ML20039G481

Monthly Operating Rept for Dec 1981

ML20039G481
Person / Time
Site:	Point Beach
Issue date:	01/06/1982
From:	Fay C WISCONSIN ELECTRIC POWER CO.
To:
Shared Package
ML20039G476	List: ML20039G475 ML20039G481
References
NUDOCS 8201180298
Download: ML20039G481 (6)

Text

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arum OPERATING DATA REPORT gy DOCKET NO. 50-266

$ Dale January 6, 1982 00 x.o COMPLETED BY C. W. FAY O

g$, TELEPHUNE 414 277 2811 oo OPERATING STATUS mO" - ........................

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

2. REPORTING PERIOD: DECEMBER 1981 . .

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

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

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

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

7. HAXIMUM 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 P0HER LEVEL TO WHICH RESTRICTED, IF ANT (NET MWE): 445.0

10. REASONS FOR RESTRICTIONS, (IF ANY): Maximum dependable capacity reduced 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 97,776

12. NUMBER GF HOURS REACTOR WAS CRITICAL 514.1 6,882.6 80,317.4

13. REACTOR RESERVE SHUTDOWN HOURS 0.3 1.6 607.3

14. HOURS GENERATOR ON LINE 472.4 6,811.2 77,948.1

13. UNIT RESERVE SHt'TDOWN HOURS 0.0 0.0 764.3

16. GROSS THERMAL ENERGY GENERATED (MWH) 601,995 8,514,396 107,352,840

17. GROSS ELECTRICAL ENERGY GENERATED iMUH) 197,800 2,761,560 36,021,280

18. NET ELECTRICAL ENERGY GENERATED (MWH) 185,779 2,613,925 34,281,211

19. UNIT SERVICE FACTOR 63.5 77.8 79.7

20. UNIT AVAILABILITY FACTOR 63.5 77.R 80.5

21. UNIT CAPACITY FACTOR (USING MDC NET) 50.4 60.3 71.9

22. UNIT CAPACITY FACTOR (USING DER NET) 50.2 60,0 70.5

23. UNIT FORCED OUTAGE RATE 0.0 0.2 3.0

24. SHUTD0UNS 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

DOCKET NO. 50-266 UNIT NAME Point Beach Unit 1 .

DATE January 6, 1982 COMPLETED BY C. W. Fay TELEPHONE 414/277-2811 AVERAGE DAILY UNIT POWER LEVEL MONTH December, 1981 AVERAGE AVERAGE AVERAGE DAILY DAILY DAILY

- POWER LEVEL POWER LEVEL POWER LEVEL DAY MWe NET DAY MWe NET DAY MWe NET-1 -2 11 22 21 415 2 -1 12 97 22 __

416 3 .-6 13 319- 23 417 4 -9 14 351 24 __

419 5 -10 15 414 25 393 6 -8 16 392 26 403 7 -11 17 391 27 417 8 -13 18 416 28 417 9 -13 19 414 29 416 10 33 20 415 30 418 31 418 AD-28A (1-77)

UNIT SHUTDOWNS AND POWER REDUCTIONS DOCKET NO. 50-266 UNIT NAME Point Beach Uni ~t 1 REPORT MONTH December, 1981 a COMPLETED BY C J TELEPHONE 414/277-2811 l

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'o o as Ve vc en ce No. Date g gg y jjy Licensee Event gg g'g Cause and Corrective Action e om o a sc Report No. m Eu To Prevent Recurrence l a- M ymG g 8

5 811009 S 1501.5 C 1 N/A ZZ ZZZZZ2 Returned to power following com-pletion of refueling outage.

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1 3 F: Forced Reason: Method: Exhibit G-Instruc-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 5

F- Administrative Exhibit I- Same AD-28B G- Operational Error (explain) Source (01-78) H- Other (explain)

NARRATIVE

SUMMARY

OF OPERATING EXPERIENCE Docket No. 50-266 Unit Name Point Beach Unit 1 Date January 6, 1982 Completed By C. W. Fay Telephone 414/277-2811 Unit 1 remained-in shut-down condition as the ninth refueling outage progressed. Preparations for initial criticality were interrupted at 1833 hours0.0212 days <br />0.509 hours <br />0.00303 weeks <br />6.974565e-4 months <br /> on December 2, 1981 when the supply breaker from 1A03 and 1A05 opened due to undervoltage caused by the voltage dip during a reactor coolant pump start-up. These TMI backfit relays were-set with a time delay of 13.5 seconds at 90% voltage (Technical Specification number), however, the pump start time to bus voltage recovery is about 18 seconds and thus these relays timed out and caused the trip of 1A52-57 breaker. During this event, the 3D diesel generator started and assumed the 1A05 loads. At 1922 hours0.0222 days <br />0.534 hours <br />0.00318 weeks <br />7.31321e-4 months <br /> a call was made to the NRC via the red phone. The situation was returned to normal by 1932 hours0.0224 days <br />0.537 hours <br />0.00319 weeks <br />7.35126e-4 months <br />. The time delay on these relays was increased to 20 seconds and successful pump start at 1935 hours0.0224 days <br />0.538 hours <br />0.0032 weeks <br />7.362675e-4 months <br /> verified these settings. This reset was given NRC concurrence to be set at any value less than 60 seconds on December 3.

Progress to start-up continued with the setting of containment integrity on December 4 at 0702 hours0.00813 days <br />0.195 hours <br />0.00116 weeks <br />2.67111e-4 months <br /> and the commencement of stear generator crevice cleaning at 0720 hours0.00833 days <br />0.2 hours <br />0.00119 weeks <br />2.7396e-4 months <br /> on the same day.

Cold rod drop tests were completed at 0300 hours0.00347 days <br />0.0833 hours <br />4.960317e-4 weeks <br />1.1415e-4 months <br /> on December 5; the steam generator crevice flush was completed at 1145 hours0.0133 days <br />0.318 hours <br />0.00189 weeks <br />4.356725e-4 months <br />; and the heat-up for the ASME Section XI ten-year hydrostatic test of Class 1 components was begun. This hydrostatic test was satisfactorily completed at 0605 hours0.007 days <br />0.168 hours <br />0.001 weeks <br />2.302025e-4 months <br /> on December 6. On December 8 hot valve line-ups were completed at 1158 hours0.0134 days <br />0.322 hours <br />0.00191 weeks <br />4.40619e-4 months <br /> with hot rod drop tests completed at 1927 hours0.0223 days <br />0.535 hours <br />0.00319 weeks <br />7.332235e-4 months <br /> the same day. The Unit I reactor was critical at 0101 hours0.00117 days <br />0.0281 hours <br />1.669974e-4 weeks <br />3.84305e-5 months <br /> on December 9 concluding the refueling outage.

Unit 1 was brought to 432 MWe net on December 14 after all outage-associated testing had been completed. Two trips were experienced on December 9 due to a spike and subsequent failure of the channel 31B source range detector. This occurred while the reactor was subcritical. The NRC was notified of the event as it was red phone reportable. Another unit trip from 80 MWe occurred on December 11 due to failure to block the low power range trip; again, the NRC was notified via the red phone.

Problems with the electro-hydraulic system governor valves caused a turbine trip on December 11 from low power conditions. The auxiliary governor solenoid valves were replaced later the same day.

Unit 1 operated at 420 MWe net throughout the remainder of the period with three load reductions. Load was reduced to 138 MWe net at 2056 hours0.0238 days <br />0.571 hours <br />0.0034 weeks <br />7.82308e-4 months <br /> on December 16 for condenser tube repairs. Load was reduced to al. proximately 330 MWe net for six hours on December 25 and 26 at the request of the Power System supervisor.

On December 10 followir.g rephasing of the unit to the line at the end of the refueling outage, both steam flow channels for loop "A" were discovered to be indicating zero flow.

The flow indications from FC-464 and FC-465 were noted at zero flow at approximately 0800 hours0.00926 days <br />0.222 hours <br />0.00132 weeks <br />3.044e-4 months <br /> on December 10. It is not unusual for flow indications to fluctuate when the unit is first placed on line and the zero flow condition could not be detected until the unit had reached approximately 15% power.

Following investigations into the problem, flow channel FC-464 was placed in the trip position at 0830 hours0.00961 days <br />0.231 hours <br />0.00137 weeks <br />3.15815e-4 months <br />. This met the Technical Specification for limiting conditions of operation since the logic is one out of two per loop for steam flow. With one steam flow channel in trip for the "A" loop, the high and high-high steam flow portion of the logic is already in for steam line isolation and reactor trip. Steam line isolation in initiated by a high steam flow coincident with low Tave and safety injection or a high-high steam flow coincident with safety injection. A reactor trip is initiated by a steam flow / feed flow mismatch (steam flow higher than feed flow) and a low steam generator level.

Following further review and discussions into the problem, the other flow channel, FC-465, was placed in the trip position at 1030 hours0.0119 days <br />0.286 hours <br />0.0017 weeks <br />3.91915e-4 months <br /> on December 10. Placing the remaining channel in trip satisfied the Technical Specifications in providing the minimum degree of redundancy.

The zero flow indications were a result of improper zero settings on both transmitters. These transmitters were installed during the outage as part of TMI-required modifications and were checked out and aligned satisfactorily on November 7.

Although the exact cause of the transmitter misalignment cannot be determined, the cause is believed to be related to contractor activity in the area; either by movement of equipment in the area or by an inadvertent adjustment of the exposed zero adjust screw by an unauthorized person.

Both transmitters were realigned and put back into service by 1230 hours0.0142 days <br />0.342 hours <br />0.00203 weeks <br />4.68015e-4 months <br /> on December 10.

This event is reportable in accordance with Technical Specification 15.6.9.2.A.2.

_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _________J

l On December 19 at'2325 hours0.0269 days <br />0.646 hours <br />0.00384 weeks <br />8.846625e-4 months <br />, Unit 1 "A" steam generatcr

. pressure indicator 1PI-482 was observed not to be indicating

. properly. It was discovered that the sensing lines to pressure i transmitter 1PT-482 had frozen up. These sensing lines were

! recently rearranged as part of post-TMI backfit modifications, i Further investigation revealed holes in the sensing line insulation allowed cold air to infiltrate the insulation and permit the water in the sensing lines to freeze. The sensing '

lines were thawed and a second heat tracing circuit for the affected

) sensing lines was activated. This occurrence is reportable as a

! 30-day report in accordance with Technical Specification 15.6.9.2.B.2,

" Conditions leading to operation in a degraded mode permitted by

, a limiting condition for operation", (Licensee Event Report No.

l 81-020/03L-0). '

i Safety-related maintenarce during this period included continued efforts in satisfying requirements for block walls, l

seismic restraints, and TMI electrical upgraded equipment >

installation; adjustment of the undervoltage relays serving the ,

A05 and A06 buses; replacement of several failed relays; completion

of replacement and repair of the reactor coolant sample valves; and correction of problems identified during the Class 1 hydro-static test.

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l OPERATING DATA REPORT DOCKET NO. 50-301 l DATE January 6, 1982 l COMPLETED BY C. W. FAY i

l TELEPHONE 414 277 2811 OPERATING STATUS

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

l 2. REPORTING PERIOD: DECEMBER 1981 . .

3. LICENSED THERMAL P0JER (MWT): 1518. . .

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

l 5. DESIGN ELECTRICAL RATING (NET MWE): 497. . .

6. MAXIMUM DEPENDABLE CAPACITY (GROSS MUE): 51v. . .

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

8. IF THANGES OCCUR IN CAPACITY RATINGS (ITEMS NUMBER 3 THROUGH ') SINCE LAST REPORI, GIVE 1NS:

NOT APPLICABLE

9. POWER LEVEL TO WHICH RESTRICTED, IF ANY (HET h1E): NOT APPLICABLE

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

11. HOURS IN REPORTING PERIOD 744 8,760 82,561

12. NUMBER OF HOURS REALTOR WAb CRITICAL 736.9 /,840.4 74,390.4

13. REACTOR RESERVE SHUTDOWN HOURS 0.0 6.7 193.0

14. HOURS GENERATOR ON LINE 724.9 7,760.1 73,058.6

15. UNIT RESERVE SHUTDOWN HOURS 0.0 54.1 178.0

16. GROSS THERMAL ENERGY GENERATED (MUH) 1,073,535 11,467,098 100,256,844

17. GROSS ELECTRICAL ENERGY GENERATED (MuH) 365.310 3,899,160 34,023,010

18. NET ELECTRICAL ENERGY GENERATED (MWH) 341,456 3,720,045 32,383,466

19. UNIT SERVICE FACTOR 97.4 88.6 88.5

20. UNIT AVAILABILITY FACTOR 97.4 89.2 88.7

-21. UNIT CAPACITY FACTOR (USING MDC NET) 94.9 85.8 79.9

22. UNIT CAPACITY FACTOR (USING DER NET) 94.5 85.4 78.9

23. UNIT FORCED OUTAGE RATE 0.0 0.0 1.7

24. SHUTDOWNS SCHEDULED DVER NEXT 6 MONTHS (TYPE, DATE, AND DURATION OF EACH): Refueling outage scheduled for April 16, 1982, expected to last approximately 14 weeks.

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

DOCKET NOo 50-301 '

UNIT NAME Point Beach Unit 2 .

DATE January 6, 1982

.t COMPLETED BY C. W. Fay TELEPHONE 414/277-2811

AVERAGE DAILY UNIT POWER LEVEL 1

MONTH December, 1981 AVERAGE AVERAGE AVERAGE i

DAILY DAILY- '

DAILY POWER LEVEL POWER LEVEL POWER LEVEL DAY MWe NET DAY MWe NET DAY MWe NET 1 486 11 489 21 492 2 488 12 488 22 492 3 488 13 488 23 495 4 489 14 482 24 494 5 488 15 492 25 490 6 497 16 488 26 446 7 481 17 487 27 456 8 477* 18 475 28 457 9 488 19 33 29 490 10 488 20 499 30 490 31 480 AD-28A (1-77)

UNIT SHUTDOWNS AND POWER REDUCTIONS DOCKET NO. 50-301 ,

UNIT NAME Point Beach Unit 2 DATE January 6, 1982 REPORT MONTH December, 1981 COMPLETED BY C. W. Fay ,

TELEPHONE 414/277-2811

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$n ao l o ou m e as No. Date g gg g j g g. Licelisee Event y g'g Cause and Corrective Action I e om e v .c Report No. m so To Prevent Recurrence Qw N O to C o 2: 3 0 0 l l

6 811219 S 19.1 B 1 N/A ZZ 3ZZZZZ The unit was taken off line for turbine stop valve and moisture separator reheater maintenance.

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1 3 F: Forced Reason: Method: Exhibit G-Instruc-S: Scheduled A- Equipment Failure (explain) l- 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 5

F- Administrative Exhibit I- Same AD-28B G- Operational Error (explain) Source (01-78) H- Other (explain)

. -. - ..= . .-

WARRATIVE

SUMMARY

OF OPERATING EXPERIENCE Docket No. 50-301 Unit Name Point Beach Unit 2 Date January 6, 1982 Completed By C. W. Fay Telephone 414/277-2811 Unit 2 operated at'490 MWe net throughout the period with one steam plant shut-down for turbine stop valve.and moisture separator reheater maintenance. Unit 2 was off line at 0151 hours0.00175 days <br />0.0419 hours <br />2.496693e-4 weeks <br />5.74555e-5 months <br /> on December 19. Following secondary plant maintenance, Unit 2 was placed on line at 2057 hours0.0238 days <br />0.571 hours <br />0.0034 weeks <br />7.826885e-4 months <br /> the same day and was at 490 MWe at 0050 hours5.787037e-4 days <br />0.0139 hours <br />8.267196e-5 weeks <br />1.9025e-5 months <br /> on December 20.

Training start-ups wer a conducted during the mei ntenance-outage.

Safety-related maintenance during the period included -

repacking of the 2P2A charging pump.

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