ML19351F621

Monthly Operating Repts for Dec 1980

ML19351F621
Person / Time
Site:	Browns Ferry
Issue date:	01/04/1981
From:	Thom T TENNESSEE VALLEY AUTHORITY
To:
Shared Package
ML18025B279	List: ML18025B278 ML19351F621
References
NUDOCS 8101130588
Download: ML19351F621 (37)

Text

,

O TENNESSEE VALLEY AUTHORITY DIVISION OF POWER PRODUCTION BROWNS FERRY NUCLEAR PLANT MONTHLY OPERATING REPORT December 1, 1980 - December 31, 1980 DOCKET NUMBERS 50-259, 50-260, AND 50-296 LICENSE NUMBERS DPR-33, DPR-52, AND DPR-68 Submitted By: // // /

Pl' ant Manager

810113 Oj$

TABLE OF CONTENTS Oper itions Sununary . . . . . . . . . . . .. . . . . . . . . . 1 Refueling Information . . .. . .. . .. . . . . ... . . . 3 Significant Operational Events . .. . . .. . .. .. . . . . 5 Average Daily Unit Power Level . . . . . . . . .. .. . . . . 12 Operating Data Reports . . . . ... . .. . .. . . . . .. . 15 Unit Shutdowns and Power Reductions. . .. . . . . ... . . . 18 Plant Maintenance . . . . . .. .. . . .. . . . . .. . .. 21 Outage Sununary . . . . . . . . . . . . .. . . .. .. . .. . 33 l

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Operations Summary December 1980 The following summary describes the significant operational activities during the reporting period. In support of this summary, a chronological log of significant events is included in this report.

There were twenty-three reportable occurrences and thirteen revisions to

< previous occurrences reported to the NRC during the month of December.

Unit 1 There was one scram on the unit during the month. On December 29, the reactor was manually scrammed to accommodate replacement of the stator cooling

~ '

filters.

Unit 2 There was one scram on the unit during the month. On December 27, the reactor scrammed from MSIV not full open during a SI when the unit operator 1

l tripped channel B main steam Hi radiation while PCIS channel Al was still in trip status, l

Unit 3 The unit was in its EOC-3 refueling outage the entire month.'

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2 Operations Summarv (Continued)

December 1980 Fatigue Usage Evaluation The cumulative usage factors for the reactor vessel are as follows:

Location Usage Factor Unit 1 Unit 2 Unit 3 Shell at water line 0.00497 0.00381 0.00315 Feedwater nozzle 0.24040 0.16081 0.11746 l

Closure studs 0.19766 0.13425 0.09816 Note: This accumulated monthly information satisfies technical specification section 6.6. A.17.B(3) reporting requirements.

Comon System I

Approximately 1.15E+06 gallons of waste liquid were discharged containing approximately 1.28E+00 curies of activity.

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3 Refueling Information December 1980 Unit 1 Unit 1 is scheduled for its fourth refueling beginning on or about April 10, 1981, with a scheduled restart date of August 23, 1981. This re-fueling will involve loading additional 8 X 8 R (retrofit) fuel assemblies into the core, the final fix on the sparger modification, power supply on LPCI modification, and torus modifications if all approvals are received.

There are 764 fuel assemblies in the reactor vessel. The spent fuel storage pool presently contains 550 spent 7 X 7 fuel assemblies, five 8 X 8 fuel assemblies, and one 8 X 8 R fuel assembly. Because of modification work to increase spent fuel pool capacity to 3471 assemblies, present available capacity is limited to 1193 locations.

Unit 2 Unit 2 finished its EOC-3 refueling outage and began cycle 4 during the month. Unit 2 is scheduled for its fourth refueling beginning on or about March 26, 1982, with a scheduled res, tart date of August 8, 1982.

This refueling outage will involve completing relief valve modifications, torus modifications if all approvals are received, "A" low pressure turbine inspection, and loading additional d X 8 R fuel assemblies into the core.

There are 764 fuel assemblies in the reactor vessel. At the end of the month, there were 132 discharged cycle 1 fuel assemblies,156 discharged cycle 2 fuel assemblies, and 352 discharged cycle 3 fuel assemblies in the

! spent fuel storage pool. The present available capacity of the spent fuel pool is 160 locations. With present capacity,' the 1979 refueling was the I

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Refueling Information (Continued)

December 1980 Unit 2 (Continued) .

last refueling that could be discharged to the spent fuel pool without exceeding that capacity and maintaining full core discharge capability in the pool. However, 9ss new high density storage locations have been installed, but cannot be used until Special Test 161 is completed.

Unit 3 Unit 3 was in its EOC-3. refueling outage during the month. Unit 3 is scheduled for its fourth refueling beginning on or about September 25, 1981, with a scheduled restart date of February 7, 1982. This EOC-4 re-fueling, involves loading additional 8 X 8 R (retrofit) assemblies into the core, relief valve modification, turbine inspection, and torus modi-fications if all approvals are received.

There are 764 fuel assemblies presently in the reactor vessel.

There are 124 discharged cycle 3 fuel assemblies, 144 discharged cycle 2 fuel assemblies, 208 discharged cycle 1 fuel assemblies, and 40 new 8 X 8 R assemblies in the spent fuel storage pool. The present available l

l storage capacity of the spent fuel pool is 1012 locations. With present capacity, the 1980 refueling will be the last refueling that could be discharged to the spent fuel pool without exceeding that capacity and I

maintaining full core discharge capability in the pool.

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5 Significant Operational Events Unit 1 Date Time Event 12/01 0001 Reactor thermal power at 77%, PCIOMR in progress sequence "A".

2300 Reactor thermal power at 96% steady state, maximum flow.

12/02 0700 Reduced thermal power from 96% to 94% due to Xenon buildup.

1406 Commenced rod withdrawal for power ascension.

1500 Reactor thermal power at 96%, maximum flow.

12/03 2333 Reduced reactor thermal power from 96% to 86% for control rod pattern adjustment and maintenance to "A" reactor feedwater pump.

12/04 0248 Control rod pattern adjustment complete, commenced PCIOMR from 86% thermal power - sequence "A" 0425 "A" reactor feedpump in service, PCIOMR in progress.

2300 Reactor thermal power at 99% steady state, thermal limited.

12/05 2335 Reduced thermal power from 99% to 60% for MSIV closure and turbine control valve tests.

12/06 0250 MSIV and turbine control valve tests complete, commenced power ascension.

0800 Commenced PCIOMR from 88% thermal power - sequence "A".

1500 Reactor thermal power at 99%, thermal limited.

12/12 2345 Reduced thermal power from 99% to 85% for turbine CV tests and SI's.

12/13 0425 Turbine CV tests and SI's completed, commenced power ascension.

0440 Commenced PCIOMR from 95% thermal power - sequence "A".

1500 Reactor thermal power at 99%, maximum flow.

12/22 0305 Commenced reducing thermal power from 99% to 70% for turbine control valve tests and SI's.

0345 Turbine control valve tests and SI's complete, commenced power ascension from 70% thermal power.

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6 Significant Operational Events Unit 1 Date Time Event 12/22 0700 Commenced PCIOMR from 94% thermal power - sequence "A".

1045 Reactor thermal power at 99%, maximum flow.

12/23 2350 Commenced reducing thermal power from 99% to remove "A"

/ recirculation MG set, "A" reactor feedpump and "B" con-densate booster pump from service for maintenance.

12/24 0500 Reactor thermal power at 55% holding for maintenance on "A" recirculation MG set, "A" reactor feedpump and "B" condensate booster pump.

0505 "B" condensate booster pump placed in service, reduced thermal power to 50% for maintenance on "A" reactor feedpump and "A" recirculation MG set.

0625 "A" recirculation MG set placed in service, increased thermal power to 70% and holding for "A" reactor feed pump maintenance.

0830 Reduced reactor thermal power to 45% for control rod sequence exchange from "A" to "B".

1155 Control rod sequence exchange complete, increased

-thermal power to 47% and holding for scram testing control rods.

1430 Scram test complete, commenced power ascension from 47% thermal power.

1730 Commenced PCIOMR from 57% thermal power - sequence "B".

2030 Placed "A" reactor feedpump in service.

12/26 1500 Reactor thermal power at 99%, maximum flow.

12/27 0015 Reduced thermal power to 85% for turbine control valve l

tests and SI's.

0330 Turbine control valve test and SI's complete, commenced PCIOMR - sequence "B" .

1126 Reactor thermal power at 99%, maximum flow.

12/29 0822 Commenced reducing thermal power for shutdown due to stator cooling filter problems.

1012 Reactor scram, manual, No. 139 from 41% thermal power to perform maintenance on stator cooling water system.

2226 Maintenance complete on stator cooling water system commenced rod withdrawal for startup.

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Significant Operational Events I Unit 1 Date Time Event 12/30 0125 Reactor Critical No. 160.

0725 Rolled T/G.

0754 Synchronized generator, commenced power ascension.

2145 Commenced PCIOMR from 65% thermal power - sequence "B".

12/31 0130 Reactor thermal power at 82% holding for possible feed-water heater leak.

0310 "C" string high pressure heaters isolated for leak repairs.

0420 Commenced PCIOMR from 82% thermal power - sequence "B".

1501 "C" string high pressure heaters placed in service.

2030 Reactor thermal power at 99%, maximum flow.

2203 Commenced reducing thermal power from 99% for control rod pattern adjustment.

2400 Reactor thermal power at 58%, control rod pattern adjustment in progress.

8 Significant Operational Events Unit 2 l

Date Time Event 12/01 0001 Reactor thermal power at 40% (RTI-32) recirculation pump ramp test in progress.

0135 RTI-32 complete, commenced power ascension from 40%

thermal power.

0848 Commenced PCIOMR from 60% thermal power - sequence "A".

12/02 2330 Reactor thermal power at 99%, maximum flow.

12/03 0040 Reduced reactor thermal power to 96% due to "B" recirculation pump speed control problems.

1500 Reduced reactor thermal power to 94% due to "B" recirculation pump maintenance (mechanical and electrical stops and speed indication).

2050 Maintenance complete on "B" recirculation pump, commenced PCIOMR from 94% thermal power.

12/04 0030 Reduced reactor thermal power from 97% to 95% for isolation of B1 and B2 high pressure heaters to repair leaks.

12/05 0140 B1 and B2 high pressure heaters back in service, comenced PCIOMR from 95% thermal power - sequence "A".

0445 Reactor thermal power at 97%, full core flow.

12/06 1220 Commenced reducing reactor thermal power for control rod pattern adjustment.

1500 Reactor thermal power at 55%, control rod pattern adj ustment in progress.

1600 Control rod sequence exchange complete, comenced power ascension from 55% thermal pcwer.

, 12/07 1000 Comenced PCIOMR from 80% thermal power - sequence "A".

! 2305 Reactor thermal power at 90%, holding to run a set of TIP's.

12/08 0240 Reduced thermal power to 80% for turbine control valve tests and SI's.

0440 Turbine control valve tests and SI's complete commenced pwar ascension.

l 0500 Comenced PCIOMR from 82% thermal power - sequence "A".

! 1801 Reactor thermal power at 99%, thermal limited, r 2227 Reducing thermal power from 99% for MSIV SI's and con-

! trol rod pattern adjustment.

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9 Significant Operational Events Unit 2 Date Time Event 12/09 0130 Reactor thermal power at 65%, MSIV SI's and control rod pattern adjustment in progress.

0300 MSIV SI's and rod adjustment complete, comenced power ascension.

0400 Commenced PCIOMR from 67% thermal power - sequence "A".

12/11 0700 Reactor thermal power at 99%, thermal limited.

12/12 2345 Reducing thermal power to 85% for turbine control valve tests and SI's.

12/13 0001 Reactor thermal power at 85%, turbine control valve tests and SI's in progress.

0229 Turbine control valve tests and SI's completed, com-

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menced power ascension.

0230 Commenced PCIOMR from 89% thermal power - sequence "A".

12/14 0700 Reactor thermal power at 99%, maximum load (electrical).

12/17 2230 Reducing thermal power from 99% for isolatic of Al and A2 high pressure heaters from service to repair leak on moisture seperator drain pump instrument line.

2300 Reactor thermal power at 95%, holding for maintenance on moisture seperator drain pump instrument line.

! 12/18 1320 Maintenance complete, Al and A2 heaters back in service, conunenced power ascension from 95% thermal power.

2300 Reactor thermal power at 99%, maximum load (electrical).

I 12/22 0350 Reduced reactor thermal power to 85% for control valve I tests and SI's.

l 0515 Turbine control valve test complet2d, increase reactor thermal power to 91%, holding for control rod exercise SI 4.3.A.2.

0520 Control rod exercise complete, consnenced power ascension from 91% thermal power.

0830 "B" recirculation pump M.G. fluid coupling oil line l leaking, reducing thermal power from 95% for repairs to oil line.

1014 Maintenance complete on "B" recirculation pump M.G.

fluid coupling oil line', commenced power ascension from 47% thermal power.

1100 Commenced PCIOMR from 94% thermal power - sequence "A".

1600 Reactor thermal power at 99%, maximum flow.

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10 Significant Operational Events Unit 2 Date Time Event 12/23 2047 Reduced thermal power to 70% for maintenance on control rod drive 38-35.

2340 Maintenance complete on CRD 38-35, commenced power ascension.

12/24 1500 Reactor thermal power at 99%, maximum flow.

12/27 0225 Reactor Scram No. 111( ) from 99% thermal power when main steam line high radiation monitor was not reset properly.

1737 Comnenced rod withdrawal for startup.

2125 Reactor Critical No. 122.

12/28 0035 Rolled T/G.

0103 Synchronized generator, cou enced power ascension.

1930 Commenced PCIOMR from 72% thermal power - sequence "A".

12/29 0942 Reactor thermal power at 99%, maximum flow.

1230 Reduced thermal power to 90% for control rod drive exercise.

1516 CRD exercise complete, commenced PCIOMR from 90%

thermal power - sequence "A".

12/30 0005 Reactor thermal power at 99%, maximum load (electrical).

12/31 2400 Reactor thermal power at 99%, maximum load (electrical).

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11 Significant Operational Events Unit 3 Date Time Event 12/01 0001 ECC-3 refuel outage in progress.

12/04 0550 Fuel moves started.

12/22 2200 Fuel movement completed.

12/29 0600 Tensioning reactor vessel head.

12/31 2400 Preparations for RPV hydro and startup test in progress.

(1) Personnel Error

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. 12 AVERAGE D AILY UNIT POWER LEVEL DOCKET NO. 50-259 UNIT Browns Ferry - 1 DATE 1~4-81 COMPLETED BY Ted Thom TELEPHONE 205-729-6846 I MONTH December 1980 DAY AVERAGE DAILY POWER LEVEL DAY AVER AGE DAILY POWER LEVEL IMWe-Net) (MWe Nett i 909 1063 37 2 1011 18 1060 3 1012 in 1056 4 964 1050 20 1058 1050 5 21 6 976 22 1n19 7 1068 23 ,

1052 10^9 8- 24 505 9 1052 25 A1R 10 1063 26 1025 gg 1057 1032

• 27 12 1058 23 1059 13 1031 420 29 14 inAA 30 anA 15 1063 33 880

,, 1058 INSTRUCTIONS

( On this tormat. fist the average daily umt powei !esci in MWe Net for eash day in the reporting month. Compute to the i;earest whole mepwatt.

l (4I77)

13 AVERAGE D AILY UNIT POWER LEVEL DOCKET NO. 50-260 UNIT Browns Ferry - 2 DATE 1-A Al COMPLETED BY Ted Thom TELEPHONE 205-729-6846 MONTH D= ~ hae DAY AVERAGE DAILY POWER LEVEL DAY AVERAGE DAILY POWER LEVEL (MWe. Net) (MWe. Net i j 713 ,7 1083 2 478 18 1037 3 1044 in 1072 4 1002 20 1073 5 in?' 21 In76 6 RM 22 1028 7 876 23 .

1037 3

973 1061 34 9 701 25 1075 10 938 -

26 1079 11 Inni 27 44 12 1nA 28 00' u

13 1034 29 1007 g4 1080 1067 30 15 1dRa 31 1070 lo -

1087 INSTRUCTIONS On ilus 1.irmat.!i<t the average dails umt pimes !csel m MWe. Net fur exh day m flie reporimg in. nth. Compute to the nearest whole nwyaw;itt.

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s 14 AVERAGE DAILY UNIT POWER LEVEL DOCKET NO.

50-296 UNIT Browns Ferry - 3 DATE 1-4-91 COMPLETED BY Ted Thom TELEPHONE 205-729-6846 i

MONTH n.c -her 1980 DAi AVER AGE DAILY POWER LEVEL DAY AVER AGE DAILY POWER LEVEL (MWe Net) (MWe-Net)

-9 37 -4 2 7 18 4

3 -4 19 4 4 A 20 - -4 3 -6 23 -5 6 -6 22 A 7

-6 23 ,

-4 f 8 -5 24 -5 9 -5 25 9 to -5 26 -5

-5 -5

27 12 , -5 33 _t 13 29 -4 la -5 30 ~4 15

-4 3l ~7 16 -4 INSTRUCTIONS On this format.!ist the averas daily imit p.>wer lesel is MWe Net for each day in Ilie repoetmg mi.nih.Coimpute io the nearest whole mepwatt. ,

(4/771 O

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.. .. ,, 15 OPERATING DATA REPORT DOCKET NO. 50-259 DATE 1 A A1 COMPLETED BY h I'e a a*t TELEPilONE _205 -774-6846 OPERATING STATUS Browns Ferry - Unit 1 Note 5

1. Unit Name:

December 1980

2. Reporting Period:

3293

3. Licensed Thermal Power (MWt):

1152

4. Nameplate Rating (Gross MWe):

1065

5. Design Electrical Rating (Net MWe):

6. Maximum Dependable Capacity (Gross MWe): 1098.4 1065

7. Maximum Dependable Capacity (Net MWe):

8. If Changes Occur in Capacity Ratings (!tems Number 3 Through 7) Since Last Report.Give Reasons:

NA

9. Power Level To Which Restricted.lf Any (Net MWe): NA -

10. Reasons For Restrictions.lf Any: MA ,

c This Month Yr to.Date Cumulative .

744 8,784 56,282  !

11. Ilours in Reporting Period 728.78 6,529.29 34,806.57

12. Number Of Hours Reactor Was Critical 409,26 5098.57 15.22

13. Reactor Reserve Shutdown Hours 722.30 6,380.09 33,992.82

14. Hours Generator On.Line 0 0 0

15. Unit Resene Shutdown flours  ;

2,242,925 19,155,868 93,292,361

16. Gross Thennal Energy Generated (MWH)

17. Gross Electrical Energy Generated (MWH) 741.87Q__,... 6.244.830 30.763.290 723.052 6.061.849 29.863,817

18. Net Electrical Energy Generated (MWH) '

97.1 72.6 -60.4 ,

19. Unit Service Factor '

97.1 72.6 60.4

[ 20. Unit Availability Facto,

21. Unit Capacity Factor IUsing MDC Net) 41.3 64.8 49.8 91.3 64.8 49.8

22. Unit Capacity Factor IUsing DER Net)

23. Unit Forced Outage Rate 2.9 7.5 29.3

24. Shutdowns Scheduled Over Next 6 Months IType.Date.and Duration of Each):

Refuel April, 1981 l

25. If Shut Down At End Of Report Period. Estimated Date of Startup:

26. Units in Tot Status a Prior to Commercial Operations: Forecast Achiesed INITIA L CRITICALITY INJTIAL ELECTRICITY

! COMMERCI \ L OPERATION 1

i 4

(9/77) 7

)

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OPERATING DATA REPORT DOCKET NO. 50-260 DATE 1-4-81 COMPLETED DY Nn t'v .,

TELEPHONE 709-770 AA46 OPERATING STATUS Notes Browns Ferry - hie ?

1. Unit Name:

2. Reporting Period: December 1980

3. Licensed Thennal Power (MWt p: 3293 l 1152

4. Nameplate Rating (Gross MWe):

1065

5. Design Electrical Rating (Net MWe):

1098.4

6. Maximum Dependable Capacity (Gross MWe):

7. Maximum Dependable Capaci;y (Net MWe): 1n6s

8. If Changes Occur in Capacity Ratings (items Number 3 Through 7) Since Last Report. Gi e Reasons:

NA

9. Power Level To which Restricted.lf Any (Net MNe): MA ~

10. Reasons For Restrictions.!f Any: NA 4

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This Month Yr..to.Date Cumulative -

744 8,784 51,193 I II. Hours in Reporting Period

12. Number Of Hours Reactor Was Critical 779 A 9 't o 1 1 in 7 7.1 es 12,45L48

~

19.0 678.54 ~ *

13. Reactor Reserve Shutdown Hours

14. Hours Generator On Line 721.37 6,076.65 29.740.96 0 0 0

15. Unit Reserve Shutdown llours 2,185,250 17,415,643 83,570,643 ..

16. Gnm Thermal Energy Generated (MWII)

17. Gross Electrical Energy Generated (MWH) 738.400 _ ,,, 5.787.120 27.737.188

18. Net Electrical Energy Generated (MWH) 720,719 5.618,838 26.950.307 '

97.0 69.2 58.1

19. Unit Senice Factor

20. Unit Availability Factor 97.0 69.2 58.1

21. Unit Capacity Factor (Using MDC Net) 91.0 60.1 49.4 91.0 60.1 49.4

22. Unit Capacity Factor (Uning DER Net)

23. Unit Forced Outage Rate 3.0 in_s 19 g

24. Shutdowns Scheduled Over Next 6 Months (Type. Date,arn! Duratiim of Eacht:

25. IIShut Down At End Of Iteport Period. Estimated Date of Startup:

26. Units In Test Status (Prior to Commercial Operationi: Forecast Achieved INITIA L C!tlTICALITY INITIAL ELECTRICITY CO\lMERCI \ L OPER ATION (4/77)

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. . 17 OPERATING DATA REPORT 6O Or "

DOCKET NO. 50-296 DATE 1-4-81 i COMPLETED BY Don Creen - i TELEPHONE 9M 790_AA46 OPERATING STATUS Am== hm - t'a 4 * 't

1. Unit Name:

2. Reporting Period: December 1980 3293

3. Licensed Thermal Power (Mhtn

4. Nameplate Rating (Gross MWet 1152 1065

5. Design Electrical Rating (Net MWe):

. 6. Maximum Dependable Capacity IGron MWeg 1098.4

7. Maximum Dependable Capacity (Net MWe): 1065

, S. If Changes Occur in Capacity Ratings (Items Number 3 Through 7) Since Last Report Give Reasons: l NA

9. Power Level To Which Restricted. lf Any (Net MWe): NA -

10. Reasons For Restrictions.If Any: NA J

• This Month Yr to.Date Cumulative 1 I 744 8,784 33,648

11. Hours In Reporting Period 0 7,064 25,971.55

12. Number Of Hours Reactor Was Critica!

0 152.58 1,810.89

13. Reactor Reserve Shutdown Hours 0 6,952,19 25,390

14. Hours Cencrator On Line U 0

15. Onit Reserve Shutdown lleurs 0

16. Gros Thermal Energy Generated IMWH) 0 21,257,162 74,365,028 ..

0 7,136,450 24,539,030

17. Gron Electrical Energy Generated (MWH) , , , , , , , , , ,

0 6,936,550 23,824,323

13. Net Electrical Energy Generated (MWH) ,

19. Unit Service Factor 0 79.1 75.5 ,

20. Unit Asailability Factor 0 79.1 75.5

21. Unit Capacity Factor IUsing MDC Net, O 74_1 A A _ a;

• 22. Unit Capacity Factor IUsing DER Net) 0 74.1 66.S

23. Unit Forced Outage Rate 0 11.7 9.8

24. Shutdowns Scheduled Over Next 6 Months IType. Date,and Duration of Each1:

2

25. If Shut Down At End Of Report Period. Estimated Date of Startup: ye...q.17;ioni

26. Units in Tnt Status t Prior to Commercial Qperationi: Forwast Achiesed INITIA L CltlTICALITY INITIAL ELECTRICITY C0\lM ERCI AL OPER ATION (9/77)

UNITSilUTDOWNS AND POWEO REDUCT10NS Botkk No. e 30e259 UNIT NAME R rnt.rn <a Fngry_,- 1.

D ATE _1_.4_g1 j' NEUD W " " D ""

REPORT MONTil n co-hor TELEPilONE ?n b7 m 684(u

-_ E E No. Date

., jg 3 j

JU Licensee ,E e, h Cause & Corrective e

3, 3g g

.E s 5 Event g? g? Action to f= jgg Repose = in U g' Preveni Recurrence C

158 801205 S B Derated for turbine control valve and MSIV tests and SI's 159 801222 S B Derated for turbine control valve tests and SI's 160 801223 F A Maintenance to "A" reactor feedpump "A" recirculation MG set and "B" E$

condensate booster pump 161 001229 F 21.70 A 2 Maintenance to stator cooling system (Replace filters) 162 801231 S H . Derated for control rod pattern adj ustment tc i I 2 . 3 4 N

F: Forced Reason: Method:

S: Scheduled A Equipment Failure (Explain) .

I-Manual Exhibit C - Inst ructiems for Preparation of Data Q'

B Maintenance of Test 2-Manual Scram. Entr> Sheets for i nenwe '

C Refueling 3 Autonutic Strim. Eveni Repost iLl.'RI File (NURI G- "M D Regulatory Restsiction 4-Other (Explain) 01611 b c>l E-Operator Training 1 License Examination - -

~

F Adadnistrative G Operatiosul Es tos (Explaini 5

Estubis 1 - Same Source PZ (9/77) ll Ot her i Explaini F

l o UNITSHUTDOWNS AND POWER REDUC 110NS wgga 35460 -

UNIT NME Browns Fetry -2 l DATE 1 11 1 December COMPLETED BY 3191LGIcen REPORT MONTil TELEPif0NE 7fl5-729d84L_

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, - E E l , .! - 3 j Y ~t Lisensee ,E=e, g'",, Cause A Currectisc l L. Date i, 5 4 2sE Eveni y g ~' Aceh m oo e-35 E j if3 g Repors= v: O g' Psevens Recurrense d ,

9 157 801206 S H Derated for control rod adjustments l 158 801208 S H Derated for MSIV SI's and control l rod adjustments l 159 801222 F B Derated for maintenance to "B" recir-culation pump MG oil line G

j. 160 801223 F B Derated for maintenance of CR-38-35 l 161 801227 F 22.63 A 3 Reactor scrammed when main steam line l high radiation trip was reset impro-perly l '

t e

Y h y l l 3 4 Q

l F: ForceJ S- S heduled Reason:

A. Equipment Failure (Explain)

Method:

1 Manual Exhibie G-Instructions M l . for Preparation us Dana H4taintenance of Test C Refueling 2 Manual Scram.

3 Autonntie & sam.

Ents) Sheets for I acusee g  !

i D.Resulatiny Restsiettun 4-Other (E xplaml tient 0161i Repuri(l.I'RIIile iNURt G M t Opeutor l'saining & t.isense Exammation l F Adminnerati.e 5 [9~2) j- G-Operatior.al Errus IExplain t Esinbis 1 - Same Source (9/77) Il-Ot hes ( E splami pg  ;

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UNIT SilUTDOWNS AND POWER REDUCTIONS bd'

• l UNIT NAME .Br.auns Ferry - 3 .

! DATE .1-4-81 i REPORT MONTil n.,--u, COMPLETED BY nnn Creen l

TELEPHONE .205-129-6846 .

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-, .! ? 'h E Licensee E*, c. Cause A Correi.tive l N*- DJ8e i 5? 4 .s s E Evens a7 g? Assion to 35 5 jig Report dib y' Prevent Recustence d ,

153 801201 S 744 C 1 EOC-3 Refuel Outage Cont.

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L3 GEED ass I 3 4 F: ForccJ Reason: Method: Exhihis C . insieuctions @

S. Ssheduled A. Equipment Failure (Explain) it.Maintenanse ci Tes

. l. Manual 2-Manual Scram.

for Pseparation os Data Entry Sheets fos tiemee g

C Refuchng  %

3 Autunutic Stram. Event Repost lLERil'de tNURi~G-D. Regulator) Resisiction 4 Other (Emplami 016Ii

1. Operato Training & lxense Examination F Adnunistusi.e 5 DM 19/77)

G Operaisenal E:ror IEmplaint 11 Othes I Explami Estubit I . Same Sousce g M

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' EROWNS FERRY NUCLEAR PLANT UNIT cn-man ..

CSSC EQUIPMENT ELECTRICAL HAINTENANCE SL29fARY For the Month of December 1980 Effect on Safe Action Taken

' Results;of To Preclude Nature of Operation of Cause of Date System Component Halfunction Recurrence Haintenance The Reactor Halfunction j

4>

None, the A bad coil on The bad coil caused Replaced bad coil, 2/1/ 80 Diesel 'C' Diesel Scheduled s slow operation of on SUDR relay, Generator' redundant diesel generator signal unit Generator duration relay. the SUDR relay completed EMI 3. SUD start test was operable. relay operated proper allowing an are to i .

EtiI 3 remain across' relay ly. TR #194429 contacts 1-2 thus 6 I ' -

not allcwing DG

- fast start circuit i to reset. I t

6 A shorted diode A shorted diode in 8eplacedshorteddiod

, 12/3/80 Diesel 'C' Diesel Output bkr. NONE in over-speed over-speed trip Reran surveillance Generator 1812 opened Generator during sur- trip alarm alarm circuit pest, diesel generate circuit, tripped breaker operated properly,o **

veillance TR #189406 BFR0 testing (SI % 1812.

50-259-8088 l

- 4.9.A.l.a.) ,

. l 8 -

1 Filter dryer Capacity to cool, ke'placedfilter Ref'rigerant Compressor None. C07 fire 12/11/80 CO 2 Fire lines freezing protectioA became saturated CO2 was slightly fryerandchecked Protection compressor on causing Ifnes to reduced. bxpansion valve, System Cardox uni't system remained - booling unit operatec in service freeze.

located at TR #17826".

units 1 & 2 froperly.

g diesel gene - .

' rators , ,

l t

... Audio Alarm inop- Replaced bad relay, Audio alarm DG alarm panel 12/14/8C Diesel 'D' Diesel NONE relay mechani- erable alarm operates .

Generator Gensrator relay was cally hanging properly. TRfl97031 found to be hanging up up

- during sur-f.

~

veillance i testing (SI 4.9.A.l.d) .

O

\- l . i

• BRO' INS FERRY NUCLE /d PLANT UNIT 1_ .

ELECTRICAL HAINTENANCE

SUMMARY

CSSC EQUIPHENT I

- . For the Month of December 1931.

Effect on Saie Action Taken Natuie of Operation of Cause of Results of To Preclude D..t e System jComponent Halfunction Halfunction Recurrence Haintenance The Reactor a

?

lA, RPS HG HG set was None. Equipment Relay contact Burned rplays, Replaced wiring 12/2/80 Reactor arm retainer , wiring and trans- and transformer, Protection set removed from responded in former. ' changed relays to System service due safe direction rings were '

non-flammable type to smoke and gave is made of flamma-g ,

coming from scram. Hinor ble materials. -

retainer rings.

TR #189267, 219203 HG set control fire was local- -

box ized and con-tained within ,

the equipment enclosure.

J FSV 77-15B Not receiving NONE Closed limit Received no closed Adjusted limit switch 12/4/80 Radwaste indicating lights System a closed in- switch was indicating light operate properly. U 4

dicating out of adjust- in control room, ment. TR #189278 light in the control room. ,

l .

Valve position NONE Limit switches Indicating lights on Adjusted limit 12/20/80 Primary FCV 64--140 switches, indicating indicating out of adjust- panel 9-3 did not Containment operate properly. lights and switches

~

System lights not ment. ,

- operating operate properly, properly.

TR #203251 Open indicating NONE Open limit. Tightened open opera-12/21/80 HPCI FCV 73 Not receiving tor arm, lim'it switcl-

% a valve indi- switch operator light inoperative.

cating light arm was loose. now operates properly for open .

TR #203247 4

position on panel 9-3. .

Closed indicat- NONE Bad resistor Closed indicating Replaced resistor,in-12/22/80 HPCI FCV 73-6B ing light for light fqr FCV 73-6B <licating light oper-on panel 9-3 inoper- ates properly. TR i FCV 73-6B on panel was inop ative. 203245

} j  ;

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1

• BRO'.fNS FERRY NUCLEA!! PLANT UNIT ELECTRICAL HAINTENANCE

SUMMARY

CSSC EQUIPflENT For the Month of December 19 80 ,

Effect on Sate Action Taken Operation of Cause of Resultslof To Preclude System Coraponent Nature of Malfunction Recurrence Dr.tc The Reactor Halfunction Maintenance l

Handswitch for NONE Blown fuse in Handswitch indicat- Replaced fuse, indi-112/29/80 Associated Indicating-indicating ing lights were cating lights operate Electrical lights on normal-alter-System panel 9-8 nate feed to light circuit. inoperative. properly. TR #203221 480V shutdown ,

board IB has no indicating l I

lights l ,

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' BROWS FERRY NUCLEAll PLANT UNIT L' ELECTRICAL MAINTENANCE SUt&fARY

, CSSC EQUIPMENT

- For the Month of December 19 80 Ef fect on Sale Action Taken Nature of Operation of Cause of Results of To Preclude DnSe System Component Malfunction Malfunction Recurrence Haintenance The Reactor D Bad pushbutton Local control open Replaced bad trans-

'12/6/80 EECW FCV 67-49 Open indicat- NONE indicating light former, open indicat-ing light on light transfor-inoperative ing light transformer local control mer.

is operable. TR f switch inop- 197013 i

erative During EMI 4C Neutron 2A battery Replaced broken Neutron 2A Scheduled NONE.. System battery per SEMI 27.

12/7/80 Neutron continued to found neutron was inoperative.

Monitoring Battery maintenance TR #193740, 178795, EMI 4C operate pro- 2A battery System post broken. 197016 perly.

Bad terminal Indicating lights Replaced bad terminal Core FCV 75-39 Both open and NONE block. TR #189321 12/8/80 block on limit fail to operate Spray closed indica- properly. Z ting lights train.

Cooling g System are on with '

valve closed.

8 e

l- .

Removed condensation Shorted relay Condensation acted 12/28/80 Fire TA 39-110 Heat detected NONE as a conductor from relay and dried or power due to conden- detector box, annunct i Protectior across the relay sation in zone failure detector box. contacts of the ator cleared. TR #

alaon heat detector (TA 202843 39-110) thus giving l

' a false alarm 4

+

b 9

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' ' BR05'NS FERRY NUCLEAR PLANT UNIT L' -

CSSC EQUIPHENT ELECTRICAL HAINTENANCE SIR &fARY For the Month of December 1980 .

. Effect on Safe Action Taken i Nature of Operation of Cause of Results of To Preclude -

Date System Component Malfunction Maintenance The Reactor Halfunction Recurrence HCV 23-49 Limit switch NONE Broken limit Limit switch would Replaced broken I 11/30/80 RHRSW inoperative switch, not return to limit switch. TR f normal position 189670 3

when valve was l '

closed thus not giving a indicating

- light at panel 9-3.

t 12/1/80 RCIC FCV 3-71-3 EMI 16 and 18 None, RCIC During perform- Valve would not Replaced bad torque was tagged out ance of EMI 16 cycle. Closed switch, performed EMI 16 & 18. TR #

due to unit & 18 FCV 71-3 each time it outage. torque switch would operate. 219284 g was discovered to be bad. Ul 1

i "

Vacuum Pump Pump motor hac NONE, Brush lead was Vacuum pump was Cleared brush lead, RCIC

{12/6/80 a 250V ground grounded to inoperable, megged motor, motor cover, was started and op-

erated properly. TR l #188976 12/9/ 80 Neutron Startup , Two SRM detec- None, the SRM Bad coils on Relays would not Replaced bad coils, Monitoring range monitoi t'ro drives detectors were relays 7C-K7A pick up when power relays operated System detectdie inoperable in proper and 7C-K9L. was applied. properly. TRf drive relays monitoring - 158662, 158664 ,

7C-K7A and locations 7C-K9L in panel 25-14 .

l .

' ER0h'NS FERRY NUCLEAR PLANT UNIT 3 ELECTRICA13 MAINTENANCE SUt21ARY CSSC EOt!IPMENT For the Month of December 19 80 Effect on Safe Action Taken Operation of Cause of Results of To Preclude Date System Component Nature of Malfunction Recurrence Maintenance The Reactor Halfunction 2

• 42/12/80 RCIC Speec detec- Over-speed NONE Broken connec- Over-speed trip Replaced broken

tor (SE 71- trip circuit tor on speed circuit inoperative connector on speed ,

42) on RCIC inoperative detector detector. TR #158531 Turbine Relay 5AK15A Replace auxil- NONE* Broken auxil- Broken seal in Replaced broken L2/15/B0 Reactor ,

contacts for relays auxiliary contacts, Protection Relay SAK15C iary contacts lary contacts.

would not allow relays and contacts System on relay-SAK15A and reactor manual operated properly SAK15C.' scram channel "A3" allowing scram to to reset, reset. TR #189410, 189576 S?

t 12 RCIC Magnetic RCIC logic None, this Wire shield on 'Over-speed' trip Insualted wire shiel l /24/80 speed pick- had a 220V event occurred magnetic speed circuit inoperative from ground, ground up ground. during unit pick-up.on cleared. TR #203129 refueling over-speed trip outage, circuitry was grounded.

12/28/80 Reactor FCV 69-1 Check opera- NONE Auxiliary Required that hand- Adjusted and cicaned Water , tion of seal- ,

contacts were switch be held to auxiliary contacts, Cleanup . in contacts in not making up. open position now functioning System V. . open run mode -

through complete properly. TRf202979 of breaker. open cycle of valve ,

9

3 ,

' BROWNS FERRY NUCLEAR PLANT UNIT .

ELECTRICAL HAINTENANCE SUtttARY CSSC EQUIPt1ENT 19 80 For the donth of December Action Taken Effect on Safe Results of To Preclude Operation of Cause of Component Nature of Malfunction Recurrence D.-te System Haintenance The Reactor Halfunction Circuit breaker Th'e valve was Aligned and retight-FCV 74-35 Indicating s NONE 12/13/$0 RHR lights blink-was not align- operable, the loose ened breaker, valve ed properly connection only and lights operated ed during thus not making caused brief inter- properly. TRi197042 valve opera-tion a tight connec- ruptions in the

- tion to bus. circuit.

When alarm NONE Bad relay on When alarm was test- Replaced bad relay, ,

l 12/13/80 Annuncia- 3B diesel ed it was slow to alarm operated l was tested it annunciator generator properly. TRf 189571 '

tor alarm panel would not card. S reset.

reset properly ,

Seal-in contacts FCV 74-25 would not Aligned contacts, tj L2/13/80 RHR FCV 74-25 Valve would ^

NONE valve operated not drive were out of fully open.

alignment. properly. TRf189582 fully open.

k .

I NONE' Pressure' switch Received annuncia- Replace pressure k2/14/80 Fire Received Pressure tion on fire pro- switch. TR# 189573 Protection switch for annunciation out of calibra '

on fire pro- tion tection pan &1 sprinkler. 3-25-311 system a't tection panel panel 25-2-81 3-25-311.

A . -

V. ,

XA-39-114A2 Received NONE Loose connection The loose connection Reterminated wires to 12/17/80 Fire on terminal poin caused the loss of point #7 on TA block, Protection Panel 25-313 trouble annun-power supply of trouble annunciation clation in point #7, TA termi, nation 2 smoke detectors cleared. Reopened control room supervisory circuit t block verify trouble annun-clation would repeat.

Trnuble alarm operatt

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' BR0k'NS FERRY NUCLEAR PLANT UNIT 3_

• ELECTRICAL HAI ITENANCE SUt!!!ARY C3SC EQUIPflENT For the Month of December J 81 Effect on Safe Action Taken Nature of Operation of Cause of Results of To Preclude Dr.t e System Component Malfunction liaintenance The Reactor Malfunction Recurrence

,)

properly at local-panel. TR#189572 I .

Relay SAK13C NONE Relay contacts Relay 5AK13C some- Aligned relay con-L2/24/80 CRD Relay SAK13C contacts, contacts-sometimes arcing due to times arcing located at operated properly.

contact mis- causing relay panel 9-15. arcing causing TR #203130 relay 5AK15 alignment. SAK15 and SAK15C and SAK15C to chatter.

to chatter.

s 3

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BROWNS FERRY NUCLEAR PLANT UNIT ALI, INSTRUMENT MAINTENANCE

SUMMARY

CSSC EQUIPMENT fog TIIE MONT11 OF December 19 80 NATURE EFFECT ON SAFE CAUSE ACTION TAKEN "JATE SYSTDI COMPONENT OF OPERATION OF OF RESULTS OF TO PRECLUDE

MAINTENANCE Tile REACTOR MALFUNCTION MALFUNCTION RECURRENCE JNIT 1 -

L2-ll Radiation TA-90-144 Calibrate None Setpoint drift Indicated abnormal None Monitoring temperature L2 Containment Il M-76-39 Replace None End of sensor Low sensor output New system to 2

Inerting life replace CE system bNIT I.

~

I L2-2 Radiation FI-90-165 Calibrate None Instrument drift Annunciator would None Monitoring not clear L2-ll Residual FI-74-56 Repair None Faulty amplifier Indicated flow with None' y lleat pump off Removal L2-22 Residual TI-74-136B Repair None PCB corroded Room temperature None

. lieat indicated downscale -

Removal

• • um 4

e 8

BROWNS FERRY NUCLEAR P1 ANT UNIT _ q _

HECHANICAL HAINTENANCE

SUMMARY

CSSC EQUIPMENT For the Month of December 19 80 ACTION TAKEN EFFECT ON SAFE CAUSE OF RESULTS OF 'lD PRECLUDE DATE SYSTEM COMPONENT NATURE OF OPERATION OF MALFUNCTION MALFUNCTION RECURRENCE MAINTENANCE ' IRE REACTOR None Leaking valve Leaking valve Replaced bonnet gasket

/1/80 RCIC Steam line dralii Valve bonnet ,* on valves pot isolation leak l

TR 166790 valves None Valve leaking Valve leaking Replaced bonnet gasket

/1 RCIC Valve 71-201A Valve seat steam leak on valve

~

TR 166707 Replaced dia- None Preventive None Changed out repair kits

!/15 CRD CRD Hodules Flaintenance and diaphragms 22-31, 26-31 phragas and 26-39, 18-39 valve internal 6 TR 198949 14-39, 10-43 14-43, 18-43 22-43, 26-43 30-43, 22-39 o scram pilot val-res Replaced dia- None Preventive None Changed out repair kit 1/16 CRD CRD Hodules daintenance and diaphragms 30-35, 26-35 phragms and -

TR 198949 22-35-18-35 valve internal s 14-35, 10-39 hf 06-47, 10-47 14-47, 18-47 22-47, 26-47 scram pilot val res Valve 78-66 None Valve stem bindini, Metal shavings comini, Repaired packing glant 2/22 Fuel Pool Valve stem not off when operated on valve -

Cooling lined correct 1 r TR 202996 FCV-85-llA and Bad seat None Bad seat Flow in excess of Replaced-seat with new 2/10 CRD minimum requirement one e- .

^ +-

FCV-85-11B TR 158658 & 158659

s "ep v i e

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- L t AOR Y A n o S O R C NT R I M NOC e E N OIA n F A e TE o l

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~  !

33 OUTAGE

SUMMARY

December 1980 Refuel floor activities progressed well through the month of December with completion of fuel shuffle at 2200 hours0.0255 days <br />0.611 hours <br />0.00364 weeks <br />8.371e-4 months <br /> on December 22. Core verification work was completed at 0100 hours0.00116 days <br />0.0278 hours <br />1.653439e-4 weeks <br />3.805e-5 months <br /> on December 24, and vessel reassembly work started shortly thereafter. Vessel reassembly efforts in preparation for the RPV hydro were complete at 0200 hours0.00231 days <br />0.0556 hours <br />3.306878e-4 weeks <br />7.61e-5 months <br /> on December 30. At this time emphasis shifted to the drywell valve work remaining in preparation for hydro. All outage preparations for RPV hydro were complete by the end of this reporting period.

Major modification work which was underway during this reporting period includes:

1. LPCI modification (L1845) - completed installation and testing of Loop I Motor-Generator sets. Loop II terminations and testing are scheduled during the next reporting period.

2. Install raw cooling water pump and strainers (P0214) - strainers and pump have been placed and minor piping and electrical work remains.

3. Replace GE 22H 0 Analyzer Conduit and Cable (L2079) - piping work was approximately 60% complete and electrical approximately 90% complete.

Other areas of outage involvement include:

1. Limited turbine floor work because turbine disassembly was deferred until the next outage. The principal effort has been with reactor water feed pumps, oil pumps, and associated refurbishment.

2. Eddy current inspections of selected heat exchanger tubes and subsequent repairs as required has been completed.

3. Main steam relief valve removal for off-site testing and repairs. These valves have been reinstalled in preparation for RPV hydro testing.

4. Main steam isolation valve testing revealed seven (of eight total) valves required repairs. The repairs were performed l and the valves are being returned for functional testing.

l i

l l

35 -.

OUTAGE

SUMMARY

(Continued)

December 1980 Schedule Remarks The refuel floor activities, which are critical path, have been on schedule when assessed per the revised 46 day outage schedule. Currently i the expected return to service date for Unit 3 is January 9, 1981. Factors which may affect this date are H22 0 m dification work, scram discharge 1

header UT devices (P0367) and CCW inlet tunnel joint repairs.

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