61e-6 months <br /> on the 23rd, reactor power was reduced to 94%. At 0530 hours0.00613 days <br />0.147 hours <br />8.763227e-4 weeks <br />2.01665e-4 months <br /> on the 24th, reactor power was increased to a nominal 100%.

January 27 Station in operational mode 1 with reactor power at a nominal 100% and reactor coolant system at normal operating tempera-ture and pressure. At 2120 hours0.0245 days <br />0.589 hours <br />0.00351 weeks <br />8.0666e-4 months <br />, a crew entered containment to view a leak in the 'B' reactor coolant pump cubicle. The crew noted several flange and packing leaks. The leak rate was estimated to be approximately 0.2 GPM.

January 28 Station in operational mode 1 with reactor power at a nominal through 100% and reactor coolant system at normal operating temperature January 31 and pressure. At 0200 hours0.00231 days <br />0.0556 hours <br />3.306878e-4 weeks <br />7.61e-5 months <br /> on the 29th, reactor power was decreased to 92% at the request of the system operator. At 0020 hours2.314815e-4 days <br />0.00556 hours <br />3.306878e-5 weeks <br />7.61e-6 months <br /> on the 30th, reactor power was reduced again to 82% per system. At 0705 on the 31st, reactor power was in-creased back to a nominal 100% as requested by system operator.

DUQUESNE LlGHT COMPANY ,

Bssvar Valley Powar Station l MAJOR SAFETY-RELATED MAINTENANCE - JANUARY 1983

1. Began overhauling reactor plant river water pump [WR-P-lA). Shaft sent out for balancing.

2. Instrument and Control replaced the preamp and detector for source range Channel N-32. Detector was tested satisfactorily.

i

OPERATISG DATA REPORT

- DOCKET NO. 50-334 DATE 2-4-83 COMPLETED BY _ J. L. !!altz TELEPHONE. 412-64 4-)yg,9 OPERATING STATUS

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

' Jaruary, 1983

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 Ca.pacity (Gross MWe): 860

7. Maximum Dependable Capacity (Net MWe): -810 g

8. If Changes Occur in Cap.acity Ratings (Items Number 3 Through 7)Since Last Report,' Jive Reasons:

9. Power Level To Which Restricted,if Any (Net MWe). None

10. Reasons For Restrictions.If Any:. -

N/A -

_ . This Month Yr..to.Date " Cumulative .

, 11. Hours In Reporting Period -

~

744 "744 T 59.208 -

12. Number Of Hours Reactor Was Critical 711.0' 711.0 25,528 5

13. Reactor Reserve Shutdown Hours 0 0' e 4,482.8-

14. Hours Generator On-Line 708.4 708.4 24,508.6

15. Unit Reserve Shutdr,wn Hours 0 0 0

16. Cross Thrmal Energy Generated (MWH) 1,734,339.0 1,734,339.0 54,244,520

17. Gross Electrical Energy Generated (MWH) 571,100 571,100 17,083,740

18. Net Electrical Energy Generated (MWH) 544,494 544,494 15,756,611 *

19. Unit Service Factor 95.2 *95.2 43.3

20. Unit Availability Factor 95.2- 95.2 43.3

21. Unit Capacity Fa'etor (Using MDC Net) 90.4 90.4 .36.1*

22. Unit Capacity Factor (Using DER Net) 85.9 85.9 34.4*

23. Unit Forced Outage Rate 4.-8 4.8 35.5

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

Shutdown for 3rd refueling scheduled to begin June 11, 1983 -

Projected duration is 14 weeks.

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

• These items contain corrected figurcs per 1982 operating sts.Listics (9/77) audit.

UNITSHUTDOWNS AND POWER REDUCTIONS DOCKET NO. 50-334 ,

y UNIT N AME BVPS Unit #1 l DATE 2 83

',' J. L. lloltz

. REPORT MONTil January COMPLETED BY 1

. TELEPilONE (412) 643-1369 "E -

e ce = r 5

.2 E g 3.os ;i licensee ,E.+, -4 Cause & Currecieve No- DJ'e h 3? i Ej5 Event E ~! h3 Atilon en j

H

$5 $ jgg Repose s AU

]' Prevent Recurrente 6

l 1 830107 F 33.6 A 3 83-2/03L EB RELAYX At 0930 hours0.0108 days <br />0.258 hours <br />0.00154 weeks <br />3.53865e-4 months <br />, line backup timer 1

?

62-Z41 in switchyard operated, which in turn operated 87-Z41X and 872141XL auxiliary trip and lockout relays.

This tripped all 138K7 breakers on j No. 1 - 138KV bus, including the one serving the 1A station service trans-

• former,and sent a remote trip signal to the plant to allow high speed transfer of station service to alter-j e nate source 1C transformer. The IC transformer ia out of service thus caus.ing a reactor trip on a 2/3 reactor coolant pump bus undervoltage signal. No conclusive evidence was found to indicate the cause of the 1

2 3 -t F: F nced Reason: Hethod Exhible G. Instructions 5: Schedu!cd A. Equipment Failure (Explain) 1-Manus 1 Int Pseparation of Data B. Maintenance of Test 2-Manual Scram C Refueling Entr) Sheets for Iicensee 3-Automatic Scram Event Repine iLFRI FileiNUREG D Regulatin) Restriction 4-Continued From Previous Month 0161)

E-Operator Training A License Examinalism 5-Reduction F Administrative 9-Other .  ?

G-Operational Ee ror IExplain t ,

Eshihin I - Same Source t'l/77)  !! OiherIE xplaing

1 .

UNIT SilUTDOWNS AND POWER REDUCTIONS DOCKET NO. 50-334 ,

i UNIT NAME BVPS Unit il DATE 2-2-83 COMPLETED BY J. L. Holtz

' REPORT Af0NTit Janua % TELErilONE (412) 643-1369 U

l '

3 -

I s ,* ~y b3 k b LIC'"5** $'., h., cause A correciise of*

"I  !! =

5E E 4 2 g oc j di j Event Repore s m2

fi0 g Atigon in Prevent Recurrente c5 i

h 1 830107 F 33.6 A 3 83-2/03L EB RELAYX timer operation. Possible causes were found and work is being done to eliminate recurrence of the problem.

L q 2 830108 F 2.0 A 3 N/A Cll VALVEX While increasing reactor power with the 1B Steam Generator Level Control in manual, operator attempted to

, close the bypass feedwater regulating valve when steam generator level was 1 40% and rising. The slow response j .- of the bypass valve allowed the S/G j level to continue to rise until the j turbine tripped on a high S/G 1evel

, indication. A design change package j has been generated to reduce the i response time of the S/G bypass j valves.

a

.j ,

I 2 i 3 4 p F: F.nced Reason:

j q S: Sc hedu,ed A Eiluipment Failure (Explain)

B-Maintenance or Test Hetheir 1-Manual-Exhibit G. Instructions for Pseparation of Data 2-Manual Scram .

Entr) Sheets for I.icensee C-Refuchng 3-Automatic Scram Event Rep.we ll.1 RI File tNUREG D Regulator) Restriction 4-Continued From Previous Month 0161)

l. Operator Training A l_iccuse Examination 5-Reduction

.L F Adruinistrative 9-Other 5 G Operational Enror ll:xplain) Eshible 1 SJme Somcc

-. I,8/77) Il-Other (Explain g I

9 r

o. ,

AVERAGE DAILi UNIT POWER LEVEL DOCKET NO.

50-334 UNIT 37?S Unit #1 DATE February 4. 1983 <

1 COMPLETED BY J. L. Holtz - l TELEPHONE 4,32-643-1369 .

January , 1983-DAY AVERAGE DAILY POWER LEVEL DAY AVERAGE DAILY POWER LEVEL (MWe. Net) (MWews) 544 g7 768 ._

g 537 gg 830 ,

2 I

739 19 822 3

826 3 825 4

822 _ , _ _ _ _ _

826 ,

g 822 22 822 6 ,

303 772 i 7 3 -

g 11 3 809 658 y 830 )

9 ,

i 777 M . 830 L 10

• 825 826 II - 27 ,

{ 826 3 822 g2 I ' "

13 29 821 681 I4 30 685 776 --

15 31 .

16 677 INSTRUCDONS On this format. list the avermye daily unit power levelin MWe-Net for esch day in the reporting munth. Compute to the nentest whole mepwsst.

19/77)

_ _ _ _ _ _ _ _ _ _ _ . _ . _ . . _ . . _ . . _ _ .__ _ . , __ _ _