L-99-038, Monthly Operating Repts for Feb 1999 for Bvps,Units 1 & 2. with

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Monthly Operating Repts for Feb 1999 for Bvps,Units 1 & 2. with
ML20207K595
Person / Time
Site: Beaver Valley
Issue date: 02/28/1999
From: David Jones, Ostrowski K
DUQUESNE LIGHT CO.
To:
NRC OFFICE OF INFORMATION RESOURCES MANAGEMENT (IRM)
References
GL-97-02, GL-97-2, L-99-038, L-99-38, NUDOCS 9903170234
Download: ML20207K595 (7)
v • d • e


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'At5 Telephone (412) 3916000 Nuclear Group L-99-038 Shippingport, PA 15077-0004 March 5,1999 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 Operating Report U. S. Nuclear Regulatory Commission Document Control Desk Wa .hington, DC 20555 Gentlemen:

In accordance with NRC Generic Letter 97-02, " Revised Contents of the Monthly Operating Report", and Unit 1 and 2 Technical Specification 6.9.1.6, the " Monthly Operating Report" is submitted for Unit 1 and Unit 2 for the month of February,1999.

Respectfully,  ;

i h$.Ww$

K. L. Ostrowski j Division Vice President, i Nuclear Operations Group l and Plant Manager DTJ/ sip  !

Enclosures cc: NRC Regional Office King ofPrussia, PA i

The Nuclear Professionals 9903170234 990228 3 PDR ADOCK 05000334 R PDR 3

, .' UNIT SHUTDOWNS DOCKET NO. 50-334 UNIT NAME BVPS Unit #1 DATE March 2,1999 COMPLETED BY David T. Jones TELEPHONE (412) 393-4962 REPORTING PERIOD: February 1999 No. Date Type Duration Reason Method of Cause / Corrective Actions F: Forced (Hours) (1) Shutting S: scheduled Down (2) Comments 2 990214 F 36.3 A 1 The Unit was removed from service due to unacceptable secondary system chemistry levels caused by a tube leak in the "C" Waterbox of the Main Unit Condenser.

One tube required plugging.

3 990216 F 198.1 A 4 Startup from the forced outage discussed above was delayed when four Condenser Steam Dump Valves failed to open due to wear in their balance chambers. All four Condenser Steam Dump Valves were repaired and tested satisfactorily.

4 990224 F 12.4 A 4 Startup from the forced outage discussed above was delayed to investigate a I possible tube / tube sheet leak in the "C" I I

Waterbox of the Main Unit Condenser. No leak was detected and the air in-leakage I problem corrected itself upon establishing circulating water system flow through the "C" Waterbox, as verified by improving secondary system chemistry conditions.

5 990225 F 13.7 A 4 Startup from the forced outage discussed above was delayed when the Turbine was manually tripped to prevent an overspeed condition (prior to synchronization). This was done when the Turbine Main Speed Channel circuit failed to actuate due to a failed speed proximity sensor. A spare speed proximity sensor was connected in the circuit prior to re-initiating turbine roll.

I (1) Reason (2) Method A Equipment Failure (Explain) 1. Manual B Maintenance or Test 2. Manual Trip / Scram C - Refueling 3. Automatic Trip / Scram D - Regulatory Restriction 4 - Continuation E - Operator Training / Ucense Examination 5 Other(Explain)

F - Administrative G. Operational Error (Explain)

H Other(Explain)

,. . UNIT SHUTDOWNS DOCKET NO. 50-334 UNIT NAME BVPS Unit #1 DATE March 2,1999 COMPLETED BY David T. Jones TELEPHONE (412) 393-4962 REPORTING PERIOD: February 1999

SUMMARY

- The Unit began the report period operating at approximately 34% output to support cleaning of the Main Unit Condenser. From 2/1/99 until 1800 hours0.0208 days <br />0.5 hours <br />0.00298 weeks <br />6.849e-4 months <br /> on 2/12/99, output was increased and decrease as Condenser parameters permitted while cleaning of the Main Unit Condenser continued. With the Unit operating at a nominal value of 100% output, cleaning of the Main Unit Condenser was completed on 2/13/99.

The Unit continued to operate at a nominal value of 100% output until 1149 hours0.0133 days <br />0.319 hours <br />0.0019 weeks <br />4.371945e-4 months <br /> on 2/14/99, when a power reduction to less than 30% output was commenced due to a sharp increase in the secondary system chemistry levels indicating a possible tube leak in the Main Unit Condenser. Due to unacceptable secondary system chemistry levels in the Steam Generators, the Unit commenced a further power reduction at 1850 hours0.0214 days <br />0.514 hours <br />0.00306 weeks <br />7.03925e-4 months <br /> on 2/14/99, in' preparation for removing the Unit from service. The Unit was taken off-line at 1941 hours0.0225 days <br />0.539 hours <br />0.00321 weeks <br />7.385505e-4 months <br /> on 2/14/99. Mode 2 was entered at 2015 hours0.0233 days <br />0.56 hours <br />0.00333 weeks <br />7.667075e-4 months <br /> and Mode 3 was entered at 2046 hours0.0237 days <br />0.568 hours <br />0.00338 weeks <br />7.78503e-4 months <br /> on 2/14/99. One tube in the "C" Waterbox of the Main Unit Condenser required plugging. Upon achieving acceptable secondary system chemistry levels in the Steam Generators for power ascension to 30% output, Reactor startup was commenced on 2/16/99. Mode 2 was entered at 0509 hours0.00589 days <br />0.141 hours <br />8.416005e-4 weeks <br />1.936745e-4 months <br /> and the Reactor was taken critical at 0628 hours0.00727 days <br />0.174 hours <br />0.00104 weeks <br />2.38954e-4 months <br /> on 2/16/99.

At 0757 hours0.00876 days <br />0.21 hours <br />0.00125 weeks <br />2.880385e-4 months <br /> on 2/16/99, startup was placed on hold due to four Condenser Steam Dump

~ Valves failing to open. The Reactor was shutdown and Mode 3 was entered at 0857 hours0.00992 days <br />0.238 hours <br />0.00142 weeks <br />3.260885e-4 months <br /> on 2/16/99. Upon completion of repairing and testing the Condenser Steam Dump Valves, Reactor startup was commenced on 2/24/99. Mode 2 was entered at 0324 hours0.00375 days <br />0.09 hours <br />5.357143e-4 weeks <br />1.23282e-4 months <br /> and the Reactor was taken critical at 0436 hours0.00505 days <br />0.121 hours <br />7.208995e-4 weeks <br />1.65898e-4 months <br /> on 2/24/99. Mode 1 was entered at 0553 hours0.0064 days <br />0.154 hours <br />9.143518e-4 weeks <br />2.104165e-4 months <br /> on 2/24/99 and Reactor power was stabilized at approximately 12% output.

I Due to degrading secondary system chemistry levels indicating possible tube / tube sheet leakage in the "C" Waterbox of the Main Unit Condenser, a reduction of Reactor power was commenced at 1400 hours0.0162 days <br />0.389 hours <br />0.00231 weeks <br />5.327e-4 months <br /> on 2/24/99. Mode 2 was entered at 1429 hours0.0165 days <br />0.397 hours <br />0.00236 weeks <br />5.437345e-4 months <br /> and Reactor ,

power was stabilized at approximately 2% output at 1448 hours0.0168 days <br />0.402 hours <br />0.00239 weeks <br />5.50964e-4 months <br /> on 2/24/99. No tube or tube  !

sheet leakage was detected, and the air in-leakage problem corrected itself upon establishing circulating water system flow through the "C" Waterbox, as verified by improving secondary system chemistry conditions.

Power escalation was begun at 2400 hours0.0278 days <br />0.667 hours <br />0.00397 weeks <br />9.132e-4 months <br /> on 2/24/99. Mode 1 was entered at 0005 hours5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br /> on 2/25/99. While at approximately 15% Reactor output, the Turbine was manually tripped at 0225 hours0.0026 days <br />0.0625 hours <br />3.720238e-4 weeks <br />8.56125e-5 months <br /> on 2/25/99 due to a failure of the Turbine Main Speed Channel circuit. Upon I repair of the Turbine Main Speed Channel circuit, Turbine roll was successfully commencec at I 1329 hours0.0154 days <br />0.369 hours <br />0.0022 weeks <br />5.056845e-4 months <br /> on 2/25/99. The Unit was synchronized to the electrical grid at 1609 hours0.0186 days <br />0.447 hours <br />0.00266 weeks <br />6.122245e-4 months <br /> on i

UNIT SHUTDOWNS {

l DOCKET NO. 50-334 UNIT NAME BVPS Uriit #1 DATE March 2,1999 i COMPLETED BY David T. Jones ~~

TELEPHONE (412) 393-4962 I REPORTING PERIOD: February 1999

SUMMARY

(continued):

2/25/99 and output was escalated to approximately 30%. Upon achieving acceptable chemistry levels in the Steam Generators, power escalation was commenced at 0748 hours0.00866 days <br />0.208 hours <br />0.00124 weeks <br />2.84614e-4 months <br /> f j

on 2/26/99. '

At 0935 hours0.0108 days <br />0.26 hours <br />0.00155 weeks <br />3.557675e-4 months <br /> on 2/26/99, powor escalation was placed on hold at approximate:y 35% output f

te evaluate a possible stem / plug separation on the 1A/1C Moisture Separator Reheater Supply Valve which prohibits placing the Moisture Separator Reheaters (MSR's) in service.

Pewer . escalation was resumed at 1400 hours0.0162 days <br />0.389 hours <br />0.00231 weeks <br />5.327e-4 months <br /> on 2/26/99. A maximum output of appoximately 96% was achieved at 0307 hours0.00355 days <br />0.0853 hours <br />5.076058e-4 weeks <br />1.168135e-4 months <br /> on 2/27/99 due to the out of service MSR's while repair of the 1A/1C Moisture Separator Reheater. Supply Valve continued.. The Unit continued to operate at approximately 96% output for the remainder of the report period.'

4 In addition to the above, the foibwing events which also occurred during the report period are being reported as required by Technical Specification 3.1.3.2, Note (3).

On 2/3/99 at 2211 hours0.0256 days <br />0.614 hours <br />0.00366 weeks <br />8.412855e-4 months <br />, the Analog Rod Position Indication (ARPI) for Control Rod K-6 read greater than the Technical Specification limit of 12 steps. At 2232 hours0.0258 days <br />0.62 hours <br />0.00369 weeks <br />8.49276e-4 months <br />, the ARPI for Control Rod K-6 returned to within the 12 step limit and was declared operable.

On 2/8/99 at 1953 hours0.0226 days <br />0.543 hours <br />0.00323 weeks <br />7.431165e-4 months <br />, the Analog Rod Position Indication (ARPI) for Control Rod H-2 read greater than the Technical Specification limit of 12 steps. At 2010 hours0.0233 days <br />0.558 hours <br />0.00332 weeks <br />7.64805e-4 months <br />, the ARPI for Control Rod H-2 returned to within the 12 step limit and was declared operable.

On 2/1499 at 1230 hours0.0142 days <br />0.342 hours <br />0.00203 weeks <br />4.68015e-4 months <br />, the Analog Rod Position Indication (ARPI) for Control Rod H-2 read greater than the Technical Specification limit of 12 steps. At 1238 hours0.0143 days <br />0.344 hours <br />0.00205 weeks <br />4.71059e-4 months <br />, the ARPl for Control Rod H-2 retumed to within the 12 step limit and was declared operable.

r --

J OPERATING DATA REPORT l

DOCKET NO. 50-334 UNIT NAME: BVPS UNIT #1 REPORT CATE: 03/03/99 COMPLETED BY: DAVID T. JONES TELEPHONE: (412) 393-4962 la. REPORTING PERIOD: FEBRUARY 1999 *

[ Notes

1. DESIGN ELECTRICAL RATING (Net Mwe): 835 . [
2. MAX. DEPENDABLE CAPACITY (Net Mwe): 810 .....,,.........

THIS MONTH YEAR TO DATE CUMULATIVE 3a. HOURS IN REPORTING PERIOD: 672.0 1416.0 200136.0

3. NO. OF HRS. REACTOR WAS CRITICAL: 450.7 1152.2 13043'2.2
4. SERVICE HOURS GENERATOR ON LINE: 411.5 1097.3 128129.0
5. UNIT RESERVE SHUTDOWN HOURS: 0.0 0.0 0.0
6. NET ELECTRICAL ENERGY GEN. (MWH): 304392.0 828189.0 94514081.0
7. GROSS ELECT. ENERGY GEN. (MWH): 330302.0 888149.0 101054924.0
8. GROSS THERMAL ENERGY GEN. (MWH): 1019933.0 2729907.0 312199684.5
9. UNIT AVAILABILITY FACTOR (%): 61.2 77.5 65.5
10. UNIT CAPACITY FACTOR (MDC) (%): 55.9 72.2 60.3
11. UNIT FORCED OUTAGE RATE (%): 38.8 22.5 18.4

)

[

E j

, l UNIT SHUTDOWNS DOCKET NO. 50-412 UNIT NAME BVPS Unit #2 DATE March 2,1999 ,

COMPLETED BY David T. Jones i TELEPHONE (412) 393-4962 REPORTING PERIOD: February 1999 l l

No. Date Type Duration Reason $

Method of Cause / Corrective Actions j F: Forced (Hours) (1) Shutting s: scheduied Down (2) Comments 1 990226 S 50.0 C 1 The Unit shutdown for its seventh refueling outage (2R7).

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)

(1) Reason (2) Method A Equipment Failure (Explain) 1 - Manual B Maintenance or Test 2 - Manual Trip / Scram .

C Refueling 3 Automatic Trip / Scram D Regulatory Restriction 4 - Continuation E operator Training / License Examination 5 Other(Explain)

F - Adrninistrative G operationalError(Explain)

H Other(Explain)

SUMMARY

The Unit had reduced output to approximately 95% on 1/31/99 to remove the "A" First Point Heater from service in order to support required repairs to the 21 A First Point Heater Normal Level Control Valve due to stem / plug separation. Following removal of the "A" First Point l Heater from service, small incremental power escalations were performed with a nominal value of 100% reactor output achieved at 1000 hours0.0116 days <br />0.278 hours <br />0.00165 weeks <br />3.805e-4 months <br /> on 2/1/99.

The Unit continued to operate at a nominal value of 100% output until 1420 hours0.0164 days <br />0.394 hours <br />0.00235 weeks <br />5.4031e-4 months <br /> on 2/26/99, when a planned reduction was commenced in preparation for the Unit's seventh refueling outage. The Unit was taken off-line at 2159 hours0.025 days <br />0.6 hours <br />0.00357 weeks <br />8.214995e-4 months <br /> on 2/26/99. Mode 2 was entered at 2314 hours0.0268 days <br />0.643 hours <br />0.00383 weeks <br />8.80477e-4 months <br /> and Mode 3 was' entered at 2348 hours0.0272 days <br />0.652 hours <br />0.00388 weeks <br />8.93414e-4 months <br /> on 2/26/99. The Unit continued to cool down and entered Mode 4 at 1631 hours0.0189 days <br />0.453 hours <br />0.0027 weeks <br />6.205955e-4 months <br /> on 2/27/99. Mode 5 was entered at 0058 hours6.712963e-4 days <br />0.0161 hours <br />9.589947e-5 weeks <br />2.2069e-5 months <br /> on 2/28/99. The Unit remained in Mode 5 (cold shutdown) through the end of the report period while the planned seventh refueling outage continued.

,g

  • i CPERATING DATA REPORT e ,

-i l

DOCKET NO.: 50-412 UNIT NAME' BVPS UNIT #2 REPORT DATE: 03/03/99 COMPLETED BY: DAVID T. JONES TELEPHONE: (412) 393-4962 la. REPORTING PERIOD: FEBRUARY 1999

  • Notes *
1. DESIGN ELECTRICAL RATING (Net Mwe): 836 [
2. MAX. DEPENDABLE CAPACITY (Net Mwe): 820 ................

1

-i THIS MONTH YEAR TO DATE CUMULATIVE 3a. HOURS IN REPORTING PERIOD: 672.0 1416.0 98919.0 i

3. NO. OF HRS. REACTOR MAS CRITICAL: 623.8 1367.8 78964.1

-I

4. SERVICE HOURS GENERATOR ON LINE: 622.0 1366.0 78395.1
5. UNIT RESERVE SHUTDOWN HOURS: 0.0 0.0 0.0 6 NET ELECTRICAL ENERGY GEN. (MWH): 516773.0 1139220.0 60539802.0 7 -GROSS ELECT. ENERGY GEN. (MWH): 544659.0 1199202.0 64056154.0 1
8. GROSS THERMAL ENERGY GEN. (MWH): 1632969.0 3596006.0 196100761.0
9. UNIT AVAILABILITY FACTOR (%): 92.6 96.5 '79.3
10. UNIT CAPACITY FACTOR (MDC) (%): 93.8 98.1 74.4
11. UNIT FORCED OUTAGE RATE (t): 0.0 0.0 12.2 I

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