ML20028D134

Monthly Operating Repts for Dec 1982

ML20028D134
Person / Time
Site:	Point Beach
Issue date:	01/15/1983
From:	Fay C WISCONSIN ELECTRIC POWER CO.
To:
Shared Package
ML20028D133	List: ML20028D132 ML20028D134
References
NUDOCS 8301170129
Download: ML20028D134 (10)

Text

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• E8 3,I. OPEHATING DATA REPORT

@j DOCKET NO. 50-266 o **

o DATE January 5, 1983

$0 oo COMPLETED Bf C. W. FAY O r*

' M a* TELEPHONE 414 277 2811 E$ OPERATING STATUS

1. UNIT NAME: POINT BEACH NUCLEAR PLANT UNIT 1 . NOTES .

2. REPORTING PERIOD: DECEnBER 1982 . .

3. LICENSED THERMAL POWER (MWT): 1518. . .

4. NAMEPLATE RATING (GROSS MWE): 523.8 . .

5. DESIGN ELECTRICAL RATING (NET nWE): 497. . .

6. MAXIMUM DEPENDABLE CAPACITY (GROSS MWE): 519. . .

7. MAXIMUM DEPENDABLE CAPACITY (NET MWE): 495. .. ......................

8. IF CHANGES DCCUR IN CAPACITY RATINGS (ITEMS NUMBER 3 THROUGH 7) SINCE LAST REPORT, GIVE REASONS:

NOT APPLICABLE

9. POWER LEVEL TO WHICH RESTRICTED, IF ANT (NET MUE): 390.0

10. REASONS FOR RESTRICTIONS, (IF ANf): Power level restricted because of self-imposed hot leg temperature limitation in an attempt to limit steam generator tube corrosion.

THIS MONTH YR TO DATE CUMULATIVE

11. HOURS IN REPORTING PERIOD 744 8,760 106,536

12. NUMBER OF HOURS REACTOR WAS CRITICAL 576.7 7,219.1 87,572.3

13. REACTOR RESERVE SHUTDOWN HOURS 5.3 16.7 624.0

14. HOURS GENERATOR ON LINE 534.0 7,136.1 85,108.3

15. UNIT RESERVE SHUTDOWN HOURS 1.8 29.2 793.5

16. GROSS THERMAL ENERGY GENERATED (MWH) 600,074 8,596,149 115,948,989

17. GROSS ELECTRICAL ENERGY GENERATED (MWH) 178,360 2.854,510 38,875,790

18. NET ELECTRICAL ENERGY CENERATED (MWH) 186,047 2,700,507 36,981,718

19. UNIT SERVICE FACTOR 71.8 81.5 79.9

20. UNIT AVAILABILITY FACTOR 72.0 81.8 80.6

21. UNIT CAPACITY FACTOR (USING hDC NET) 50.5 62.3 71.1

22. UNIT CAPACITY FACTOR (USING DER NET) 50.3 62.0 69.8

23. UNIT FORCED OUTAGE RATE 0.0 0.2 2.8

24. SHUIDOWNS SCHEDULED OVER NEXT 6 MONTHS (TYPE, DATE, AND DURATION OF EACH):

NONE

25. IF SHUTDOWN AT END OF REPORT PERIOD, ESTIMATED DATE OF STARTUP: NOT SHUTDOWN DATA REPORTED AND FACTORS CALCULATED AS REQUESTED IN NRC LETTER DATED SEPTEMBER 22, 1977

UNIT SHUTDOWNS AND POWER REDUCTIONS DOCKET NO. 50-266 -

UNIT NAME Point Beach Unit 1 DATE January 5, 1983 REPORT MONTH December, 1982 COMPLETED BY C. W. Fay TELEPHONE 414/277-2811

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u C M En o S o

as au "co 5t

'o a m Po D 'o En ao No. Date g mg g jjg Licensea Event Report No.

y g'g Cause and Corrective Action To Prevent Recurrence e c= m oa m Eo Q~  % o v) C o s: > u o

5 821022 S 207.3 C 1 N/A ZZ ZZZZZ2 Returned to power following com-pletion of refueling outage.

6 821209 F 2.1 G 3 N/A HB ZZZZZZ Reactor trip from 20 MWe due to a low-low trip signal.

7 821210 S 0.6 B 4 N/A ZZ ZZZZZZ Unit removed from service for off-line turbine testing.

l F: Forced Reason: 3 4 Method: '

Exhibit G-Instruc-i S: Scheduled A- Equipment Failure (explain) 1- Manual tions for Prepar-B- Maintenance or Test 2- Manual Scram ation of Data Entry -

C- Refueling 3- Automatic Scram Sheets for LER File D- Regulatory Restriction 4- Other (explain) (NUREG-0161)

E- Operator Training & License Exam F- Administrative 5 AD-28B Exhibit I- Same G- Operational Error (explain) Source (01-78) H- Other (explain)

DOCKET NO. 50-266 UNIT NAME Point Beach Unit 1 DATE January 5, 1983 COMPLETED BY C. W. Fay TELEPHONE 414/277-2811 ,

AVERAGE DAILY UNIT POWER LEVEL MONTH December, 1982 l

AVERAGE AVERAGE AVERAGE DAILY DAILY DAILY POWER LEVEL POWER LEVEL POWER LEVEL DAY MWe NET DAY MWe NET DAY MWe NET 1 -2 11 364 21 372 2 -2 12 364 22 372 3 -8 13 371 23 374 4 -8 14 372 24 372 5 -9 15 372 25 366 6 -9 16 372 26 302 7 -11 17 372 27 326 8 -13 18 367 28 336

. 9 11 19 366 29 354 10 173 20 372 30 372 31 372 i

AD-28A (1-77)

NARRATIVE

SUMMARY

OF OPERATING EXPERIENCE Docket No. 50-266 Unit Name Point Beach Unit 1 Date January 5, 1983 Completed By C. W. Fay Telephone 414/277-2811 gs' Unit 1 completed its tenth refueling outage during the reporting period.

On December 3, cold rod drop tests were completed, along with accumulator pressure and loop reactor temperature detection calibrations, and heatup of the primary coolant system commenced. Three~ cycles of steam generator crevice flushing were completed on December 3 and 4. On December 6, a bubble was drawn in the pressurizer. On December 7, after completion of the hot rod drop tests, the reactor was taken critical at 2112 hours0.0244 days <br />0.587 hours <br />0.00349 weeks <br />8.03616e-4 months <br />.

On December 9, at 1014 hours0.0117 days <br />0.282 hours <br />0.00168 weeks <br />3.85827e-4 months <br /> with the unit at 5%

power, Unit 1 experienced a reactor trip due to a low-low steam generator level from "A" steam generator. The level was the result of the feed regulator bypass valve HCV-480 remaining closed following a steam generator level increase. Although this event was not considered LER reportable, the NRC Resident Inspector was notified, as well as red phone notification.

i At 1220 hours0.0141 days <br />0.339 hours <br />0.00202 weeks <br />4.6421e-4 months <br /> the reactor was again taken critical and at 1724 hours0.02 days <br />0.479 hours <br />0.00285 weeks <br />6.55982e-4 months <br /> the generator was chased on line.

On December 10 at 1258 hours0.0146 days <br />0.349 hours <br />0.00208 weeks <br />4.78669e-4 months <br />, the generator was taken off line to complete the turbine overspeed trip tests (ORT #4).

At 0335 hours0.00388 days <br />0.0931 hours <br />5.539021e-4 weeks <br />1.274675e-4 months <br /> the generator was phased on line after the completion of the testing.

4 The unit operated at approximately 370 MWe net with no shutdowns or power reductions for the remainder of the period.

The primary-to-secondary leakage in the steam generators is less than ten gallons per day.

i

Following the replacement of Westinghouse NBFD relay coils in the reactor protection racks, as recommended by the manufacturer, one relay dropout time was found to be excessive upon being deenergized. Further testing on December 4 indicated

' that one additional relay had excessive dropout time when deenercized.

The previously unobserved failure mechanism causes the normally energized relays to remain in the energized positions longer i

l l

than designed after the removal of power. This nonconservative mode of failure was unacceptable and efforts have been directed to replacing the reworked coils with the previous model.

Inspection of the failed coils indicated that what appeared to be the coil filler epoxy had leaked into the plunger cavity. This epoxy would then inhibit plunger movement to the extent that the relay could become sluggish or fixed in the energized position. These defective replacement coils can be used on NBFD-type relays. Preliminary conversations with the manufacturer indicate that this could be linked to a batch manufacturing problem.

This event constitutes a reportable occurrence per Technical Specification 15.6.9.2.A.9 and the Resident Inspector has been notified. This event also is reportable under 10 CFR 21.

On December 11 at 2240 hours0.0259 days <br />0.622 hours <br />0.0037 weeks <br />8.5232e-4 months <br />, "A" steam generator pressure transmitter 1PI-469 instrument line began showing signs of freezing. The channel was put in the trip condition to facilitate a minimum degree of redundancy. Maintenance personnel were called to the site and were able to thaw out the instrument line as the other two channels were inspected. The transmitter line freeze-up was attributed to a failure of the temporary heat tracing on the pressure transmitter sensing lines. The loss of the transmitter channel is a reportable event per Technical Specification 15.6.9.2.B.2 and a 30-day Licensee Event Report will be filed with the NRC.

On December 13 while evaluating data, Reactor Engineering discovered a setpoint error in the Unit 1 computer program which alarms control rod misalignment. The computer and the program were operable; however, the incorrect setpoint would cause an inaccurate alarm. The program was corrected and a 30-day Licensee Event Report will be filed with the NRC.

On December 15 at 1308 hours0.0151 days <br />0.363 hours <br />0.00216 weeks <br />4.97694e-4 months <br /> during fire system surveillance testing, the fire detection system for the Unit 1 rod drive room was found inoperable. Hourly surveillance of the area was instituted per Technical Specification pending the repair of the system. A 30-day Licensee Event Report will be filed with the NRC.

On December 17 at 1210 hours0.014 days <br />0.336 hours <br />0.002 weeks <br />4.60405e-4 months <br />, it was discovered that the "A" main steam line hydraulic snubber on top of the Unit 1 "A" steam generator missile shield had a leaking shaft seal.

Although the hydraulic oil system was drained to the elevation of the snubber, the lateral seismic hydraulic snubber system maintained a 13.5 psig pressure head. Maintenance repaired the leaking seal and restored the system at 1312 hours0.0152 days <br />0.364 hours <br />0.00217 weeks <br />4.99216e-4 months <br /> on December 19.

A 30-day Licensee Event Report will be filed with the NRC.

On December 5, a severed tube in the "A" component cooling heat exchanger caused an estimated loss of 1260 gallons of component cooling water to the service water system and eventually to the circulating water system. This event was not considered reportable.

Also on December 17, a minor body-to-bonnet steam leak was discovered on Unit 1 pressurizer control valve 1PCV-431B.

This valve controls spray flow from the reactor coolant system to the pressurizer. "Furmanite" contractor personnel were called to the site and were able to stop the leak, however, surveillance i'

of the valve is continuing. This event was not considered reportable.

On December 28 approximately 300 gallons of radioactive fluid spilled when boron concentrations in the mixed bed demineralizer were being equalized with the primary system prior to putting the domineralizer on line. The mixed bed tank drained through the sump tank to the waste tank. The sump tank level indicator was being calibrated by Instrument and Control. During the calibration process, the fluid spilled to El. -19 feet sump which pumped it to the waste holdup tank. The radioactive release was 99.7% noble gas and amounted to less than 1% of Point Beach Nuclear Plant 15-minute allowable Technical Specification limit.

The NRC Resident Inspector was notified, as was the Region III offer per red phone, however, the event is not reportable per the Licensee Event Report format.

Other work completed during the period included repair of the valve operator for "A" steam generator blowdown isolation valve 1-2042, seal replacement of the Unit 1 charging pumps, modifications to the auxiliary feedwater actuation logic test circuit, and repairs to th( 1XY01 instrument transformer for the P-250 computer.

OPERATING DATA REPORT DOCMET NO. 50-301 DATE January 5, 1983 COMPLETED BY C. W. FAY TELEPHONE 414 277 2811 OPERATING STATUS

1. UNIT NAME: POINT BEACH NUCLEAR PLANT UNIT 2 . NOTES .

2. REPORTING PERIOD: DECEMBER 1982 . .

3. LICENSED THERnAL POWER (MUT): 1518. . .

4. NAMEPLATE RATING (GROSS nWE): 523.8 . .

5. DESIGN ELECTRICAL RATING (NET MUE): 497. . .

6. MAXIMUM DEPENDABLE CAPACITY (GROSS MUE): 519. . .

7. MAXIMUM DEPENDABLE CAPACITY (NET MUE): 495. ........................

8. IF CHANGES OCCUR IN CAPACITY RATINGS (ITEMS NUMBER 3 THROUGH 7) SINCE LAST REPORT, GIVE REASONS:

NOT APPLICABLE

9. POWER LEVEL TO WHICH RESTRICTED, IF ANY (NET nWE): HOT APPLICABLE

10. REASONS FOR RESTRICTIONS, (IF ANY): NOT APPLICABLE THIS MONTH YR TO DATE CUMULATIVE

11. HOURS IN REPORTING PERIOD 744 8,760 91,321

12. NUMBER OF HOURS REACTOR UAS CRITICAL 744.0 7,667.7 82,058.1

13. REACTOR RESERVE SHUTDOWN HOURS 0.0 3.8 196.8

14. HOURS GENERATOR ON LINE 744.0 7,596.6 80,655.2

15. UNIT RESERVE SHUTDOWN HOURS 0.0 3.2 181.2

16. GROSS THERMAL ENERGY GENERATED (MWH) 1,109,078 11,258,750 111,515,594

17. GROSS ELECTRICAL ENERGY GENERATED (MUH) 371,920 3,778,390 37,801,400

18. NET ELECTRICAL ENERGY GENERATED (MWH) 356,151 3,605,501 35,988,967

19. UNIT SERVICE FACTOR 100.0 86.7 88.3

20. UNIT AVAILABILITY FACTOR 100.0 86.8 88.5

21. UNIT CAPACITY FACTOR (USING MDC NET) 96.7 83.1 80.2

22. UNIT CAPACITY FACTOR (USING DER NET) 96.3 82.8 79.3

23. UNIT FORCED OUTAGE RATE 0.0 0.0 1.5

24. SHUTDOUNS SCHEDULED OVER NEXT 6 MONTHS (TYPE, DATE, AND DURATION OF EACH):

Eleven week refueling and steam generator sleeving outage scheduled to begin March 25, 1983.

25. IF SHUIDOWN AT END OF REPORT PERIOD, ESTIMATED DATE OF STARTUP: NOT SHUIDOUN DATA REPORTED AND FACTORS CALCULATED AS REQUESTED IN NRC LETTER DATED SEPTENBER 22, 1977

DOCKET NOo 50-301 UNIT NAME Point Beach Unit 2 DATE January 5, 1983 i

COMPLETED BY C. W. Fav TELEPHONE 414/277-2811 AVERAGE DAILY UNIT POWER LEVEL MONTH December. 1982 AVERAGE AVERAGE AVERAGE DAILY DAILY DAILY POWER LEVEL POWER LEVEL POWER LEVEL DAY MWe NET DAY MWe NET DAY MWe NET 1 486 11 487 21 485 2 489 12 448 22 486 3 487 13 481 23 487 4 487 14 488 24 487 5 486 15 460 25 454 6 487 16 475 26 479 7 485 17 _,

479 27 487 8 486 18 487 28 452 9 487 19 446 29 481 10 4g7 20 453 30 482 31 487 AD-28A (1-77)

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NARRATIVE

SUMMARY

OF OPERATING EXPERIENCE Docket No. 50-301 Unit Name Point Beach Unit 2 Date January 5, 1983 Completed By C. W. Fay Telephone 414/277-2811 Unit 2 operated at approximately 487 MWe net throughout the period with no major load reductions.

The primary-to-secondary leakage remains at less than ten gallons per day.

On December 12 at 1238 hours0.0143 days <br />0.344 hours <br />0.00205 weeks <br />4.71059e-4 months <br />, steam generator pressure transmitter 2PI-482 exhibited signs of freeze-up. The channel was put in the trip condition to facilitate a degree of redundancy.

Maintenance personnel were called to the site to thaw out the line. The remaining two channels were inspected.and were satis-factory. The transmitter line freeze-up was attributed to a failure of the temporary heat tracing on the pressure transmitter sensing lines. In addition, it was discovered that heat trace recorder charts would not respond to actual changes in the sensing line of the steam generator pressure transmitters. The loss of the transmitter channel is a reportable event per Technical Specification 15.6.9.2.B.2 and a 30-day Licensee Event Report will be filed with the NRC.

Other safety-related maintenance included the inspection of the Unit 2 snubbers.