ML19345D838

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Monthly Operating Rept for Nov 1980
ML19345D838
Person / Time
Site: Beaver Valley
Issue date: 12/03/1980
From: Timko D
DUQUESNE LIGHT CO.
To:
Shared Package
ML19345D835 List:
References
NUDOCS 8012170572
Download: ML19345D838 (8)
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DUQUESNE LIGHT COMPANY Beaver Valley Power Station NARRATIVE

SUMMARY

OF MONTHLY OPERATING EXPERIENCE-NOVEMBER 1980 l

November 1 Station in Operating Mode 3 with the Reactor Coolant System temperature through and pressure at approximately 545F and 2220 PSIG, respectively.

j Nove=ber 9 4

November 10 Station in Operating Mode 3 with the Reactor Coolant System temperature i through and pressure at approximately 545' and 2220 PSIG, respectively.

{ November 11 Commenced diluting of the Reactor Joolant System for the approach to i initial criticality at 2210 hours0.0256 days <br />0.614 hours <br />0.00365 weeks <br />8.40905e-4 months <br /> ot Nove=ber 10. Initial criticality was achieved at 0535 hours0.00619 days <br />0.149 hours <br />8.845899e-4 weeks <br />2.035675e-4 months <br /> on November 11 and Low Power Physics Testing was begun.

November 11 Station in Operating Mode 2 in the Low Power Physic's testing decade.

through Low Power Physics testing was in progress. On November 14 at 1952 November 15 hours the reactor was manually tripped in accordance with the Low Power Physics testing procedure. The reactor was returned to criticality at 0515 hours0.00596 days <br />0.143 hours <br />8.515212e-4 weeks <br />1.959575e-4 months <br /> on November 15.

November 16 Station in Operating Mode 2 in the Low Power Physics testing decade.

At 2330 hours0.027 days <br />0.647 hours <br />0.00385 weeks <br />8.86565e-4 months <br /> the reactor was manually tripped for Low Power Physics testing and at 0605 hours0.007 days <br />0.168 hours <br />0.001 weeks <br />2.302025e-4 months <br /> it was returned to criticality.

November 17 Station in Operating Mode 2 in the Low Power Physics testing decade.

At 1403 hours0.0162 days <br />0.39 hours <br />0.00232 weeks <br />5.338415e-4 months <br /> a Reactor Trip and Safety Injection occurred. One channel of the Steam Break Protection System was failing low,

oscillating about the trip point, and it was decided to place the

, channel in the tripped mode. The wrong channel was selected  ;

causing a 2/3 Low Steam Pressure Safety Injection & Reactor Trip.

At 2015 hours0.0233 days <br />0.56 hours <br />0.00333 weeks <br />7.667075e-4 months <br /> batching of the Boron Injection Tank was begun.

November 18 Station in Operating Mode 3 with the Reactor Coolant System j through temperature and presure at approximataly 542F and 2235 PSIG. The Nove=ber 19 reactor was returned to criticality at 2030 hours0.0235 days <br />0.564 hours <br />0.00336 weeks <br />7.72415e-4 months <br /> on November 19.

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! November 20 Station in Operating Mode 2 with a nominal 2% thermal power. Main Unit warm-up was in progress and the turbine achieved synchronous speed at 1842 hours0.0213 days <br />0.512 hours <br />0.00305 weeks <br />7.00881e-4 months <br />. At 1851 hours0.0214 days <br />0.514 hours <br />0.00306 weeks <br />7.043055e-4 months <br /> a reactor trip occured due

to a turbine trip from high steam generator level when the operator j had difficulty controlling the levels in MANUAL.

l November 21 Station in Operating Mode 3 with the Reactor Coolant System temperature and pressure at approximately 530F and 2235 PSIG. The reactor was taken critical at 0246 hours0.00285 days <br />0.0683 hours <br />4.06746e-4 weeks <br />9.3603e-5 months <br /> and the Unit was synchronized at 0650 hours0.00752 days <br />0.181 hours <br />0.00107 weeks <br />2.47325e-4 months <br />. At 0728 hours0.00843 days <br />0.202 hours <br />0.0012 weeks <br />2.77004e-4 months <br /> the turbine and reactor tripped due to 13 high Steam Generator level during transfer form the main feed-water system bypass flow control valves to the main flow control

, valves when a faulty signal isolator removed the feedwater flow signal to the automatic level controller.

8012170 572

DUQUESNE LIGHT COMPA.W Beaver Valley Power Station NARRATIVE

SUMMARY

OF MONTHLY OPERATING EXPERIENCE - November 1980 Nove=ber 22 Station in Operating Mode 3. The Reactor Coolant System temperature and pressure were approxi=ately 545F and 2235 PSIG. The reactor was returned to criticality at 1029 hours0.0119 days <br />0.286 hours <br />0.0017 weeks <br />3.915345e-4 months <br /> and the Main Unit was synchronized at 1345 hours0.0156 days <br />0.374 hours <br />0.00222 weeks <br />5.117725e-4 months <br />.

Nove=ber 23 Station in Operating Mode 1 at 35.5% reactor power. At 0058 hours6.712963e-4 days <br />0.0161 hours <br />9.589947e-5 weeks <br />2.2069e-5 months <br /> a reactor trip occured due to a turbine trip during performance of turbine thrust bearing test. The reactor was returned to criticality at 0338 hours0.00391 days <br />0.0939 hours <br />5.588624e-4 weeks <br />1.28609e-4 months <br />. At 0642 hours0.00743 days <br />0.178 hours <br />0.00106 weeks <br />2.44281e-4 months <br /> the reactor tripped on a lA low Steam Generator level due to the Main Feedwater System Bypass automatic Flow Control valve not working properly. The reactbr was returned to criticality at 1010 hours0.0117 days <br />0.281 hours <br />0.00167 weeks <br />3.84305e-4 months <br />. The reactor tripped again at 1847 hours0.0214 days <br />0.513 hours <br />0.00305 weeks <br />7.027835e-4 months <br /> on a 13 low stea= generator level when the 13 Main Feed Valve appeared to stroke very slowly with respect to the 1A and 1C Main Feed Valves. The reactor was returned to criticality at 2100 hours0.0243 days <br />0.583 hours <br />0.00347 weeks <br />7.9905e-4 months <br /> and the Main Unit was synchronized at 2135 hours0.0247 days <br />0.593 hours <br />0.00353 weeks <br />8.123675e-4 months <br />.

November 24 Station in Operating Mode 1 at a nominal 35.5% reactor power level.

through Novenber 25 November 26 Station in Operating Mode 1 at a nominal 46% reactor power level.

At 0144 hours0.00167 days <br />0.04 hours <br />2.380952e-4 weeks <br />5.4792e-5 months <br /> the reactor tripped due to a turbine trip when a technician inadvertently laid a relay case against the rectifier mounting studs in the Electro-Hydraulic Control Cabinet causing a loss of Electro-Hydraulic Control DC Voltage. The reactor was returned to criticality at 0413 hours0.00478 days <br />0.115 hours <br />6.828704e-4 weeks <br />1.571465e-4 months <br /> and the Main Unit was synchronized at 0524 hours0.00606 days <br />0.146 hours <br />8.664021e-4 weeks <br />1.99382e-4 months <br />.

Nove=ber 27 Station in Operating Mode 1 at a nominal 43% reactor power level.

through Nove=ber 30 i

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DUQUESNE LIGHT COMPMT Beaver Valley Power Station MAJOR SAFETY-REIATED .VAINTENANCE-NOVEMBER 1980

1. Calibration of the Rod Position Indicators were done by the Station

=aintenance and test groups.

2. Calibration of Pressurizer Level Transmitters were completed.
3. Hot setting inspections of approxi=ately 90% of the Grinnel Snubbers were completed.

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.l OPERATING DATA REPORT

. DOCKET NO. 50-334 D,:T" 12/3/SO COMPLETED v. S. ' . Tisko 1

. TELEPHONE a ^4'-6308 OPERATING STATUS 3eaver Vallev Peve ge3e g g g 3,m I. Unit Name:

2. Reporting Penod: Nevebe - i oc0 l ?c4n

' 3. IJcensed Thermal Power (MWt):

4. Nameplate Ratml(Cross MWeJ: 923
5. Design Dec*rical Ratmg(Net MWeg 352
6. Maximum Dependable Qpacty (Gross Mwe): 345

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7 Maximum Dependable Qpacity (Net MWe): at a

8. If Changes Oc::arin Qpecity Ratings (Irems Number 3 Throusa 7) Since W Report. Gir Reasons:
9. Power Level To Which Restricted. !f Any (Net MWe): No"*
10. Reasons For Rasmctions.If Any: N/A This Month YrAo.Date 'Camulative
11. Hours in Reportmg Pmod 720 8033 40!200
12. Number of Hours Resctor Was Critieni 3 " .63 333.63 R 79.34
13. Rasetor Reserve Shutdown Hours 0 0 4.43 2.8
14. Sours Generator On.Line 179.28 179.28 13.284 25
15. Unit Reserve Shutdown Hours 0 0 0 216,989.29 216,989.29 27,191,242.e2 l 16. Gross Thermal Energy Generated (MWH) j 17. Gross EIectrical Energy Generated (MWH) 46,200 , _ ,

46.200 8.324,140

18. Net Dectrical Energy Generated (MWH) 21.816 21.816 7,592,559 l 19. Unit Service Factor 24.9 2.2 33.7
20. Unir Availability Factor 24.9 2.2 33.7 l 3.7 0.3 26.0 l
21. Unit Qpacity Factor (Using MDC Net, j 22. Unit Qpacity Factor (Using DER Net) 3.6 0.3 24.7
23. Unic Forced Outage Rate 26.9 26.9 46.2 l
24. Shutdowns Scheduled Over Next 6 Months (Type.Date.and Duration of Eacht:

h ier modification outaze/W v 15, 1981/10 days.

25. If Shut Down At End Of Report Period. Estimated Date of Startup:
26. Units in Test Status (Prior to Commercial Operation n Forecast Achieved INITIAL CRITICALATY N/A V/A INITIAL ELECTRICITY N/A N/A COMMERCIA L OPERATION N/A N/A (4/77)

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F AVERAGE DAILY UNIT POWER LEVEL DOCKET NO-50-334 UNIT 2V?S Uni: 'I l DATE 12/3/80

  • A* I COMPLETED BY _

TELEPHONE 412-643-5308 e , 19 0 MONTH DAY AVERAGE DAILY POWER LEVEL DAY AVERAGE DAILY POWER LEVEL (MWe-Net) g 9,,3,g 17 0 I

0 3 0

1 0 0 3 9 '

0 4 0 ,j y 0 21 30 0 ,

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0 234 S

341 9 0 3, 0 26 229 to 0 372 Ii 7 0 381 12 0 3,3 g3 9 30 381 14" -

13 __ 33 16 0 INSTRUCTIONS On this roemat.!ist the average d:ily unit power lesel in MWe Net for each day in the reportine month. Cmnpute io the nearest whole megawatt.

(4/77)

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4 } lEM 5 Event y L' A u .n in i-35 ;p, Repius = a Le reevcus Resuncnte 6

3 801121 F 30.28 a 3 N/A Cil INSTRil Due to a failed feedwater flow signal isolator, time 111 main feed regulating valve went wide open during transfer from laypass flow control causing a high steam generator level trip befort the operator could regain manual control.

4 801123 F 17.0 A 3 N/A IIA INSTHil While performing turbine thrust bearing oil trip check, tlee turbine t ripped, which restilt ed in a reactor

, t r i gs. Investigated thrust bearink trip circuitry, found nothing wrong.

t' i 2 3 1 l~s F.utcd Reasius: Method: 1.ninbis G - histnis tiims 5: Sc hedu!cd A taguipmens failure (Laptain) , 141anual l'os Picpanis.in os Data li Maintenance ei Test 2 Mannal Soaui. 1.nu) Shecis sin Iiscence C Hefueling .l- Ausonutic Suans. 1 sent P p.us ei l'R t I sie iNilRI G D Regniaius) Restikilon -l Othes Ilimplaint tiltil i I: Opesatin Isaining a tiense I:xaininatiosi l'- Ad minisisalive 5 G Opeutional I ison ll.xplaint I sinine I - Same'S.m:.e l'8/77) It Othes (laplain g

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llNIT Silull) OWNS ANilPOWER HEl>UCilONS I ' E IO I nit #1

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_Et - Tl'nf o HEPOR I MONill hyendier COMPl.EIEllliY _{l 2-6Cl- $30ft lllIPHONE I

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33 3 E 1 itensce E.e, '< t, Cause & Cunestne l  %. Date

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35 j~ d 4 2 5 sg jg Event y aO p Atil.ni sie Hepose a g' Psevens Hetiusense 6

t 5 801123 F 3.08 C 3 N/A Cil INSTRU Operator unfamiliarity witle the 4

sluggish control action of the main feed regulating valves and feed 1.ypas ,

! valves, when transferring from bypass flow control, caused a low steam 9 generator level trip.

6 801126 F 3.66 C 3 N/A IIA INSTHil When troubleshooting an alarm problem with the turbine Eli system, the Ell

} panel power supply was inadvertantly shorted out, causing a turbine trip and a reactor trip.

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I 2 .) -l F: f.uted Reason: Method: E xhiliii G - Inisini ti.wis S: 56 heduteil A-l.guipenens failure (Laplain) 14tanual In: Picpasaiion os pasa li-M.iintenance ei Test 2 Manual Scsain. I ning St.eces f.n I i.cusec l C-Hefueling .1 Ausineialit Stsani. I-=cus Rep.no 11 i Hil de int HI G l

1) Regulatus) Hesuicii.ni -l Othes Ilinplaint 0161l l' Opesaios Isaining A license lixaniination l' Adsninisisalive .'

G Operatiinul Iinne il aplalian I sinbn I - Sanic'S..uise I'l/77) 11 Othes llisplain t t

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