ML20052G187

Monthly Operating Repts for Mar 1982

ML20052G187
Person / Time
Site:	Browns Ferry
Issue date:	04/01/1982
From:	Bynum J, Thom T TENNESSEE VALLEY AUTHORITY
To:
Shared Package
ML20052G181	List: ML20052G180 ML20052G187
References
NUDOCS 8205140387
Download: ML20052G187 (39)

Text

4 TENNESSEE VALLEY AUTHORITY DIVISION'0F POWER PRODUCTION i

BROWNS FERRY NUCLEAR PLANT i

MONTHLY OPERATING REPORT March 1, 1982 - March 31, 1982 i

! DOCKET NUMBERS 50-259, 50-260, AND 50-296 LICENSE NUMBERS DPR-33, OPR-52, AND DPR-68 i

Submitted By: ~

Tant Super (/intendent 8205140387 820409 DR ADOCK 05000 u .. . .

__ _ _ __. .2_

TABLE OF CONTENTS Operations Sumary . . . . . . . . . . . . . . . . . . . 1 Refueling Information . . . .. .......... 3

-Significant Operational Events ...........

5 Average Daily Unit Power Level . ............. 15 Operating Data Reports . . . . . . . . . . . . . . . . . . . . 18 Unit Shutdowns and Power Reductions. . . . . . . . . . . . . . 21 Plant Maintenance ...................... 25 Fi eld Services Sumary . . . . . . . . . . . . . . . . . . . . 38 5

i . . . . . . . .

1 Operations Summary March 1982 q

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

There were four reportable occurrences and no revisions to previous i

reportable occurrences reported to NRC during the month of March.

Unit 1 There were five scrams on the unit during the month. On March 9, the reactor scrammed due to a turbine trip caused by the loss of hydraulic control fluid pressure which occurred when a check valve in the EHC pump discharge .

was erroneously unbolted while maintenance personnel were changing out the EHC filters. The reactor scrammed on March 14 because of a MSIV isolation caused by a false main steam line low-pressure signal due to high-pressure steam in-duced vibration. On March 15, the reactor scrammed because of a false high.

reactor water level signal which was most likely caused by maintenance personnel performing an instruction. The reactor was manually scrammed on March 20, for a drywell entry to locate and repair an unidentified leak in the drywell. On March 25, the reactor was manually scrammed when an EHC oil leak ca a supply line to the servo valve for a turbine control valve caused a rapid decrease in the EHC oil tank level.

Unit 2

.t There were no scrams on the unit during the month.

Unit 3 The unit was in its E0C-4 refueling outage the entire month.

2 Operations Summary (Continued)

March 1982 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 0.00545 , 0.00432 0.00373 Feedwater nozzle 0.26253 0.18768 0.14166 Closure studs 0.21287 0.14460 0.12339 NOTE: This accumulated monthly information satisfies Technical Specification Section 6.6. A.17.B(3) reporting requirements.

Common System Approximately 1.33E+06 gallons of waste liquids were discharged containing approximately 2.12E+00 curies of activities.

l 1

-S

4 3.

Operations' Summary-(Continued)

March 1982 Refueling Information Unit 1 Unit 1 is scheduled for its fifth refueling beginning on or about March 4, 1983, with a scheduled restart date of June 3, 1983. This refueling will involve loading 8 X 8 R (retrofit) fuel assemblies into the core; finishing the torus modification; turbine inspection; finishing TMI-2 modifications;-

post-accident sampling facility tie-ins; core spray changeout; and changeout of jet pump hold-down beams.

There are 764 fuel assemblies in the reactor vessel. The spent fuel storage pool presently contains 260 E0C-4 fuel assemblies; 232 EOC-3 fuel assemblies; 156 E0C-2 fuel assemblies; and 168 E0C-1 fuel assemblies. The present capacity is 1,148 locations. Modification work and testing is in progress to increase the spent fuel pool capacity to 3,471 assemblies.

Unit 2 Unit 2 is scheduled for its fourth refueling beginning on or about July 30, 1982 with a scheduled restart date of January 1, 1983. This refueling outage will involve completing relief valve modifications; torus modifications; "A" low-pressure turbine inspection: generator inspection; MG set installation for LPCI modification; loading additional 8 X 8 fuel assemblies into the core; TMI-2 modifications; post-accident samplins 7acility tie-ins, and changeout of jet pumr 'ald-down beams. .

There are 764 fuel assemblies in the reactor vessel. At the end of the month there were 353 E0C-3 fuel assemblies; 156 E0C-2 fuel assemblies; and 132 E0C-1 fuel assemblies in the spent storage pool. The present available storage capacity of the spent fuel pool is 160 locations. With present capacity the

4 Operations Summary (Continued)

March 1982 Refueling Information (Continued) l Unit 2 (Continued) 1979 refueling was the 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, 949 new high-density storage locations have been installed and can be used after they are qualified.

Unit 3 Unit 3 began its fourth refueling on October 30, 1981 with a scheduled restart date of April 8, 1982. This refueling involves loading additional

• 8 X 8 R (retrofit) assemblies into the core; relief valve modification; tur-bine inspection; generator breaker and unit station trnqsfonner tie-in; and torus modifications.

There are 764 fuel assemblies presently in the reactor vessel. There are 288 E0C-4 fuel assemblies; 124 E0C-3 fuel assemblies; 144 E0C-2 fuel assemblies; and 208 EOC-1 fuel assemblies in the spent fuel storage pool. The present available capacity of the spent fuel pool is 985 locations.

5 Significant Operational Events Unit 1 Date Time Event 3/01/82 0001 Unit 1 remains offline to replace leaking solenoid valve on core spray testable check valve 75-26.

3/02/82 .0040 Commenced rod withdrawal for startup.

0216 Reactor Critical No.168. '

0415 Rolled T/G. -

0500 Synchronized generator, commenced power ascension.

1730 Commenced,PCIOMR from 83% thermal power (Sequence "A").

3/03/82 1300 Reactor thermal power _ at 98%, maximum flow, rod limited.

1600 Reactor thermal power at 97%, maximum flow, rod limited.

1800 Reactor thermal power at 96%, maximum flow, rod limited. "

2000 Reactor thermal power at 95%, maximum flow, rod limited.

2300 Reactor thermal power at 94%, maximum flow, rod limited.

3/04/82 0007 Commenced reducing thermal power for' control rod pattern adjustment.

0100 Reactor thermal power at 68%, control rod pattern -

adjustment in progress. .

I 0142 Commenced rod withdrawal and increasing flow for control rod pattern adjustment.

0930 Control rod pattern adjustment complete, commenced PCIOMR from 89% thermal power. <

1745 Reactor thermal power at 99%, maximum flow, rod l limited.

'1808 Reduced thermal power to 97% for flux shaping and to bring "R" factor in limits.

3/05/82 0100 "R" factor back in limits, commenced power ascension.

0630 Reactor thermal power at 99%, maximum flow, rod limited.

3/06/82 2200 Commenced reducing thermal power for turbine control valve tests and SI's. '

2225 Reactor thermal power at 93%, holding for turbine control valve tests and SI's.

2240 Turbine control valve tests and SI's complete, hold-ing for control rod pattern adjustment.

2325 Commenced reducing thermal power for control rod pattern adjustment.

s e a me -m**

6 Significant Operational Events Unit 1 Date Time Event-3/07/82 0100 Reacter thermal power at 77%, holding for control rod pattern adjustment.

0130 Control rod pattern adjustment complete, commenced power ascension.

~ 0400 Commenced PCIOMR'from 95% thermal power (Sequence "A").

0800 Reactor thermal power at 99%, maximum flow, rod limited.

0855 Commenced reducing thermal power from 99% for con-trol rod pattern adjustment.

1100 Reactor thermal power at 75%, holding for control rod pattern adjustment.

1210 Control rod pattern adjustment complete, commenced power ascension.

1330 Commenced PCIOMR from 90% thermal power (Sequence

_ "A"). a 2100 Reactor thermal power at 99%, maximum flow, rod limited.

3/08/82 1622 Commenced reducing thermal power due to 1/4 isola-tion signal on "B" main steam line low pressure.

1800 Reactor thermal power at 98%, holding due to 1/4 isolation signal.on main steam line "B" low pressure.

3/09/82 0001 Commenced power ascension from 98% thermal power.

0100 Reactor thermal power at 99%, maximum flow, rod limited.

0940 Reactor Scram No. 149(I) from 99% thermal power on turbine trip from loss of EHC oil pressure. EHC oil pressure was lost when a check valve in the EHC pump discharge was erroneously unbolted while maintenance men were changing out the oil filters.

2245 Commenced rod withdrawal for startup.

3/10/82 0150 Reactor Critical No. 169.

0516 Rolled T/G.

0542 Synchronized generator, commenced power ascension.

2000 Commenced PCIOMR from 74% thermal power (Sequence "B").

• 3/11/82 2200 Reactor thermal power at 97%, maximum flow, rod limitai.

3/12/82 1000 Reactor thermal power at 96%, maximum flow, rod limited.

1400 Reactor thermal power at 95%, maximum flow, rod limited.

7 Significant Operational Events Unit 1 Date Time Event -

3/12/82 2200 Reactor thermal power at 94%, maximum ficw, rod limited.

2330 Comenced reducing thermal powt e for control rod pattern adjustment and SI's.

3/13/82 0100 Reactor thermal power at 69%, holding for control rod pattern adjustment and SI's.

0330 Control rod pattern adjustment and SI's complete, commenced power ascension.

0630 Commenced PCIOMR from 82% thermal power (Sequence "B").

2300 Reactor thermal power at 99%, maximum flow, rod limited.

3/14/82 0703 Reactor Scram No. 150(2) from 99% thermal power.

Indications are that the trip was due to false ,

indication of steam line low pressure.

1446 Commenced rod withdrawal for startup.

1825 Reactor Critical No.170.

2015 Rolled T/G.

2030 Synchronized generator, commenced power ascension.

3/15/82 0330 Commenced PCIOMR from 89% thermal power (Sequence "B").

0455 Reduced thermal power from 91% to 89%, holding for control rod pattern adjustment.

1135 Commenced PCIOMR from 89% thermal power (Sequence "B").

1313 Reactor Scram No.151(3) from 91% thermal power on reactor high water level indication. It is sus-pected that the scram was due to personnel error

, while maintenance personnel were performing SI 4.2.B-69.

2043 Commenced rod withdrawal for startup.

2247 Reactor Critical No.171. ,

3/16/82 0109 Synchronized generator, commenced power ascension.

0703 Commenced PCIOMR from 80% thermal power (Sequence "B").

1730 Stopped PCIOMR at 89%, reducing thermal power for .,

removal of "B" string high pressure heater from service for maintenance on "Bl" moisture separator drain pump regulator valve 6-73A.

2030 "B" string high pressure heaters out of service for maintenance, reactor thermal power holding at 86%.

)

= ------------- - - - - - - - - - -

~

8 Significant Operational Events Unit 1 Date Time Event 3/17/82 0050 Commenced power ascension from 86% thermal power, "B" string high pressure heaters remain out of  ;

service.

0400 Reactor thermal power at 94%, maximum flow, "B"

~

string high pressure heaters out of service.

2400 Reactor thermal power at 90%, maximum flow, "B" string high pressure heaters out of service.

3/18/82 0200 Conmenced reducing thermal power from 90% to l shutdown when chemistry samples revealed the SLC storage tank was outside technical specification limits on sodium pentaborate concentration.  !

0512 Control rod pattern adjustment in progress, power reduction continues for SLC problem.

0645 Stopped reducing thermal power at 67%, SLC con-

_ centration back in limits, commenced power ascension. .

1240 Commenced PCIOMR from 80% thermal power (Sequence "B").

2125 Commenced reducing thermal power from 90% for placing "B" string high pressure heaters in ser-vice.

3/19/82 0015 "B" string high pressure heaters placed in service, commenced power ascension from 79% thermal power.

0115 Commenced PCIOMR from 86% thermal power (Sequence "B").

1700 Reactor thermal power at 96%, maximum flow, rod limited.

2200 Reactor thermal power at 95%, maximum flow, rod limited.

2345 Commenced reducing thermal power for turbine con-trol valve tests and SI's.

3/20/82 0100 Reactor thermal power at 87%, holding for turbine control valve tests and SI's.

0130 Turbine control zalve tests and SI's complete, commenced PCIOMR (Sequence "B").

l 0910 Commenced reducing thermal power from 96% for 1119 shutdown due to high drywell[gidentified leakage.

Reactor Scram Manual No. 152 from 40% thermal power to investigate high drywell leakage. In- -

spection of drywell revealed that a vent line on valve 1-69-1 was broken resulting in the excess drywell leakage. The unit will remain offline for a small piping inspection, repairs to 69-1 limit switches, repairs to IRM "B" and repairs to a leak on the feedwater heater line in the moisture separator room.

9 Significant Operational Events Unit 1

^

Date Time Event 3/21/32 0450 Reactor in cold shutdown.

2000 Maintenance complete on vent line valve 1-69-1.

3/22/82 0010 Maintenance complete on feedwater heater line.

0430 Unit remains offline due to problems with rod sequence control system, and limit switch for 1-69-1 valve.

1100 Maintenance complete on limit switches for 1-69-1 valve. -

2130 Problems with IRM "B" unresolved (will repair during next outage).

3/23/82 0830 Commenced rod withdrawal for startup.

0925 Reactor Critical No.172.

1945 Rolled T/G.

2013 Synchronized generator, commenced power ascension. .

3/24/82 1430 Commenced PCIOMR from 73% thermal power (Sequence "B").

2130 Commenced reducing thermal power from 84% to shut-down due to an EHC leak on control valve servo valve.

3/25/82 0002 Reactor Scram Manual N0. 153 from 66% thermal power for repair to EHC leak on control valve servo valve.

0358 Maintenance complete on servo valve, commenced rod withdrawal for startup.

0559 Reactor Critical No. 173.

0818 Rolled T/G.

0833 Synchronized generator, commenced power ascension.

1630 Commenced PCIOMR from 86% thermal power (Sequence "B").

1900 Reduced thermal power from 96% to 73% for control rod pattern adjustment.

2030 Control rod pattern adjustment complete, commenced power ascensicn.

2130 Commenced PCIOMR from 84% thermal power (Sequence "B").

l 3/26/82 0530 Reactor thermal power at 90%, maximum flow, rod 4 limited.

0800 Reactor thermal power at 89%, maximum flow, rod limited.

1000 Reactor thermal power at 88%, maximum flow, rod

limited.

1300 Reactor thermal power at 87%, maximum flow, rod limited.

l A *we ~.

10-Signif' cant Operational Events Unit 1

'Date Time Event.

3/26/82 -1600 Reactor thermal power at 86%, maximum flow, rod limited.

1715 Comenced withdrawing control rods for control rod pattern adjustment.

~ 1800 Reactor thermal power at 96%, maximum flow', rod limited.

2230 Comenced reducing thermal power for control rod pattern adjustment and turbine control valve tests and SI's.'

3/27/82 0037 Turbine control valve tests complete, reactor power at 66%, commenced increase for control rod pattern adjustment.

0700 Control rod pattern adjustment complete, holding at 80% thermal power for testing of no. 2 bus.

. (Load limited while testing 500 kV offsite power). .

1545 Comenced PCIOMR from 80% thermal power (Sequence aa"),

2045 "A" recirculation pump tripped from 88% thermal power reducing thermal power to 54%.

2015 "A" recirculation pump in service, commenced power ascension.

2200 Commenced PCIOMR from 79% thermal power (Sequence "B").

3/28/82 1530 Reactor thermal power at 96%, MSL pressure switches limited.

3/30/82 1012 Commenced power ascension from 96% thermal power.

1320 Reactor thermal power at 99%, maximum flow, rod limited.

3/31/82 1415 Commenced reducing thermal power for vibration test on main steam line low pressure switches.

1900 Reactor thermal power at 93% for vibration tests on MSL low pressure switches.

1930 Vibration testing on MSL low pressure switches complete, comenced power ascension.

2000 Commenced PCIOMR from 97% thermal power (Sequence "B"). s 2015 Reduced thermal power from 97% to 96% for main-tenance on "Cl" heater level transmitter.

2l00 Comenced PCIOMR from 96% thermal power (Sequence "B").

2400 Reactor thermal power at 98%, PCIOMR in progress (Sequence "B").

11 Significant Operational Events Unit 2 Date Time Event 3/01/82 0001 Reactor thermal power at 99%, maximum flow, rod limited.

3/05/82 2150 Reduced thermal power to 92% for turbine control valve tests. .

2240 Turbine control valve test complete, reducing thermal power for recirculation pump MG set brush-replacement.

2335 Reactor thermal power at 50%, holding for _ recir-culation pump MG set brush replacement.

3/06/82 0228 Recirculation pump.MG set brush replacement com-plete, commenced power ascension.

0430 Commenced PCIOMR from 76% thermal power (Sequence "A").

- 2100 Reactor thermal power at 99%, maximum flow, rod

• limited.

3/07/82 0130 Reduced thermal power to 91% for control rod pattern adjustment.

0147 Control rod pattern adjustment complete, commenced power ascension.

0300 Reactor thermal power at 99%, maximum flow, rod limited.

0840 Reduced thermal power to 98% for control rod pattern adjustment.

0942 Control rod pattern adjustment complete, commenced PCIOMR (Sequence "A").

1030 Reactor thermal power at 99%, maximum flow, rod limited.

3/10/82 1645 Reduced thermal power to 97% for control rod pattern adjustment.

1647 Withdrawing control rods for control rod pattern adjustment. -

1900 Reactor thermal power at 99%, maximum flow, rod limited.

3/13/82 0110 Commenced reducing thermal power for turbine con-trol valve tests and SI's.

• 0130 Reactor thermal power at 86%, holding for turbine control valve tests and SI's.

0137 Turbine control valve tests complete, reducing thermal power for SI 4.1.A.ll (MSIV functional) and SI 4.7.D.l.b-2 (MSIV full closure).

0300 Reactor thermal power at 68%, holding for SI's.

0350 SI 4.1.A.ll and ST 4.7.D.1.b-2 completed, commenced power ascension.

12 Significant Operational Events Unit 2 Date Time Event- ~

3/13/82 0700 Reactor thermal power at 99%, maximum flow, rod limited.

3/16/82 1855 Comenced reducing thermal power for removal of "A" condensate booster pump from service for maintenance on oil lines. -

1920 Reactor thermal power at 82%, holding for "A" condensate booster pump maintenance.

3 2355 "A" condensate booster pump returned to service, commenced power ascension.

3/17/82 0100 Reactor thermal power at'99%, maximum flow, rod limited.

1045 Commenced reducing thermal power for maintenance on "A" condensate booster pump oil line.

~

1300 Reactor thermal power at 72%, holding for mainte- .

nance on "A" condensate booster pump oil line.

1340 "A" condensate booster pump returned to service, commenced power ascension.

1430 Commenced PCIOMR from 95% thermal power (Sequence.

"A").

1600 Reactor thermal power at 99%, maximum flow, rod limited.

3/20/82 0130 Reduced thermal power to 73% for control rod pattern adjustment.

0330 Control rod pattern adjustment complete, commenced power ascension.

0430 Commenced PCIOMR from 91% thermal power (Sequence "A").

1000 Reactor thermal power at 99%, maximum flow, rod

. limited.

3/24/82 2140 Commenced reducing thermal power for testing of No. 2 buss (load Jimited while testing 500-kV offsite power with only three lines available).

2300 Reactor thermal power at 82%, holding for testing of No. 2 bus.

3/25/82 0015 No. 2 bus testing complete, commenced power ascension, 0200 Reactor thermal power at 99%, maximum flow, rod limited.

1016 Commenced reducing thermal power for testing of No. 2 bus.

1200 Reactor power at 88%, holding for testing of No.

2 bus.

1300 Commenced power ascension from 88% thermal power.

. 1400 Reactor thermal power at 99%, maximum flow, rod limited.

. .13 Significant Operational Events Unit 2 i- '

. Date Time ' Event' 1~ 3/27/82 0305 Commence' d reducing-thermal power for turbine i-control valve tests and SI's.

0342 Reactor thermal power at-74%, holding for turbine controlLvalve tests-and SI's.

~0535 Turbine control-valve tests and SI's complete, 1

+

reducing thermal power for testin'g of No. 2 bus. '

0700 Reactor thermal power at 68%, holding for-testing-of No. 2; bus.

1440 Commenced power ascension from 68% thermal power.

1445 Reactor thermal' power at 76%, holding for testing of No. 2 bus.

1550 Commenced power ascension from 76% thermal power.

2000 Reactor thermal power _at-99%, maximum flow, rod limited.

_- 3/29/82. 1200 ' Reactor thermal power at'99%, maximum flow, E0C-4 .

coastdown begins.

3/30/82 0001 < Reactor thermal power at 98%, maximum flow, E0C-4 3 coastdown.

t.

I-3/31/82 0700 Reactor thermal power at 97%,' maximum flow, E0C-4 coastdown.

2400 Reactor thermal power at 97%, maximum flow,'E0C-4'

, coastdown.-

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'14

- Significant Operational Events

. Unit 3

. Date Time Event

- 3/01/82 0001 End of Cycle 4 refuel outage continues.

' 3/31/82 . 2400 End of Cycle 4 refuel outage continues.

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15 AVERAGE DAILY UNIT POWER LEVEL DOCKET NO. 50-259 UNIT Browns Ferry - 1 DATE 4-1-82 COMPLETED BY d.Thom TELEPflONE 205 729 6846 MONTH March 1982 DAY AVERAGE DAILY POWER LEVEL I AY AVERAGE DAILY POWER LEVEL (MWe-Net) (MWe Net!

, -14 986 37 2 547 846 18 3

1017 991 19 4 980 445 20 5 1071 -15 21 6

1050 -15 22 7 986 59 23 g 1063 703 24 9 422 489 25 10 524 932 26 11 945 823 27 12 1026 '

13 919 1019

- 29 14 365 1051

. 30 15 510 1041 31 -

16 785

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INSTRUCTIONS

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, , ,tngry Browns Ferry N .

, 'DdTE 4-1-82

- a '

COMPLETED IlY T. Thom s f' J ELEPHONE a 205 729'6846

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MONTil March _

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. AVERAGE DAILY P, MER LEVEL DAY AVERAGE DAILY POWER LF. VEL

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17 AVERAGE Dally UNIT POWER LEVEL s

d DOCKET NO. _ 50-296

+-

UNIT Browns Ferry -3

, D ATE 4 1-82 ~

COMPLETED llY 'T. Thom 4

• TELEPilONE 205 729 6846 k, c,7 MONTil MdECh; DAY AVER AGYDAILY YO%ER LEVEL U O*

g y we.Seg A\ ERAGE D tlLY POhER LEVEL (MWe Net) 1

-8 17 -8

'8 18 _g 3

-8 -8 19 4 20 .g ,

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-8 21 -9 h '

6

-8 -10 22 7 -8 23 -10 s -8 -10 24 9 -8 -10 25 to -8 -11 26 ii

-8 -12 27 12 -8 28 -12 r3

-8 -12 29 34

-8 -11 30 j -8 -

'3: -12 i3

-8 -

s INSTRUCTIONS Oii this Iornut,in: the iset ige 'la:l> nnit power lesel in Mwe.Nel foi cach dJF in slee seporting in..nih. c.,inpute to the nearest winile nxp .,ig, l'8/771

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18 OPERATING DATA REPORT DOCKET NO.

50-259 DATE ~4- 3-02 COMPLETED BY T. Thom TELEPil0NE 205 729 6846 OPERATING STATUS

- Browns Ferry - 1 Nat'5

~

1. Unit Name:

2. Reporting Period: ' March 1982 .

3. Licensed Thennal Power (Mht): 3293

4. Nameplate Rating (Gross MWe): 1152

5. Design Electrical Rating (Net MWe): 1065

6. Maximum Dependable Capacity (Grow MWe): 1098.4

7. Maximum Dependable Capacity (Net MWe): 1065

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

NA

9. Power Lesel To Which Re>tricted. lf Any (Net MWe): NA

10. Reasons For Restrictions.lf Any: NA Tiiis Month Yr.-to Date Cumulatise

11. Ilours in Reporting Period 744 2,160 67,202 '

12. Number OfIlours Reictor Was Critical 604.58 1,929.45 41,244.25

13. Reactor Resesse Shutdown llours 139.42 182.15 5,397.35

14. Ilours Generator On Line 580.17 1,898.85 40,329.02

15. Unit Resene Shutdown llours 0 0 0

16. Gron Thermal Energy Generated (MWil) 1,763,647 5,978,649 112,853,556 .

17. Grou Electrical Energy Generated (MWil) 556 2420 1,943,970 37,236,420

18. Net Electrical Energy Generated (MWil) 540,3T5_,, 1,893,475 36,162,384

19. Unit Senice Factor 78.0 87.9 60.0

20. Unit Asailability Factor 78.0 87.9 60.0

21. Unit Capacitv Factor IUsing MDC Neti 68.2 __

82.3 50.5

22. Unit Capacity Factor (U>ing DER Net) 68.2 82.3 50.5

23. Unii Forced Ontage Rate 22.0 12.1 26.5

24. Shutdowns Schedultd Oser Nest 6 Months IType. Date,and Duration of Fach t:

's

25. If Shut Down At 1.nd Of Report Period. Estimated Date of Startup:

26. Units in fest Stains (Prior to Commercial Operationi: Forecast Achiesed INITI \ L Cill TICA LITY INITi \ L ELEClltR'ITY

, CO\l\lERCl \L OPI R A TION (9/77) l l

. .D

19

~

OPERATING DATA REPORT DOCKET'NO. 50-260 DATE 4-1-82 COMPLETED BY _T. Thom TELEPIIONE 205 Z21.5846 OPERATING STATUS

1. Unit Name: . Browns Ferry - 2 Notes

2. Reporting Period: March 1982 -

3. Licensed Thermal Power (MWt): 3293

4. Nameplate Rating (Gross alWe): lIO2

5. Design Electrical Ratiag(Net MWe): 1065 -

6. 51asimum Dependable Capacity (Gross MWe): 1098.4

7. Maximum Dependable Capacity (Net MWe): 1065

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

NA

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

10. Reasons For Restrictions.If Any: NA This Month Yr. to Date Cumulative I1. Ilour . In Reporting Period '744 2,160 62,143 '

12. Number Of flours Reactor Was Critical 744 1,993.78 40,440.74

13. Reactor Reserve Shutdown flours 0 157.72 '-- 13,639.48

14. Ilours Generator On-Line 744 1,938.38 39,135.47

15. Unit Resene Shutdown flours 0 0 -0

16. Gross The: mal Energy Generated (MWil) 2,337,365 6,184,740 112,837.530 .

17. Gross Electrical Energy Generated (Mull) 806,430,,,

~

2,088,710 37,521,358

18. Net Electrical Energy Generated (MWil) 7f8,7fl 2,038,582 36,460,728 ,

89.7 63.0

19. Unit Senice Factor 100

~

20. Unit Availability Factor 100 89.7 63.0

21. Unit Capacity Factor (Using MDC Net) 99.5 ~ 88.6 55.1

22. Unit Capacity Factor (Using DER Neti 99.5 88.6 55.1

23. Unit Forced Outagc Rate 0 10.3 28.4

24. Shutdowns Scheduled Oscr Next 6 Months (Type.Date.and Duration of Each):

August 1982 - Refuel and modifications. ..

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

26. Units in Test Status IPrior to Commercial Operation): Forecast Achiesed INITIA L CRITICA LITY INITIA L ELECT RICITY COM\lERCIAL OPER ATION (9/77) u -

._ .1

c 20

~

OPERATING DATA REPORT

~

DOCKET NO. 50-296 DATE 4-1-82 COMPLETED BY T. Thom TELEPl!ONE 205 729 6846 OPERATING STATUS I. Unit Name: . Browns Ferry -3 N8'*5

2. Reporting Peric.i: March 1982 -

3. Licens<d Thermal Power (MWt):

3293

4. Nameplate Rating (Gross MWe): 1152

5. Design Electrical Rating (Net MWe): 1065

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

7. Maximum Dependable Capacity (Net MWe): 1065

8. If Changes Occur in Capacity Ratings (items Number 3 Thrcugh 7) Since Last Report. Give Reasons:

NA NA

9. Power Level To Which Restricted,If Anyget MWe):

10. Reasons For Restrictions,if Any:

This Month Yr..to.Date Cumulative

11. Ilours In Reporting Period 744 2,160 44,568 '

12. Number Of Ilours Reactor Was Critical 0 0 32,466.98

13. Reactor Reserve Shutdown ifours 0 0 2,141.53 I4. Ilours Generator On Line 0 0 31.750.78

15. Unit Reserve Shutdown llours 0 0 0

16. Cross Thermal Energy Generated (MWil) 0 0 93.858.620 -

17. Gross Electrical Energy Generated (MWil) 0 _ _ _ ,

0 - 30.998.190

18. Net Electrical Energy Generated (MWil) 0 0 30,088,046

19. Unit Sersice Factor 0 0 71.2

20. Unit Availability Factor O t0 71.2

21. Unit Capacity Factor (Using MDC Net) 0 - 0 63.4

22. Unit Capacity Factor (Using DER Net)

- 0 0 63.4

23. Unit Forced Outage Rate 0 0 9.2

24. Shutdowns Scheduled Oser Next 6 Months (Type. Date.and Duration of Eachi. ,

a l

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

26. Units In Test Status (Prior to Commercial Operation): Forecast Achiesed INITIA L CRITICA LITY INITI Al. ELECTRICITY COM\lERCI A L OPER A TION (9/77)

. . . . . .. . . . n

.c -

i o ,

DOCKET NO. 50-259 UNITSilUTDOWNS AND POWER REDUCTIONS Browns Ferry -1 UNIT NAME ~

4-I-82 t DATE March COMPLETED BY T. Thom  !

REPORT MONTII TELEPilONE 205 729 6846  :

n.

-  ? E jg 3 4Il Licensee ,E-r, Evt . Cause A Corrective No. Date H

g ~, p 5 jg5 Event gy mV s.? Action to 35 E j di Report e j' Prevent Recurrence C

203 3-01-82 F 29.00 A 2 Reactor scram continues for maintenance on core spray testable check valve 1-75-26 204 3-04-82 S H Derated for control. rod pattern ad-justment 205 3-06-82 S H Derated for control rod pattern ad-Ju:,tment D3 206 3-07-82 S H Derated for control rod pattern ad-justment 207 3-09-82 F 20.03 G 3 Reactor scram due to loss of EHC oil ,

pressure when maintenance personnel g were attempting to change EHC oil filter 208 3-12-82 S H Derated for control rod pattern ad-justment and SI's 209 3-14-82 F 13.45 A 3 Reactor scram due to false indication of steam line low pressure.

~

I 2 3 4 F: Forced Reason: Method: Exhibit G -Instructions ,

S: Scheduled A Equipment Failure (Explain) 1 Manual for Preparation of Data ILMaintenance of Test 2 Manual Scram. Entr> Sheets for Licensee C-Refueling 3 Automatic Scram. Event Report (LER) File tNUREG.

D Regulatory Restriction 4-Other (Explain) - 0161)

E-Operator Training & License Examination F Administrati.e' 5 G-Operational Error (Explain) Exhibit I - Same Source (9/77) ll-Other (Explain) i' W

e

t e .

DOCKET NO.

50-259 f UNIT SilUTDOWNS AND POWER REl I'CTIONS Browns Ferry - 1 Cont.!

UNIT NAME DATE 4-I-82  !

COMPLETED BY T. Thmt REPORT MONTil March TELEPilONE . 205 729 684Q_

r.

E E jE 3 $Yi

,@ j $

Licensee ,E r, K Cause A Corrective Action to No. Date i 3g 4 Event 37 E- ?

H f~ $ j ;ji Report = mV y' Prevent Recurrence c

210 3-15-82 F 11.93 G 3 Reactor scram on reactor high water level when maintenance personnel were performing SI 4.2.B-69.-.

211 3-18-82 F D Derated because sodium pentaborate concentration was out of technical specifications.

212 3-20-82 F 80.90 A 2 Reactor scram when vent line on valve 1-69-1 broke causing high drywell leakage.

213 3-25-82 F 8.52 A 2 Reactor scram to repair leak on EHC'

< control valve servo valve.

214 3-26-82 S H Derated for control rod pattern ad-justment, turbine control valve tests and sis.

215 3-27-82 F A Derated because "A" recirculation pump tripped.

I

~

I 2 3 4 F: Forced Reason: Method: Exhibit G -Instructions S: Scheduled A-Equipment Failure (Explain) 141anual for Preparation of Data B-Maintenance of Test 24f annal Scram. Entry Sheets for Licensee C-Refueling 3 Automatic Scram. Event Report iLER) FileINUREG-D-R?gulatory Restriction 4 Other (Explain) 01611 E Oprator Training & License Examination F-Administrative 5 G-Operational Errur (Explain) Eshibit I- Same Source 19/77) Il~Ot her (E xplain)

?

• t

d t

!=

a 50-260

'l:

UNITSilOTDOWNS AND POWER REDUCTIONS DOCKET NO.

UNIT NAME Browns Ferry - 2 ,

4-l-82 I DATE .

T. Thnm f March COMPLETED BY  ;

REPORT MONTil TELEPilONE 205 729 6846 a,

, .!E 3 .Y Licensee ,Eg o Cause & Corrective No. Date g 3g s ,g s 5 Event g7 g? Action to

$ 5 } di g Report 2r vi V j' Present Recurrence 6

228 3-05-82 S B Derated '.o replace recirculation pump MG set brushes.

229 3-13-82 S B Derated for MSIV functional and full, closure sis.

230 3-17-82 F B Derated for maintenance on "A" con-densate booster pump oil line.

231 3-20-82 S H Derated for control rod pattern ad- to justment.

232 3-27-82 S B Derated for turbine control valve tests and sis.

I I 2 3 4 F: Forced Reason: Method: Exhibit G -Instructions S: Scheduled A Eqmpment Failure (Explain) 1 -Manual for Preparation of Data IbMaintenance of Test 2 Manusi Scram. Entry Sheets for Licensee C Refueling 3 Automatic Scram. Esent Report (LER) File (NUREG-D-Regulator) Restriction 4-Other (Explain) 0161) li Operator Training & License Examination F Administrative 5 G-Operational Error (Explain) Exhibit I - Same Source 1 (9/77) Il-Other (Explain)

I .

9 ,

- . 50-296 d DOCKET NO.  :

UNIT SilUTDOWNS AND POWER REDUCTIONS BrCWDS ferry - 3 i UNIT NAME DATE 4-l-82 l T. Thnm f COMPLETED BY REPORT MONTH March TELEPilONE 704 774 6Ad6 l

s a

n.

• fl *A

, iE s 4sx Licensee ,Eg {% Cause & Co rective  ;

No- Date i 5? 4 is5 Event y mV e- ? At ri.e do

$E $ 55g e

Report 2 u

E' Preven '- .trence O

93 3-01-82 5 744 C 2 Reactor scram to accommodate E0C-4 (Cont) refuel outage ro 4

I

(

l 2 3 4 F: Forced Reason: Method: Exhibit G-Instructisms S: Schedideil A Equipment Failure (Explain) 1-Manual for Preparation of Data Italaintenance of Test 2-Manual Scram. Entry Sheets for Licensee C-Refueling 3 Automitic Soam. Event Report (LER) File INURIL D Regulatory Restriction 4 Other (Explain) 0161i E-Operator Training & Ucense Examination F Administrative 5 G-Operational Error (Explain) Exhibit I Same Source (9/77) Il-Ot her (Explain)

=

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.l BROWNS FERRY EUCLEAR PLAET UNIT 1 & Common CSSC EQUIPMENT ELECTRICAL MAINTENANCE

SUMMARY

For the Month of March 19 82 Effect on Safe Action Taken Nature of Operation of Cause of Results of To Preclude Date System Component Maintenance The Reactor Malfunction Malfunction Recurrence 3/1/82 RHRSW PS-24-134A During the None, redundant Broken wires to PS-24-134A was Re-terminated performance of raw cooling PS-24-134A. inoperable. wires LB96 and SI4.2.B-67 water low pres- LB97 and the SI (RHRSW Initiat- sure logic was successfully ing Logic) PS- (PS-24-134B) completed.

24-134A was was operable. TR #279205 found to be inoperable.

4

'C' Shehr valve None Loose wire One of the two The loose connec-3/2/82 Neutron TIP initiator circuits, tion was repairedo Monitor- machine shear initiator connection in '

ing valve initia- circuit cannon plug. for the 'C' TIP and the TIP re-tor circuitry, inoperable. machine shear valve turned to service.

was inoperable. TR #231743 i

Bell fail to None Loose wire con- Alarm bell on panel Tightened the wire 3/2/82 Diesel Local bell on 25-331 was inoper- connections and Genera- D/G panel alarm during nection at bell.

tors 0-25-331 the perform- able. the alarm bell ance of SI4.11 operated properly.

C.3 & 4 TR #187436 3/10/82 Standby FS-65-20A During SI4.2. None FS65-20A was Flow switches were Calibrated FS 65-Ga s-Trea t- FS-65-42A A.13 the flow out-of-adjust- erratic. 20A and replaced ment FS-65-42B switches were ment and FS 65- FS 65-42 A & B.

erratic. 42A & B were bad, TR #187461 TR #187263 e

'i 1 & Common j BROWNS FERRY NUCLEAR PLANT UNIT CSSC EQUIPMENT ELECTRICAL MAINTENANCE

SUMMARY

March 82 For the Month of 19 l

t i .

Effect on Safe Action Taken '

Nature of Operation of Cause of Results of To Preclude Date System Component Maintenance The Reactor Malfunction Malfun'etion Recurrence 3/16/82 Air Condi- Control bay Purge unit None Fan locked up Control bay chiller Replaced the fan tioning chiller lA. blowing. fuses, due to a broken lA inoperable, and drive belt.

(Cooling- fan blade hung ir The chiller opera-Heating) the drive belt. ted properly.

TR #187285 3/19/82 High- "A" Fire pump The breaker None Bad charging Spring charging Replaced the Pressure feeder breake) spring charg- i, motor. motor operated too charging motor Fire ing motor took slow, and the breaker Protection toolong to operated properly, charge spring '

TR #21357 m on pump start. . ,

3/20/82 Reactor FCV-1-69-1 The valve fail None Torque switch The valve would not Adjusted the Water (to fully close was out of completely seal torque switch per Cleanup on isolation adjustment. closed. EMI-18.

signal. TR #231878 3/20/82 Core Testable Inspection for None Limit switches Indicating lights Adjusted the limit Spray check valve shorted cir- were out-of- were not operating switches and the Cooling- 1-75-26 cuit follow- adjustment. properly. switches operated ing water leak, . properly.

TR #231888 9

e

, i BROWNS FERRY NUCLEAR PLANT UNIT 1 & Common f f

CSSC EQUIPMENT ELECTRICAL MAINTENANCE

SUMMARY

f For the Month of March 19 82 .

4 Effect on Safe Action Taken Nature of Operation of Cause of Results of To Preclude Date System Component Maintenance The Reactor Malfunction Malfun*ction Recurrence 3/20/82 EECW Relay 67BL1 EECW low flow None Burned relay Received a false low Replaced the relay alarm would 67BLl. flow alarm in the per EMI-23, the not clear in control room which alarm circuitry the control would not clear. operated properly, room. TR #231890 3/25/82 CRD LA-085-085A When tested- None Bad annunciator LA-85-85A failed to Replaced the bad LA-85-85A fail- ., circuitry card. illuminate in the card and the ed to illumi- control room. annunciator nate in the operated properly.

control room. ,

TR #21366 m e

o e

'l BROWNS FERRY NUCLEAR PLANT UNIT 2

• ELECTRICAL MAINTENANCE

SUMMARY

CSSC EQUIPMENT For the Month of March 19 82 Effect on Safe Action Taken Nature of Operation of Cause of Results of To Preclude Date System Component Maintenance The Reactor Malfunction Malfun'etion Recurrence FCO-2-64-41 Rx zone exhaust None The position Damper position Adjusted the switch 2/27/82 Rx Bldg.

switch actuator switch was not actuator arm and Heating & position to stendby gas arm was out-of- operating properly. the switch operated Ventila- switch, treatment adjustment. properly.

tion (FCO-64-41) damper position TR #229817 switch was not operating properly.

Unit preferred Bredker inop- None Bad relay and Emergency-feeder Replaced the relay 3/16/82 Unit overcurrent trip breaker inoperable. per EMI-23, Preferred ) DIG set 3 tie able.

replaced the over-120 Volt to battery Bd device.

current tripping m AC 2 emergency -

device and per- 03 feeder break-er.

formed EMI-7.

TR #241512 f

LA2-63-1 would None Loose annunciator LA2-63-1 was inop- Tightened the 3/18/82 SLC (LA 2-63-1) erable on panel 9-5. annunciator card SLC tank level not test, circuitry card, abnormal and the SLC tank level annunciator annunciation circuitry operated circuitry, properly.

TR #20026 l

i BROWNS. FERRY NUCLEAR PLANT UNIT 3

• t CSSC EQUIPMENT ELECTRICAL MAINTENANCE

SUMMARY

For'the Month of March 19 82 Effect on Safe Action Taken Nature of Operation of Cause of Results of To Preclude Date System -Component Maintenance The Reactor Malfunction Malfun'c tion Recurrence 3/3/82 Diesel D/G 3D over- Received false None Loose annuncia- Received a false Tightened the Genera- speed trip alarm in tor circuitry overspeed trip alarm annunciator card tors alarm cir- control room card. in the control room. and the alarm cuitry. which would not operated properly.

clear.- TR #225951 3/13/82 Diesel Rectifier / During the None A lead wire from During performance'of The wire was re-Genera- reactor cir . performance of ,, a reactor in the SI4.9.A.l.b' Diesel lugged and reterm-tors cuitry in the SI4.9.A.l.b remote excita- Generator 3C started inated and the SI RHR* pump'3B tion' cabinet and tied onto 4kV successfully.

D/G 3C remote excitation failed to failed'due to shutdown Bd.3EC. completed. All no cabinet. start, overheating at When RHR 3B pump wiring'in.the the crimp on a breaker closed on reactor compart-lug which con- this' board the diesel ment of the remote nected it to a generator became excitation cabinet rectifier. unstable, the output for Diesel Genera-(

voltage dropped and tors 3A, 3B, 3C, the RHR pump breaker and 3D was inspect-tripped. ed and found to be acceptable.

TR #187267 I

e

. l. :

BROWNS FERRY MUCLEAR PLAWT UNIT 3 CSSC EQUIPMENT ELECTRICAL MAINTENANCE

SUMMARY

For the Month of March 19 82 Effect on Safe Action Taken Nature of ' Operation of Cause of Results of To Preclude Maintenance The Reactor Malfunction Malfuscrion Recurrence i Date Svstem Component Overspeed Overspeed None, unit in The overspeed The overspeed monitor Freed and cleaned 3/18/82 RCIC was initiating a the relay contacts, i monitor, monitor trip. refueling moni' tor relay circuitry outage, contacts welded continous trip signal ,the trip solenoid inoperable. together during operated properly.

actuation. This This event is is a 250-VDC under evaluation.

circuit. It was TR #187302 discovered that l

., the relay con-tacts are rated

- for 29-VDC and is the probable ,,

• C) cause of the contacts welding .

together. -

Overspeed 'A 130 volt None, unit in A resistor in' Overspeed monitor Cleared the 3/22/82 RCIC grounded resistor monitor. negative refueling the overspeed inoperable.

ground was outage, monitor was and the over-indicated. grounded against speed monitor the monitor case. returned to service.

TR #225756 I

1

BROWNS FERRY NUCLEAR PLANT UNIT 3 CSSC EQUIPMENT ELECTRICAL MAINTENANCE

SUMMARY

For the Month of March 19 82 Effect on Safe Action Taken Nature of Operation of Cause of Restilts of To Preclude The Reactor Malfunction Malfunction Recurrence Date System Component Maintenance The overspeed None, unit in Ground in over- Overspeed monitor Replaced the bad 3/29/82 RCIC RCIC over-speed monitor. monitor was refueling speed monitor due inoperable. zenor's and I

inoperable. outage. to bad zenor's capacitor. The and capacitor in monitor operated 250 V DC optional properly.

power circuit. TR'#187360 3B2 Drywell Blower would None The breaker's The breaker would Adjusted the manua:

ti 3/28/82 RBCCW manual trip not close. trip mechanism and blower feeder not start.

the breaker opera-breaker. - mechanism was sticking in the ted properly.

TR.#239322 h3 trip position.

f f During the per- None The limit switch " Position" indicating Adjusted the limit 3/30/82 Core HCV-75-1 lights did not work switch.

Spray limit switch g formance of was out-of-SI3.2.10 hCV- adjustment. properly. TR #25068 Cooling 75-1 limit switch did not operate pro-perly.

g 4

h

BROWNS FERRY NUCLEAR PIANT UNIT 1 MECHANICAL MAINTENANCE

SUMMARY

CSSC EQUIPMENT .

For the Month of March' 19 82 EFFECT ON SAFE ACTION TAKEN NATURE OF OPERATION OF CAUSE OF RESULTS OF TO PRECLUDE MTE SYSTEM COMPONENT 4

MAINTENANCE THE REACTOR MALFUNCTION MALFUNCTION RECURRENCE 3-21 Rx. Fdwtr. Rx. Vessel head Valves need None Worn packing & Packing Leak,- Replaced gasket &

vent valves repacking' gasket pa,cked valves g 3-98, 3-99 TR# 326987 3-22 Main Steam HCV-1-513 Steam Leak None Worn bonnet & Leak found at bonnet Replaced bonnet &

gasket of valve gasket TR# 306677 e

I*

h h

f

J BROWNS FERRY NUCLEAR PLANT UNIT 1 MECHANICAL MAINTEWABCE

SUMMARY

CSSC EOUTPMENT .

For the Month of March' 19 82 EFFECT ON SAFE ACTION TAKEN NATURE OF OPERATION OF CAUSE OF RESULTS OF 70 PRECLUDE InIE SYSTEM COMPONENT MAINTENANCE THE REACTOR MALFUNCTION R\LFUNCTION RECURRENCE Rupture disc None. Rupture dise Personnel Err,or Replaced rupture disc, 3-17 RCIC RCIC. Turbine missing missing (outer) torqued bolts to 1 0 See W.P. 6411 f t'-lbs. .

TR# 338891 None Unknown Unknown Replaced with all 3-17 RCIC RCIC Turbine Bolts missing thread seuds.

TR# 274820 CRD Module 46- Leak None Stem out of Outlet valve leaking Adjusted stem linkage 3-9 CRD TR# 280114.

43 adjustment through lEN LPCI MG Unusual vibr. None Bad gears in Gen.. bearing slinging Replaced gears in - '

2-4 LPCI Set & shaft move- flywheel grease flywheel, ment TR8 281448 w w

CRD Module 34- Leak None Faulty seat disc, Scram discharge' valve Replaced seat disc, 3-9 CRD body gaskets, disc 43 gasket & retainer leaking retainers i TR#_280162 HCV-10-505 Packing Leak None Worn packing Old packing leaking- Repacked valve 3-22 Nuclear-TR# 227426 Boiler Valve back-seated open ,

9 4

k

l. .- . j

--rre--

BROWNS FERRY NUCLEAR PIANT UNIT 2 PfECIIA3ICAL MAINTEEiANCE

SUMMARY

CSSC EQUIPMENT ,

For the Month of March 19 82 EFFECT ON SAFE ACTION TAKEN CAUSE OF RESULTS OF TO PRECLUDE DATE SYSTEM COMPONENT NATURE OF OPERATION OF Tile REACTOR MALFUNCTION MALFUNCTION RECURRENCE MAINTENANCE 1 Overspeed IIPCI None N/A N/A Installed spool piece 3-16 IIPCI IIPCI Turbine , l for test' for overspeed test

~

TR'# 338885 I IIPCI IIPCI Turbine Overspeed test None N/A N/A Removed spool piece

! 3-16 & blanked flanges.

Completion TR# 233112.

e t

e is e

-BROWNS FERRY NUCLEAR PIAhT UNIT 3 MECHANICAL MAINTENANCE

SUMMARY

CSSC EQUIPMENT .

For the Month of March' 19 82 EFFECT ON SAFE ACTION TAKEN NATURE OF OPERATION OF CAUSE OF RESULTS OF 'ID PRECLUDE DATE SYSTEM COMPONENT MAINTENANCE THE REACTOR MALFUNCTION MALFUNCTION RECURRENCE 3-16 Contr. Bay 3A Co,ntrl Bay Valve failed to None Faulty. Valve Will not. allow disch. Installed new ball licat, Vent Chiller Cond. operate press. to meet specs. valve TR# 187432 l

& AC Valve HP Head gasket Leaking Repl. high-pressure 2-11 D/G D/G "A" #2 None Bad high-press.

side head gasket Air Comp. needs replac. head gasket TR# 228000 Cooler B&D Vent Vent Line None Unknown Vent broken off of Resoldered vent to 2-22 Core Spray cooling coil.

Line Broken cooler coil TR# 225884 3-5 CRD Module 38-39 Leak None Faulty adapter Leaking at nut. Changed adapter & -

& nut. nut.

TR# 225954 w w

Stem' Leak Cartridge Valve-

, 3-7 CRD Module 30-43 Leak around None Faulty Valve .

Star Valve star valve installed 85-229 TR# 227627 i

2-27 CRD Cartridge valve Leak None Valve stem Valve Icaking Replaced valve stem CRD hydraulic assembly bad assembly contrl. vent TR# 226031 18-19 .

2-18 CRD CRD module Leak 'None Worn packing Valve packing leaking Repacked Valve 38-15 Valve TR# 225845

+

0 y h

LROWNS FERRY NUCLEAR PIANT UNIT 3 CSSC EOUIPMENT MECllAWICAL MAINTE ENCE SUlGtARY For the Month of March' 19 82 EFFECT ON SAFE ACTION TAKEN SYSTEM COMPONENT NATURE OF OPERATION OF CAUSE OF RESULTS OF TT) PRECLUDE DATE MAINTENANCE Tile REACTOR MALFUNCTION MALFUNCTION RECURRENCE 2-18 CRD Modul,e 38-31 Valve Leaking None Worn Packing Valve packing leaking Repacked valve Valve TR# 225843 I

Packing Leak None Worn Packing Cartridge Valve Pack- Replaced packing 3-30 CRD Star valve on element module 02-31 ing leak TR# 306353

~

3-31 Control 3B Contrl Bay Valve needs None Worn Valve Va5ve non~f'nctional u Replaced with valve Bay lleat Chiller Valve rebuilding from 3-A Vent &AC to condenser TR# 187287 3-19 Control 3B Contrl Bay Valve not oper None Worn Valve Valve nonfunctional Cleaned & rebuilt i, Bay lleat Chiller Conden- properly valve & orifices Vent & AC ser water reg. TR# 326988 valve i m 3-26 CRD Strainer plug Plug leaking None Bad O' ring Strainer Plug leaking Replaced O' ring &

Module 22-19 tightened plug Block Valve TR# 239306 i

4-1 IIPCI l-1/2" flex. Ilose needs to None Flex. hose rup- Leakage Replaced hose metallic hose be replaced tured. TR# 337821 from disch, of the shaft- ,

driven oil pmp.

3-25 RilR 3A RIIR Pump Seal Leaking None Faulty seal Leakage Replaced seal TR# 225759 e

. .. - BROWNS FERRY NUCLEAR PLANT _ UNIT 1, 2 & 3 ..,___ _

INSTRUMENT MAINTENANCE SUM 1ARY CSSC EQUIPMENT FOR, DIE MONBt OF March 19 82

, NATURE EFFECT ON SAFE CAUSE t

MTE SYSTDI CO.PCNENT OF ACTION TAKEN OPERATION OF ,.o OF kiSULTS OF TO PRECLUDE MAINTENANCE THE REACTOR MALFUNCTION MALFUNCTION . RLCURRENCE U-1 * '

3-11 65 FIS-65-70A Repair None Failed Photo Bulb Switch Malfunction None '

3-22 68 FM-68-5 Calibration 1 None Insti. -Drif t Incorrect Output None U-2 , .

3-03 74 FT-74-56 Replace None

~

Natural End of Incorrect Output None 3-24 Life e 71 FT-71-1B Repair None

, Failed Amplifier, Incorrect Output No.ne 3-30 76 FR/PR 76-14 Repain. None Failed Chart Drive Chart Failed To'. None Motor Advance .

tj U-3 '

~

)3-04 75 . FT tS'21 Replace' None Natural End of Incorrect Output None

.g .

Life 3-20 90 PR-90-142 Repair None Failed Amplifier Loss of Indication None s

3

, .- e e *

? -

o i

W 9

i .

l- ,,

38 FIELD SERVICES

SUMMARY

March 1982 The major field services efforts for the month of March were centered .

around completion of the remaining unit 3 end-of-cycle 4 outage work activities, security-related modifications, and preparatory work for unit 2 torus modifi-

~

cations. ,

Unit 3 cycle 4 outage activities progressed on schedule through the end of the month which was day 152 of th'e current 160-day schedule.

All April 1, 1982 security commitments were met.

On March 1,1982 all major modification work for the torus had been com-pleted and only minor work remained to be finished;

1. Inside torus: (a) wiring for vacuum breaker switches.

(b) adjustment of vacuum breakers (c) miscellaneous bolting for handrailing.

(d) replacement of U-bolts for H 0 PIP i "9' (e)paintingtouchupofweldare$sfornewinstalledhatch.

2

2. Outside tours: (a) completion of gussets for tiedowns.

(b) completion of 4 ECCS supports.

(c) weldout of 18 MKII tiedown beams.

(d) installation of pipe hanger for HPCI test line when material certifications are received.

(e) installation-of valve operator #74-150.

During the first week in March all wiring (approximately 8,000 feet) for vacuum break:. witches was pulled, tiedown gussets completed and all ECCS supports. Work continued on MKII tiedown beams with 50 percent complete and paint touchup at welds inside the torus for the new hatch was completed.

By the end of the second week (March 14,1%2) all wiring for vacuum breakers was completed and checked out; bolting for handrails was 100 percent complete, and MKII tiedown beam installation was 100 percent complete. General cleanup and move-out of scaffolds and material from inside the torus continued.

e

= .#' .*e6 a.m b & * '

39 FIELD SERVICES

SUMMARY

(Continued)

March 1982 The following week, strong efforts were made in general cleanup of all torus areas and move-out from inside the torus in preparation of ILRT. In-stallation of valve operator #74-150 was completed in time for ILRT which started on March 19, 1982 and finished on March 22, 1982. The torus hatch was reopened on March 22, 1982, final adjustments on vacuum bre'akers were made, and removal of remaining scaffolding _,

continued in preparation for final torus inspection with divers starting April 1, 1982.

Detailed plans and schedules for unit 2 torus preshutdown work were finalized in the first week of March. As manpower became available from unit 3, setup for tiedown work was made. .

During the first half of March, efforts were made in cleanup and de-contamination at elevation 519 in order to keep it unzoned. Scaffolding was erected to make template measurements of external ring girder reinforcing and setup for work was started with layout for drilling of tiedown anchor bolts. On March 18, 1982 material was received for temporary ECCS supports and the work plan for prefabrication was approved. Fabrication in the shop started immediately.

On March 23, 1982 permission was obtained to start actual modification work, and on March 25, 1982 the first holes for tiedown anchor bolts were drilled at ring girder #15. Drilling continued for the remainder of the month.

By March 31, 1982 drilling was completed for 3 tiedowns,12 torus jacking lugs removed in preparation for new cradle extensions, and 15 of a 16 template measurements for external ring girder reinforcing were complete.

The fabrication shop shipped 11 cradle extensions to the site during March.

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m "m***M* 1_

40 FIELD SERVICES

SUMMARY

(Continued)

March 1982 l

The integrated electrical testing schedule was as follows:

1. The unit station service transformer work (P0275) and associated post modification testing was completed March 12, 1982.

2. The degraded voltage relay modification (P0275A) work and associated post-modification testing was completed March 19', 1982.

3. The 161kV capacitor bank modifications (P0403) capacitor bank 2 were com-pleted as scheduled. Bank 1 modificaton work and post-mcdification testing associated with both capacitor banks was completed March 18, 1982.

4. DPS0 Special Test Instruction STI 8A for making relay functional tests

. for the 500kV switchyard was accomplished to validate the 500kV system

• as an offsite power cource.

~

The procedure was completed by PS0 March 27, 1982.

5. Other work, part of the integrated electrical schedule but 'also part of plant electrical maintenance work, was switchyard power circuit

~

breaker maintenance complete March 4, 1982; backfeed testing complete March 13, 1982; common' acceptance signal logic complete March 8, 1982; and the diesel load acceptance tests were completed March 23, 1982.

Other modi'fication and maintenance work was as follows:

1. Security modification P0487 provides the Wells Fargo Alarm System with tamper indication; P0463 installs the Wells Fargo Alarm System at the RHRSW tunnels; and P0498 installs a balanced magnetic switch, cardreader, and necessary hardware at the intake structure. These modifications were completed

• j prior to the required NRC commitment dates. P0286 illuminates the exterior of the protected area to at least 0.2 footcandles. This modification was completed approximately three weeks prior to the required commitment date.

, The remaining three weeks, prior to April 1, 1982, were spent upgrading the lighting system to meet detailed requirements of the NRC commitment.

4

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41 FIELD SERVICES

SUMMARY

(Continued)

March 1982

2. Completed TIP system maintenance and testing

3. Completed miscellaneous LPRM connector repairs as identified.

4. Made up electrical connections to the existing MSRVs and installed conduit and cabling and made up connections to the two new MSRVs.

5. H022System (P0315/P0361E) - installed necessary conduit and cabling for

-the modification. Installed internal board wiring and made system termina-tions.

6. Dewatering pumps (P0252) - Installation of conduit and cabling necessary for this modification is in progress.

7. Post-Accident Sampling Facility (P0314) - Field Services relocated a light-ing cabinet and associated feeders and loads to facilitate the installation of the wall formwork. The floor slab was poured during the first part of the month.

8. Miscellaneous work - applying Flamemastic to cable trays; setting limits on various valves as required after maintenance; setting limits on drywell blowers; wiring drywell sump pumps; repairing flex conduit as found defective during the drywell closecut inspections; etc.

Field Services Mechenical Activities During the month of March, the mechanical work for the Field Services Group unit 3 cycle 4 refueling outage was winding down significantly. The major work for the outage was primarily complete with the exception of core reload, inter- .

grated leak rate testing and reactor pressure vessel hydro preps and nydro and drywell closecut punchlist items. Two new work items for FSG mechanical was identified in March. These bring P0462 - strongback modification to drywell

, personnel access door (inner) and the addition of a clamp around leaking flange on the RWCU regenerative heat exchangers.

42 FIELD SERVICES

SUMMARY

(Continued)

March 1982 Field Services Mechanical Activities (Continued) -

Core Reload Fuel movement for the core reload started February 27, 1982 and was completed-March 12, 1982.

During fuel movement minor problems were encountered with the air com-pressor, solenoid valve, depth counter, main hoist takeup reel, and grapple lights, all of which delayed fuel movement to some degree.

After completion of fuel load, problems were encountered with fuel- support piece alignment. The fuel cell at position 46-23 was unloaded to check for blade and fuel-support piece alignment. The fuel-support piece was reinstalled and alignment verified. Core verification was completed March 16, 1982 and the fuel pool gates were installed.

Integrated Leak Rate Test Preparation for reactor pressure vessel (RPV) head assembly was started for ILRT. All preparations were completed, and the RPV head and drywell head were set March 18, 1982.

Drywell head torquing and the local leak rate test were completed March 19, 1982. Pressurization for the integrated leak rate test started March 20, 1982 after which containment depressurization was completed. On March 23 the drywell head was removed and the drywell turned over for general access.

Reactor Pressure Vessel Hydrostatic Test

^

The RPV head and associated components were torqued in preparation for reactor pressure vessel hydrostatic test. Pressurization for hydro started March 26, 1982. On March 27, 1982 hydro associated repairs were made and began repressurization. The hydrostatic test was completed at 2120 hours0.0245 days <br />0.589 hours <br />0.00351 weeks <br />8.0666e-4 months <br /> March 27, 1982.

r 43 FIELD SERVICES

SUMMARY

(Continued) F March 1982 Reactor Pressure Vessel Hydrostatic Test (Continued)

The drywell head was set, torqued, and passed LLRT March 28, 1982.

All refuel floor work scheduled for the unit 3 cycle 4 outage was completed March 28, 1982. -

Other Activities __

MSIV. - The "A" inboard MSIV rib guide repair was completed and passed LLRT March 15, 1982. After the initial rib guide repair was made, several iterations of assembly, test, disassemble, and machining was required prior to completing LLRT on March 15, 1982. ,

MSRV Tailpipe Modification - This modification was physically completed in the month of March. The work plan is being processed for final signoff.

Condensers - Work on condensers "A,", "B," and "C" was completed in March and the condensers were closed up.

Probolog - The probolog work was completed this month when the RBCCW "A" and "B" heat exchangers were eddy-current tested. One tube in the "A" heat exchanger required plugging.

ISI S.nubbers - Completed repair / replacement of all drywell snubbers during March.

RWCU Regenerative Heat Exchanger - The flaTge clamp was installed this month on "C" regenerative heat exchanger. As of this writing no leak has been datected.

CRD Rebuild - The CRD rebuild effort was continued during March. Nineteen ,,

rebuilt CRDs are in inventory and will require testing prior to use. Six more remain t be rebuilt.

Strongback Modification - This modification to the drywell personnel access

, door (inner) was completed and the 1.5 pound air test was conducted. 50-pound test will be performed prior to startup.

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FELO SERVICES

SUMMARY

(Conteued)' */ .

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March 1982 .s

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Other Activities (Continued)_. , ', , % '

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- , Turbine + Lempleted the.$,cbpliQgs . . r.

for the. slow pressure y turbine, tpoine s - -

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generator and eic~ iter. C x.r.d. icted the turbine oilyflush, geneN. tor. air.t,est,.

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and installed theglocou(te in the No. 8 bearing. 'StIokedturbjnevalves '

kn hreparation 'f6f startup. Continued erection of permaner pikforms '

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', aroundsthe intercept Valves. '

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' y H02 2 - Complejad relucatien of solenoid vafves and associatedipiping and .

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, 4 clectr,1 cal outside the ~torus. . Comp)eted post-modificati,on test'. -

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ManpoweF utilizatiod;' ~-

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Th'e c0 art below deMcts the field services manpoweF~ut;ilfzation during

~3 ~ .

the fin:st and _last week liiMarch. Note that the decrease in personnel

~

, 7 t

., (principall'ystrades andslat,4or)[was.necessary ,

due to the decreasing unit 3 cycle l'

? N. ,

's ,

4 outage workload.- \

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Total Total

, \ ,

Week.cf ~

Week of N - s 3-3-83 3-24-82 x ~

a

1. (a) Hourly trades and labor 902 741 (b) Annual trades and labor 57 57 Subtotal -

959 798

2. (a) Management . 26 22 (b) Engineers and Aides , J1 41

-(c) Administrative and Clerical 25 , 25 Subtotal 92 88

3. (a) Power Service Shops 45 37 ,

(b) Contractors 33 23 (c) Engineers on loan 31 42 (d) Student aide 1 1 Total 1 and 2 above 1051 886

.45 FIELD SERVICES

SUMMARY

(Continued)

March 1982 Plant Modifications The below listed modifications were completed during the month of March.

. NON-SAFETY-RELATED Package Number Description 0-77-38 (Work Plan 8352) -- Provided a temporary road-P0303- way to the condenser tube pullout area. Placed grating on floor of condenser tube pullout area for stacking of radwaste drums. Provided foundations, . piping, and conduit for relocating existing propane tanks to an isolated area within the switchyard.

The ECN was not completed.

0-77-38 (Work Plan 8358 Rl) -- Relocated existing propane' P0303 storage tanks including existing piping and controls.

3-47-62 (Work Plan 9909) -- Modified and repositioned P0374 the differential expansion detector in the main turbine front standard to achieve acceptable DXD emergency governor clearances.

The ECN was completed for unit 3.

1-47-79 (Work Plan 6425) -- Removed existing silver [

DCR 2208 grounding shoes and their helders on unit 1 main turbine, front standard. Installed. cover plates over the holes where the grounding shoes were removed.

The DCR was completed for unit 1.

SAFETY-RELATED 2-3-82 (Work Plan 6720) -- Built and placed protective P0445 cages on panels25-51B and 25-52B to protect LITS 3-52 and 3-62.

The barriers did not affect the function and/or availability of the equipment or any safety-related equipment. The consequences of an accident or malfunction of safety-related equipment previously evaluated in the FSAR was not increased.

The ECN was completed on unit 2.

, 46 FIELDSERVICES

SUMMARY

(Continued)

March 1982 PlantModifications(bontinued)

/ 1 SAFETY-RELATED Package Number Description 3-433-68' (Work Plan 7909) -- Fabrica,ted and installed the' P0361 -

RCIC turbine exhaust support at catwalk knee-brace RG No. 6.

A very small portion of the work was covered by the ECN was completed.

3-433-68 (Work Plan 7893) -- Prefabricated 11 3/4-inch P0362 elbow reinforcing rings and installed inside the unit 3 torus.

Only a small portion-of the work covered by the ECN was completed.

3-257-13 P0191 (Work Plan 7982) -- Modified computer. software to monitor analog input voltages for each reactor protection system bus and performed post-modification test.

The recorder was seismically qualified and supported so it does not adversely affect safety-related equipment.

The ECN was completed for unit 3.

3-47-52 (Work Plan 7976) -- Mounted potential trans-P0275 former in 4-kV unit board 3C; performed internal

. wiring and spared out cables.

A very smali portion of the work covered by the ECN was acccmplished on this work plan.

2-1-106 (Work Plan 6739) 3-1-96 (Work Plan 7961) -- Work plans written and approved for installation of helicoils in MSIVs' for units 2 and 3. MMI-17 was revised to incor-porate the changes and the work will be done on an as-needed bosis per the MMI.

As the modifications are performed, the replace-ment of the MSIV bonnet stud threads in the valve body will not affect the valve's ability to perform its safety-related functions.

The ECN was completed for units 2 and 3.

47

, FIELD SERVICES

SUMMARY

(Continued)

March 1982

. -Plant Modifications (Continued) b SAFETY-RELATED s

Package Number Description

~

3-47-44 '(Work Plan 7920) -- Installe,d hoses'from air

-P0214 , compressor, cooling plant and control cabinets to the generator breakers in unit 3.

A small portion of the work covered by the ECN y was completed.

3-433-68 (Work Plan -7896) -- Prefabricated internal ring P0360 girder reinforcement at the Power Service Shops P0362 for the unit 3 torus modification.

A very small portion of the work covered by the

• ECN was accomplished.

1-433-19 (Work Plan 10146) -- Changed torus and drywell P0093 differential pressure and level switch set-points for LS-64-54A and B; PDS-64-137A, 1378, and 137C; and PDS-64-138A, B, and C.

A small portion of the work covered by the ECN was completed.

2-68-67 (Work Plan 9512) -- Added various test connections P0224 to the recirculation pump seal water lines between valves68-607 and 508;68-508 and 550;68-552 and b23; and 68-523 and 555 in the unit 2 drywell.

The modification was required to assure compliance

.with NRC requirements. Normal operation of the system was not affected. The test connections meet the same requirements with regard to piping class and seismic status as.the existing gland seal system.

The ECN was completed for unit 2.

1-79-57 (Work Plan 10114) -- Replaced existing fuel DCR CC19 assemblies with P8X8R and fcur lead test assemblies.

The lead test assemblies were installed to test and utilize new fuel design developed to increase cold shutdown margin. The only change to the LTAs relative to the standard reload bundles is the

, o-

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48

. FIELD SERVICES

SUMMARY

(Continued)

March 1982 PlantModifications(Continued)

SAFETY-RELATED Package Number ' Description 1-79-57 (Continued) addition of the short segment of higher godalinia-DCR CC19 concentration. This addition will not change the thermal-mechanical char'acteristics of the-fuel rods or fuel assemblies beyond what has already been analyzed and will have no signifi-cant impact on power operations.

0-236-2 (Work Plan 8516) -- -Prefabricated and installed P0502 above-ground piping for 1C transformer fire protection.

A small portion of the work covered by the ECN

. was accomplished on this work plan.

3-252-4 (Work Plan 9921) -- Changed normal feeder for-P0201 board 9-9, panel 5, from the plant nonpreferred to the unit-preferred bus.

The modification will assure a reliable source of power and one which provides proper circuit breaker coordination. The margin of safety was not reduced.

The ECN was completed for unit 3.

3-47-52 (Work Plan 7877) -- Installed conduit and' P0275 grounding for unit station-service transformer 3B.

A very small portion of the work covered by the ECN was accomplished. l 3-433-54 (Work Plan 7889) -- Installed temporary internal P0093 ventilation for the unit 3 torus modification.

Removed all temporary material installed per this work plan prior to closing work plan for QA '

records.

The ECN was not completed.

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