ML20134K152

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Monthly Operating Repts for Jan 1997 for Beaver Valley Power Station,Units 1 & 2
ML20134K152
Person / Time
Site: Beaver Valley
Issue date: 01/31/1997
From: David Jones, Legrand R
DUQUESNE LIGHT CO.
To:
NRC OFFICE OF INFORMATION RESOURCES MANAGEMENT (IRM)
References
NUDOCS 9702130149
Download: ML20134K152 (12)
v • d • e


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Shippin0 port, PA 15077-0004 Febmary 6,1997 Beaver Valley Power Station Unit 1 - Docket No. 50-334, License No. DPR-66 Unit 2 - Docket No. 50-412, License No. NPF-73 Monthly Ooerating Report U. S. Nuclear Regulatory Commission Document Control Desk Washington, D.C. 20555 Gentlemen:

In accordance with Appendix A, Technical Specifications, the Monthly Operating Report is submitted for Unit I and Unit 2 for the month of January,1997.

Respectfully, aqt h R. L. LeGrand i Division Vice President, ,

Nuclear Operations /

Plant Manager Enclosures

! cc: NRC Regional Office pl M King of Pmssia, PA 130038 p w The Nuclear Professionals 9702130149 970131

  • PDR ADOCK 05000334'-

R PDR '

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NARRATIVE

SUMMARY

OF MONTHLY OPERATING EXPERIENCE UNIT 1 L JANUARY 1997 l

l January 1 The Unit operated at s nominal value of 100% output.

l through

! January 23

-a January 24 - At 1900 hours0.022 days <br />0.528 hours <br />0.00314 weeks <br />7.2295e-4 months <br />, the Unit began a power reduction to approximatcly 90% output to clear the "B" Waterbox of the Main Unit Condenser for repai'. of a tube leak. An output of approximately 90% was achieved at 1940 hours0.0225 days <br />0.539 hours <br />0.00321 weeks <br />7.3817e-4 months <br />.

l . .

January 25 . Following clearing of the "B" Waterbox for repair.of a tube leak, the Unit began to f

escalate output to approximately 97% at 0235 hours0.00272 days <br />0.0653 hours <br />3.885582e-4 weeks <br />8.94175e-5 months <br />. The Unit achieved approximately 97% output at 0530 hours0.00613 days <br />0.147 hours <br />8.763227e-4 weeks <br />2.01665e-4 months <br />.

January 26 Following satisfactory repair of two tube leaks in the."B" Waterbox, the "D" Waterbox was cleared for testing, however, no tube leaks were found. Following return of both waterboxes to service, a return to full power was commenced at 2300 hours0.0266 days <br />0.639 hours <br />0.0038 weeks <br />8.7515e-4 months <br />.

January 27 A nominal value of 100% output was achieved at 0146 hours0.00169 days <br />0.0406 hours <br />2.414021e-4 weeks <br />5.5553e-5 months <br />.

I January 28 - The Unit operated at a nominal value of 100% output for the remainder of the report l through period.

January 31 In addition to the above, the following events which also occurred during the report period are being reported as required by Technical Specifications.

January 1 The Automatic Rod Position Deviation Monitor, although still functional, was not j through- considered - operable per Technical . Specifications. The limiting condition for

-January 31 - operation as specified in the Technical Specifications was met because the deviations between the indicated rod positions were verified to be within their 12 step limits by obtaining analog / digital rod positions at least once every 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />.

.l January 24 The Analog Rod Position Indication (ARPI) for control rod H-2 was declared

~ inoperable at 1944 hours0.0225 days <br />0.54 hours <br />0.00321 weeks <br />7.39692e-4 months <br /> due to reading greater than the Technical Specification limit ,

of 12 steps. Actual rod position was verified to be within the 12 step limit by j obtaining primary detector voltage readmgs.-

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- NARRATIVE

SUMMARY

OF t MONTHLY OPERATING EXPERIENCE ,

P UNIT 1  ;

JANUARY 1997 (Continued)

January 25 After the ARPI returned to within 12 steps, control rod H-2 was declared operable at 1030 hours0.0119 days <br />0.286 hours <br />0.0017 weeks <br />3.91915e-4 months <br />. Overhaul of the detector for control rod H-2 has been planned for during the next refueling outage. i e I

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AVERAGE DAILY UNIT POWER LEVEL DOCKET NO. 50 334 UNIT BVPS Unit 1 DATE February 3,1997 COMPLETED BY David T. Jones TELEPHONE (412) 393-4962 MONTH January 1997 DAY AVERAGE DAILY POWER LEVEL DAY AVERAGE DAILY POWER LEVEL i (MWe-Net) (MWe-Netj l 1 834 17 826 2 826 18 826 3 821 19 825 ,

4 819 20 829 5 822 21 830 6 831 22 827 .

7 831 23 832 8 ,,,

831 24 814 9 829 25 791 10 832 26 810 11 829 27 830 12 826 28 830 l 13 824 29 828 14 823 30 828 15 .,

823 31 827 16 826 INSTRUCTIONS On this form, list the average daily unit power level NIWe-Net for each day in the reporting month.

t Compute to the nearest whole megawatt.

l

. .s OPERATING DATA REPORT DOCKET NO.. 50-334 ,

REPORT DATE: 02/04/97 l COMPLETED BY: DAVID T. JONES l TELE? HONE: (412) 393-4962 l

OPERATING STATUS

1. UNIT NAME: BEAVER VALLEY POWER STATION, UNIT 1
  • Notes *
2. REPORTING PERIOD: JANUARY 1997 *
  • i
3. LICENSED THERMAL POWER (MWt): 2652 * *
4. NAMEPLATE RATING (Gross MWe). 923 * *
5. DESIGN ELECTRICAL RATING (Net MWe): 835 *
  • j
6. MAX. DEPENDABLE CAPACITY (Gross MWe) : 860 * * '
7. MAX. DEPENDADLE CAPACITY (Net MWe): 810 **************
8. IF CHANGES OCCUR IN CAPACITY RATINGS SINCE LAST REPORT, GIVE REASONS:

l

9. POWER LEVEL TO WHICH RESTRICTED, IF ANY (Net MWe): None )

10.' REASONS FOR RESTRICTIONS, IF ANY: N/A 1

THIS MONTH YEAR TO DATE CUMULATIVE l

11. HOURS IN REPORTING P2RIOD: 744,0 744.0 181944.0
12. NO. OF HRS. REACTOR WAS CRITICAL: 744.0 744.0 121391.9 1
13. REACTOR RESERVE SHUTDOWN HCURS: 0.0 0.0 4482.8 l
14. HOURS GENERATOR WAS ON LINE: 744.0 744.0 119230.6
15. UNIT RESERVE SHUTDOWN HOURS: 0.0 0.0 0.0
16. GROSS THERMAL ENERGY GEN. (MWH) : 1957638.0 1957638.0 289231380.5
17. GROSS ELECT. ENERGY GEN. (MWH)- . 648420.0 648420.0 93516012.0  :
18. NET ELECTRICAL ENERGY GEN. (MWH): 613780.0 613780.0 87475349.0 1
19. UNIT SERVICE FACTOR: (PERCENT) 100.0 100.0 67.3
20. UNIT AVAILABILITY FACTOR:(PERCENT) 100.0 100.0 67.3
21. UNIT CAPACITY FACTOR (MDC): PCT 101.8 101.8 61.7
22. U?iIT CAPACITY FACTOR (DER): PCT 98.8 98.8 59.8
23. Ut:IT FORCED OUTAGE RATE: (PERCENT) 0.0 0.0 14.9
24. SHUTDOWNS SCHEDULED OVER NEXT SIX MONTHS (TYPE,DATE,AND DURATION OF EACH):
25. IF SHUT DOWN AT END OF REPORT PERIOD, ESTIMATED DATE OF STARTUP:
26. UNITS IN TEST STATUS (PRIOR TO COMMERCIAL OPERATION) :

FORECAST ACHIEVED INITIAL CRITICALITY N/A N/A INITIAL ELECTRICITY N/A N/A COMMERCIAL OPERATION N/A N/A

UNIT SIIUTDOWNS AND POWER REDUCTIONS (220%) ' Docket No. 50-334 -

Unit Name BVPS Unit #1 Date - Febnsary 3,1997 Campicted By Dasid T. Jones REPORT MONTH January 1997 Telephone (412) 393-4 % 2 No. Date Typel Duration Reason 2 Method of Licensee System Component Cause & Corrective Action to Prevent (Hours) Shutting Event Report # Codc4 Codc5 Recurrence Down o Reactor 3 None i

I 2 3 4 F-Ferted Reason. Meehad: Exhibit F-Immerwcoms Ier Preparation of Desa Entry .

S-Scheduled A-Espupmere Faihme(Emplain) 1-Manual Sheets far Lacensee Event Report (IIR) File B-Manisenance er Test 2-Manual Sanni (NURE0016I).

C-Refinaling 3-Ameanishc Screan D-Reguimenry Restridian 44'est*d, frena Previous Mench F opermer Training A Uceme Exani 3-Re h 5 F-Ashnaustrative 94hher. Exhibit H-Same Source G-Opermeional Enw(Explain) 184Mher(Explain) t..___ _ _ _ _ . . . _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _

NARRATIVE

SUMMARY

OF MONTHLY OPERATING EXPERIENCE UNIT 2 JANUARY 1997 January 1 The Unit began the report period operating at approximately 93% output while through planned repair of the "B" Separator Drain Receiver Drain Pump occurred offsit. 1 January 2 January 3 Following repair and return of the "B" Separator Drain Receiver Drain Pump to service, the Unit commenced a return to full power at 1814 hours0.021 days <br />0.504 hours <br />0.003 weeks <br />6.90227e-4 months <br />.

January 4 A nominal value of 100% output was achieved at 0546 hours0.00632 days <br />0.152 hours <br />9.027778e-4 weeks <br />2.07753e-4 months <br />.

January 5 The Unit operated at a nominal value of 100% output.  !

January 6 At 0150 hours0.00174 days <br />0.0417 hours <br />2.480159e-4 weeks <br />5.7075e-5 months <br />, approximately 20 MWe of output was lost due to multiple secondary plant related component problems. At 0556 hours0.00644 days <br />0.154 hours <br />9.193122e-4 weeks <br />2.11558e-4 months <br />, the Unit experienced a Reactor l trip from approximately 98% output due to a Turbine Generator trip. This was I initiated by spurious operation of a Main Transformer Ground Protection Relay ]

unrelated to the secondary plant problems occurring at the time. The Unit was s ssequently stabilized in Mode 3.

Jan,ary 7 The Unit remained in Mode 3 while several secondary plant related component thrNgh problems which were observed prior to the trip and during the post-trip event Jar.uary 9 recovery required resolution prior to the Unit starting up.

1 January 10 The Unit remained in Mode 3 while preparations for entering Mode 2 proceeded. At 2249 hours0.026 days <br />0.625 hours <br />0.00372 weeks <br />8.557445e-4 months <br />, startup activities were aborted due to a potential problem concerning flood seals on the Recirculation Spray Pumps.

January 11 At 1550 hours0.0179 days <br />0.431 hours <br />0.00256 weeks <br />5.89775e-4 months <br />, Technical Specification 3.0.3 was entered based on a design basis I challenge of the Recirculation Spray Pumps during a flood scenario. Flexible boot flood seals were missing / degraded from all four Recirculation Spray Pumps between the pump casings and floor as required by the UFSAR. The Unit initiated a cooldown to Mode 5 at 1645 hours0.019 days <br />0.457 hours <br />0.00272 weeks <br />6.259225e-4 months <br /> while installation of flood seals proceeded.

Mode 4 was entered at 2221 hours0.0257 days <br />0.617 hours <br />0.00367 weeks <br />8.450905e-4 months <br />.

January 12 Mode 5 was entered at 2205 hours0.0255 days <br />0.613 hours <br />0.00365 weeks <br />8.390025e-4 months <br />.

January 13 Following installation of the flood seals for each Recirculation Spray Pump, the Unit commenced to heatup to Mode 4 at 2220 hours0.0257 days <br />0.617 hours <br />0.00367 weeks <br />8.4471e-4 months <br />. Mode 4 was entered at 2240 hours0.0259 days <br />0.622 hours <br />0.0037 weeks <br />8.5232e-4 months <br />.

. ___ _ _ _ _ _ . . . _ . . .___ _. ._ .~ _ . _

NARRATIVE

SUMMARY

OF 4

l

, MONTHLY OPERATING EXPERIENCE UNIT 2  ;

JANUARY 1997 l

(Continued) 4 i January 14 Mode 3 was entered at 0239 hours0.00277 days <br />0.0664 hours <br />3.95172e-4 weeks <br />9.09395e-5 months <br />. Mode 2 was entered at 1752 hours0.0203 days <br />0.487 hours <br />0.0029 weeks <br />6.66636e-4 months <br /> and the -

I reactor was taken critical at 1912 hours0.0221 days <br />0.531 hours <br />0.00316 weeks <br />7.27516e-4 months <br />. Mode I was entered at 2036 hours0.0236 days <br />0.566 hours <br />0.00337 weeks <br />7.74698e-4 months <br />.

, January 15 The Unit was synchronized to the electrical grid at 1310 hours0.0152 days <br />0.364 hours <br />0.00217 weeks <br />4.98455e-4 months <br /> and began power escalation at 1558 hours0.018 days <br />0.433 hours <br />0.00258 weeks <br />5.92819e-4 months <br />. Per a Station Management decision, escalation to full t

power was halted at approximately 28% output at 1900 hours0.022 days <br />0.528 hours <br />0.00314 weeks <br />7.2295e-4 months <br /> to evaluate the impact  :

on Beaver Valley of an industry event concerning a potential water hammer issue  ?

with the Recirculatica Spray System.  ;

Jar.uary 16 The Unit remained at approximately 28% output while evaluation of the impact of  !

l the potential water hammer issue with the Recirculation Spray System at Beaver  !

i. . Valley continued. l t January 17 - Following satisfactory evaluation of the impact of the potential water hammer issue l

with the Recirculation Spray System at Beaver Valley, the Unit commenced a load  !

increase towards 100% output at 2155 hours0.0249 days <br />0.599 hours <br />0.00356 weeks <br />8.199775e-4 months <br />.  !

January 18 The Unit continued to increase output towards full power while verification of through secondary plant operations continued.

. January 19

January 20 The Unit achieved a nominal vahie of 100% output at 1224 hours0.0142 days <br />0.34 hours <br />0.00202 weeks <br />4.65732e-4 months <br />. i l

[ January 2? The Unit operated at a nominal value of 100% output for the remainder of the report through' period. j January 31 l

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m. _ _. .. _ _ _ - _ _ _ _ _ _ . _ - . . .

. 1 AVERAGE DAILY UNIT POWER LEVEL DOCKET NO. 50-412 UNIT BVPS Unit 2 DATE February 3,1997 COMPI.ETED BY David T. Jones TELEPHONE (412)393-4962 MONTH January 1997 7

DAY AVERAGE DAILY POWER LEVEL DAY AVERAGE DAILY POWER LEVEL (MWe-Net) (MWe-Net)  !

l 792 17 161 2 786 18 530  !

3 791 19 820 P 4 826 20 831 5 833 21 834 6 202 22 831 7 0 23 840 8 0 24 839 9 0 25 839 10 0 26 840 11 0 27 839 12 0 28 842 13 0 29 828 14 0 30 828 15 37 . 31 827 16 141 l

INSTRUCTIONS On this form, list the average daily unit power level MWe-Net for each day in the reporting month.

Compute to the nearest whole megawatt.

. ni OPERATING DATA REPORT DOCKET NO., 50-412 REPORT DATE: 02/04/97 COMPLETED BY: DAVID T. JONES TELEPHONE: (412) 393-4962 i OPERATING STATUS

  • * * ** * * * * ** *** j
1. UNIT NAME: BEAVER VALLEY POWER STATION, UNIT 2
  • Notes *
2. REPORTING PERIOD: JhNUARY 1997 * *
3. LICENSED THERMAL POWER (MWt): 2652 *
  • l 4 NAMEPLATE RATING (Gross MWe): 923 *
  • 1
5. DESIGN ELECTRICAL RATING (Net MWe): 836 * *
6. MAX. DEPENDABLE CAPACITY (Gross MWe) : 870 * *
7. MAX. DEPENDABLE CAPACITY (Net MWe): 820 * * ** * * * * * * *** *
8. IF CHANGES OCCUR IN CAPACITY RATINGS SINCE LAST REPORT, GIVE REASONS: I l
9. POWER LEVEL TO WHICH RESTRICTED, IF ANY (Net MWe) : None 10, REASONS FOR RESTRICTIONS, IF ANY: N/A l

1 THIS MONTH YEAR TO DATE CUMULATIVE

11. HOURS IN REPORTING PERIOD: 744.0 744.0 80727.0 i
12. NO. OF HRS. REACTOR.WAS CRITICAL: 538.7 538.7 68259.7 l 13 REACTOR RESERVE SHUTDOWN HOURS: 0.0 0.0 0.0 '
14. HOUR!, GENERATOR WAS ON LINE: 520.8 520.8 67785.5
15. UNIT RESERVE SHUTDOWN HOURS: 0.0 0.0 0.0
16. GROS 3 THERMAL ENERGY GEN. (MWH): 1232795.0 1232795.0 168444638.0
17. GROSS ELECT. ENERGY GEN. (MWH): 405361.0 405361.0 54S01784.0
18. NET ELECTRICAL ENERGY GEN. (MWH): 377293.0 377293.0 51865889.0
19. UNIT SERVICE FACTOR: (PERCENT) 70.0 70.0 84.0
20. UNIT AVAILABILITY FACTOR: (PERCENT) 70.0 70.0 84.0
21. UNIT CAPACITY FACTOR (MDC) : PCT 61.8 61.8 78.0
22. UNIT CAPACITY FACTOR (DER) : PCT 60.7 60.7 76.9 2.1. UNIT FORCED OUTAGE RATE: (PERCENT) 30.0 30.0 4.7
24. SHUTDCWNS SCHEDULED OVER NEXT SIX MONTHS (TYPE,DATE,AND DURATION OF EACH):
25. IF SHUT DOWN AT END OF REPORT PERIOD, ESTIMATED DATE OF STARTUP:
26. UNITS IN TEST STATUS (PRIOR TO COMMERCIAL OPERATION):

FORECAST ACHIEVED l INITIAL CRITICALITY N/A N/A INITIAL ELECTRICITY ,,,_ N/A N/A COMMERCIAL OPERATION N/A N/A I

' UNIT S11UTDOWNS AND POWER REDUCTIONS (220%) Docket No. 50-412 .

Unit Name BVPS Unit #2 Date February 3,1997 Completed By David T. Jones REPORT MON'111 January 1997 Telephone (412)393-4 % 2 No. Date Typel Duration Reason 2 Method of Licensee System Component Cause & Corrective Action to Prevent (Hours) Shutting Event Report # Code 4 Code 5 Recurrence Down ,

Reactor 3 1 970106 F 112.9 A 3 2-97-001 EB RELAYX The Unit experienad a Reactor trip from approximately 98% output due to a Turbine Generator trip which was initiated by spurious operation of a Main Transformer Ground Protection Relay.

This relay protection was removed from service since it was only neentert to be in service for backfeed conditions only.

2 970110 F 91.0 H 9 2-97-002 SB PUMPXX Per Technical Specification require ,

ments, the Unit cooled down to mid shutdown conditions while missing / degraded flexible boot Ilood seals were installed on the four Recirculation Spray Pumps in accordance with the UFSAR and design basis.

3 970114 F 19.3 H 9 N/A ZZ 777777 The Unit remained shutdown to complete preparations for startup.

I 2 3 4 F-Forced Resenrc Meehnd; Exhibit F-imeructions for T., ~ -ofDean Emry S-Schechsled A-Eaquipment Failure (Explain) I-Manual Sheets for Imennee Evem Report (t.ER) File 83 Maintenance or Test 2-Manual Scram (NUREG016I).

C-Refueling 3-Automatic Saum D-Regulatory Restriction 4 Cont'd. frorn Previous Manch E-Operaanr Training & Lkense Exam 5-Redw13*m 5 F Adm.mestive 9-Other Exhibit II-Same Sourm G4Wr wt f.rror (Explain)

Il4hhcr(Eqdsen) i$

.' t UNIT SHIJII) OWNS AND POWER REDUCTIONS (220%) Docket No. 50-412 - l Unit Name BVPS Unit #2 Date February 3,1997 I Completed By David T. Jones REPORT MONDI january 1997 Telephone (412) 393-4 % 2 t No. Date Typel Duration Reason 2 Method of Licensee System Component Cause & Corrective Action to Prevent i (Hours) Shutting Event Report # Code 4 Code 5 Recurrence Down .

Reacter3 l

4 970115 F 0 F 9 N/A SB PUMPXX The Unit halted escalation to full powr at approximately 28% output to evaluate i sne impect on Beaver Valley of an .

industry event concerning a potential water hammer issue with the  !

Recirculation Spray System.

i I 2 3 4 F-Faced Reason: Meehad. Exhibit F-Instructions for Preparation of Des Entry S-Scheduled A-Equipe.ms Failure (Explain) 1-Masanal Sheets for licensee Event Report (LER) File B-Maineenance or Test 2-Mannel Scram (HUREG0161).

C-Refueld 3-Asstematic Scraan  ;

D-Regulaswy Restridion 40me'd freen Previous Mondi i E-Opersear Training A license Exarn 5-Redaction 5  ;

F-Ashnennerative 941.or Exhibit H-Same Seura 3 G-Operational Error (Explem) llaher(Explain) i i

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