ML18036B006

Monthly Operating Repts for Jan 1981

ML18036B006
Person / Time
Site:	Browns Ferry
Issue date:	02/10/1981
From:	Thom T TENNESSEE VALLEY AUTHORITY
To:
Shared Package
ML18025B352	List: ML18025B351 ML18036B006
References
NUDOCS 8102170497
Download: ML18036B006 (46)

Text

TENNESSEE VALLEY AUTHORITY DIVISION OF POWER PRODUCTION BROWNS FERRY NUCLEAR PLANT MONTHLY OPERATING REPORT January 1, 1981 January 31, 1981 DOCKET NUMBERS 50-259, 50-260, AND 50-296 LICENSE NUMBERS DPR-33, DPR-52, AND DPR-68 Submitted By:

Plant Manager

~l TABLE OF CONTENTS Operations Summary Refueling Information Significant Operational Events Average Daily Unit Power Level ~ ~ '

Operating Data Reports '18 Unit Shutdowns and Power Reductions. 21 Plant, Maintenance 24 Outage Summary . ~ ~ 35

0 0 erations Summar January 1981 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-two reportable occurrences and one revision to previous occurrences reported to the NRC during the month of January.

Unit 1 There were no scrams on the unit during the month.

Unit 2 There was one scram on the unit during the month. On January 3, the reactor scrammed when the main turbine tripped due to actuation of a breaker failure relay while opening the generator bus tie breaker PCB 5248 for routine maintenance.

Unit 3 There were no scrams on the unit during the month.

O~erations Summary (Continued)

January 1981 Pati ue Usa e Evaluation The cumulative usage, factors for, the Ireactor ~vessel are's follows:

Location Unit 1 Unit 2 Unit 3 Shell at water line 0.00381, 0.00321 0.00497'.24043 Peedwater nozzle 0.16191, 0. 11766 Closure, studs 0.19766 0.13426 0.09916 Note: This accumulated monthly information satisfies technical specification section 6.6.A.17.B(3) reporting requirements~.

Common S stem Approximately 5.96E+05 gallons of Maslte liguid Ver'e discharged containing approximately 9.,60E-01 curies of activity.

Ref uelin Information January 1981 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'eactor 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.

Unf t 2'nit 2 is scheduled for, its fourth refueling beginning on or about March 26, 1982, with a scheduled restart 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 8 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 capacitv, the 1979 refuel'ng was the

Refueli~n information (Continued)

January 1981 Unit 2 '(Continued) last refueling that could be discha'rged to'the spent fuel pool without exceeding that capacity and maintaining full Icore dis~charge capability in the pool. However, 949 new high density storage locations have been installed, but cannot be used until Special Test 161 is completed.

Unit 3 Unit 3 finished its EOC-3 refueling outage and began cycle 4 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 refueling, involves loading additional 8 X 8 R (retrofit) assemblies'nto 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'uel assemblies, 208 discharged cycle 1 fuel assemblies, and 40 new 8 X 8 R assemblies in the spent fuel storage pool. The present available 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 maintaining full core discharge capabilf.ty in the pool.

Si nificant Operational Events Unit 1 Date Time Event 1/01 0045 Control rod pattern adjustment complete, commenced power ascension from 58% thermal power.

0232 Commenced PCIOMR from 73% thermal power.

1720 Reactor thermal power at 87%, holding for maintenance on "Cl" and "C2" high pressure heaters (channel relief valve leak) .

1/02 0330 "Cl" and "C2" high pressure heate'rs back in service, commenced PCIOMR from 87% thermal power.

1900 Reactor thermal power at 99%, maximum flow.

1/05 1028 Reduced thermal power to 97% for SI 4.3.A-2 (control rod exercise) .

1045 SI 4.3.A-2 complete, increased thermal power to 99%, maximum flow.

1/10 0005 Reduced thermal power to 90% for turbine control valve tests and SI's.

0100 Turbine control valve tests and SI's complete, commenced power ascension.

0330 Commenced PCIOMR from 93% thermal power.

0700 Reactor thermal power at 99%, maximum flow.

1/15 1500 Reactor thermal power at 99%, maximum flow.

1/17 2300 Reduced thermal power to 95% for turbine con-trol valve tests and SI's.

2355 Turbine control valve tests and SI's complete, commenced power ascension.

1/18 0200 Reactor thermal power at 99%, maximum flow.

1/20 1403 Reduced thermal power to 82% due to condensate demineralizer problems.

1713 Condensate demineralizer problems resolved, commenced power ascension.

1800 Commenced PCIOMR from 92% thermal power.

2300 Reactor thermal power at 99%, maximum flow.

1/23 2220 Commenced reducing thermal power from removal of "A" recirculation pump from service for MG set brush replacement.

2352 R'eactor thermal power at 40%, "A" recirculation MG set brush replacement in progress.

~Si ~nificant Opexational Events Unit 1 Date . Time Event 1/24 0146 '"A" recirculation MG set brush replacement complete, pump -placed:Ln sexmice, commenced power ascension.

0500 Commenced PCIOMR from 64% thermal. power.

1930 therma.'L power at 78%, holding dud 'eactor to condensate demineralizer problems.

1/25 0335 Condensate dern:Lneralizer problems resolved,'ommenced PCIOMR.

1030 R!eactor thexma.'L power at 87/, hold'ing due to condensat:e demineralizer problems.

1600 Condensate dlemineralizer problems resolved, commenced PCI01&

'1/26 0200 Reactor t'herma.'L power at 97%, holding due to problems with condensate demineralizers.'educed 0315 therma.'L power to 93/, due to problems with condensate demineralizers.

1500 Reduced thex~.'L power to 91/, holding due to high r:Lver diT.

2134 Commenced PCIOMR from 91X thermal 2350 thermal power from 92% to 90% due to power.'educed

",A" and "B" recirculation MG set scoop due to a bad relay. tube'ockout 1/27 0245 ",A" and "B" recirculation MG sets reset, ~

commenced PCI01W.

0845 Reac.tox thermal power at 99X, thermal 1&aited.

.1/28 0230 Commenced reducing thermal power due to con~

densate demineralizer problems.

0300 Reac:tox thermal power at 91%,, holding fox condensate deminera."Lizer problems.

0337 Commenced PCIOMR from 91X thermal 1115 thermal power from !99% to 86% to back- power.'educed wash and precoat condensate demineralizers.

1225 Condensate c1emineralizer backwash and pracoat completed,, commenced power ascension.

1250 Reactox thexana1. power at 96%, commenced PCIOMR.

2030 Reduced thermal power from 98% to 88% due to high r:Lver dT.

'1/29 0330 Commenced power ascension from, 88%.

0400 Reactor thermal power at 97X, commenced PCIOMR.

0835 Reactox'hermal power at 99%, maximum flow.

1335 Commenced reducing thermal power due to high river hT.

Si nificant 0 erational Events Unit 1 Date Time Event 1/29 1500 Reactor thermal power at 65%, holding due to high river bT.

1608 Commenced power ascension from 65% thermal power.

1800 Reactor thermal power at 81%, holding due to high river hT.

1828 Commenced reducing thermal power due to high river hT.

2000 Reactor thermal power at 64% thermal power, holding due to high river hT.

1/30 0100 Commenced power ascension from 64% thermal power.

0700 Commenced PCEO~i from 93% thermal power.

1700 Reactor thermal power at 99%, maximum flow.

2230 Commenced reducing thermal power due to high river hT.

2300 Reactor thermal power at 90%, holding due to high river dT.

1/31 0615 Commenced PCIOMR from 90% thermal power.

1414 Reactor thermal power at 99% thermal limited.

2400 Reactor thermal power at 99% thermal limited.

8 Si~nificant 'Cljeexational Events Unit 2 Date Time Event 1/02 2227 Reducing thermal power from 99% for turbine con-trol valve ests and SI's.

1 2300 Reactor thermal power at 84%, turbine control valve tests and SI's in progress.

1/03 0050 Turbine control valve tests and SVs complete, commenced power ascension from 84% thermal po~er.

0245 Commenced PCIO~i from 97% thermal power.

0730 R.eactor t:hermal power,g. 99%, maximum flow.

1124 Reactor Scram No.. 112 'rom,99% thermal power while opening PCB 5248 to obtain bushing CT o: f.l samples, a 500-kv bus-to-bus rel'ay opera'tidn This. result',ed in breaker 5244 opening 'ccurred.

causing the unit to trip.

1605 C',ommenced rod withdrawal for start up.

1843 Reactor Critical No. 123.

1930 Hain turbine reste - No. 6 combined intermediate valve would not open, startup on hold.

1/04 0105 Reactor brought sub-critf.cal for maintenance on I No. 6 CIV.

0415 Reactor Critical No. 1'24 due to cold water by reactor feed pumps, in-'ection 0600 E)rought reactor sub-critical and holding; for 'wox'k on No. 6 CI'V.

1200 Maintenance complete on No. 6 CIV, commenced rod withdrawal for startup.

1230 Reactor Critical No. 125.

1700 Enrolled T/G.

'1750 .Synchronized genexator, commenced power 'asCensiCn.

1'/05 0400 Commenced PCIOMR from 54% thermal power (sequence "A").

1/06 0905 Reduced thernml power from 94% to 90% for removal "Al" and "A2" high pressure heaters from s'ervice 'of for maintenance.

2113 Reduced thermal power to 64% for control rod adjustment.

2255 Control x'od acljustment complete, commenced pow'er ascension.

1/07 0040 Reactor thermal power at 92%, holding for maintenance on "Al" and "A2" high pres;ure heaters.

0645 "Al" and "A2" high pressure heaters back in service, commenced PCIO'.IR.

1/08 0030 Reactor thermal power at 99%, mavimum flo'w.

Si nificant 0 erational Events Unit 2 Date Time Event 1/08 1428 Reduced thermal power to 55% to withdraw .control rod 34-27 after maintenance.

1500 Withdrawing control rod 34-27, commenced power ascension from 55% thermal power.

1605 Commenced PCIOMR from 95% thermal power.

2000 Reactor thermal power at 99%, maximum flow.

2030 Reduced thermal power to 90% for removal of "Al" and "A2" high pressure heaters from service for maintenance.

1/09 0440 "Al" and "A2" high pressure heaters back in service, commenced power ascension.

0500 Commenced PCIQ~from 97% .thermal power.

0700 Reactor thermal power at 99%, maximum flow.

1/10 0130 Reactor thermal power to 89% for turbine control valve tests and SI's.

0250 Turbine control valve tests and SI's complete, commenced power ascension.

0252 Commenced PCIOHR from 97% thermal power.

0700 Reactor thermal power at 99%, maximum flow.

1/16 2247 Commenced reducing thermal power for control rod pattern adjustment, turbine control valve tests and SI 1/17 0050 Reactor thermal power at 45%, commenced control rod pattern adjustment, turbine control valve tests and SI's.

0340 Control rod pattern adjustment complete, commenced power ascension.

0500 Reactor thermal power at 60%, holding for turbine control valve tests and SI's.

0520 Turbine control valve tests and SI's complete, commenced PCIOMR from 60% thermal power.

1/18 1600 Reactor thermal power at 99%, maximum flow.

1/23 2310 Commenced reducing thermal power for control rod pattern adjustment, turbine control valve tests and SI's.

1/24 0200 Reactor thermal power at 52%, holding for control rod pattern adjustment, turbine control valve tests and SI's.

10

~Si inificant Operational Events Unit 2 Date Time Event 1/24 0335 Control rod pattern adjustment, turbine control valve tests and SI's complete, commenced PCIONR.,

2030 Reactor thermal power, at 99/-, maximi~.

flow.'/25 2200 Commenced reducing thermal power due to high river dT.

1/26 0700 Reac.tor thermal power at 67%, hol'ding due to high rive.r dT.

1000 Commenced power ascension from 67% thermal power.

2110 Commenced PCIGiM from 88% thermal, power.

1/28 0348 Reac.tor thermal plower at 99%, maximum flow.

1340 Reduceii thermal.plower to 82% due to high river dT.

1412 Reduced thermal power to 64% due to high river bT.

1/29 0430 Commenced, power ascension from 64% thermal power.

0700 Commenced PCIOMR from 97/ t'hermal power.

0800 Reactor thermal power at 99%, maximum flow.

0930 C'ommenced reducing thera~tl power due to ACNE'LPD.

1000 Reactor <<hermal power at 98%, maximum flow.

1335 C'ommenced reducing thermal power due to 'high river b,T'.

1500 Reactor thermal power at 54%, holding due t:o high river dT.

1608 Coaaaenced power ascension from 64% thermal power.

1800 R'.eactor t:hermal power at 91%, holding due t:o high river bT.

1905 Coaanenced reducing theranxl power due <<o high river biT,.

2000 Reactor thermal power at 63%, holding due t;o high river dT.,

1/30'540 Coaanenced power ascension from 63/ thermal power'.

0800 Reactor thermal power at 94%, holding due t;o high river dT.

0903 Coaanenced reducing thermal power due to lhigh river'T.

1400 Reactor thermal power at 90%, holding due to high river dT.

1425 Coaanenced power ascension from 90% thermal power.

2200 Reactor thermal power at 94%, holding due <<o high river dT,.

2230 Commenced reducing thermal power due to ~high t'iver dT.

2300 Reactor thermal power at 82%, holding dUe to high river dT,.

11 Si nificant 0 erational Events Unit 2 Date Time Event 1/31 0213 Commenced power ascension from 82% thermal power.

0435 Commenced reducing thermal power from 90%, due to high river dT.

0600 Reactor thermal power at 64%, holding due to high river dT.

0608 Commenced power ascension from 64% thermal power.

0830 Commenced PCIOMR from 94% thermal power.

1050 Commenced reducing thermal power from 99%, due to high river hT.

1440 Commenced power ascension from 77% thermal power.

1500 Reactor thermal power at 87%, holding due to high river hT.

2400 Reactor thermal power at 87%, holding due to high river hT, (1) Equipment malfunction

12

~Si ~~ni'f icant .O~erational Event:s Unit 3 Date Time Event:

1/01 0001 EOC-3 Refuel outage continues.

0700 Filling vessel for hydro.

1/02 1230 Began pressurizing vessel for hydro 1300 vessel at 100 psig. test.'eactor 1540 Reactor vessrel at 500 psig.

2300 Decreasing reactor pressure to at:mosphere. i 1/03 0755 Began raising vesse]L level for hydro test.

1010 Reactor vessel at 510 psig, hydro test in progress.

1545 Reactor vessel at, 1005 psig and holding for in-spection of drywell,.

1730 Hydro test complete,, awaiting CCW repairS.

repairs startup te. ts in progress.~

'200 CCW co~mplete, 1/14 1420 Dwell leaguc test complet:e.

1945 Drywe13. entry for maintenance on MSIV's.

2238 Dwell leaguc test'. complet:e.

1/16 0100 Drywell entry for maintenance on "B" recirculation pumZ>.

1550 Maintenance complete on "B" recirculation pump.

1900 Drywel,l lea1c test: complet 1936 Commenced rod yithdrawali for startup.

2044 Reactor Critical No. 101.,

2053 Reactor sub-critical.

1/17 0250 Reactor Critical No. 102 1225 Reset main turbine.

1245 Increasing reactor pressure- to rated.

'1420 Holcling reactor pressure at 565 psi, SJAE problems.

2205 Increasing pressure to rated, 920 psi.

2220 Tripped turbine for maintenance.

1/aS 0420 Reset main turbine.

0537 Reactor placed in run mode.

1145 R.oliLed T/G.

1437 Synchronized generator, commenced power, ascension.

1531 Main turbine tripped at 21% thermal power, moisture seperator problems.

1533 Main turbine reset.

1545 Synchronized generator, commenced power,asc,ension.

1931 Tripped main turbinie for.overspeed trip test at 21%

thermal power.

1948 Synchronized generator, commenced power ascension.

2300 Reactor thermal powder at 24%, startup tests in progress (control cabell core A2 sequence).

13 Si nificant 0 erational Events Unit 3 Date Time Event 1/Zl 0515 Commenced'ower ascension, startup tests in progress.

0750 Reactor thermal power at 30%, startup tests in progress.

0845 Reduced thermal power to 25%, startup tests in progress.

1130 Commenced power ascension, startup tests in progress.

1500 Reactor thermal power at 38%, startup tests in progress.

1/Z2 1315 Commenced power ascension, startup tests in progress.

1500 Reactor thermal power at 52%, startup tests in progress.

1/Z3 0951 Startup tests complete, commenced power ascension.

1230 Commenced PCIOMR from 60% thermal power.

1/Z5 1330 Reactor thermal power at 97%, maximum flow.

2350 Reactor thermal power at 96%, maximum flow.

1/26 0700 Reactor thermal power at 94%, mazimum flow.

1550 Commenced reducing thermal power due to high river hT.

1900 Reactor thermal power at 67%, holding due to high river hT.

2330 Reduced thermal power to 55% for control rod pattern adjustment.

1/Z7 0003 Control rod pattern adjustment complete, commenced power ascension.

0400 Commenced PCIOMR from 68% thermal power.

1/28 1435 Commenced reducing thermal power from 98% due to high river IT.

1445 Reactor thermal power at 93%, holding due to high river dT..

1530 Commenced reducing thermal power due to high river'T.

1545 Reactor thermal powex at 84%, holding due to high river hT.

1910 Commenced reducing thermal power due to high river hT.

2300 Reactor thermal power at 64%, holding due to high river hT.

1/29 0351 Commenced power ascension from 64% thermal po~er.

0500 Commenced PCIO~iK from 83% thermal power.

1/30 0100 Reactor thermal power at 99%, maximum flow.

Si~ni.ficant 0~erational Events Unit 3 Date Time -Eveni 1/30 1718 Commenced. reducing thermal power for Special Test ST 191 on west scram discharge volume header.

2000 Reactor thei~l power at 96%, 'holding, for ST:L91.

2021 ST 191 comp.'Lete, commenced power ascension.

2130 Commenced reducing thermal power from 98% for RTI 32A (Recirculation '.Pumps) .

1/31 0140 Reactor thermal power at 63%, RTI 32A in progress, 0515 RTI 32A, complete commenced power ascension.,

0700 R.eactor thermal power at 71%, holding due to high river bT.

0800 Cormaenced power ascension from 71% thermal power.

1930 C'ommenced PCIOHR from 89% 'therma.L power.

2300 R.educing thermal power from 92% due to high r:Lver bT.

2400 Holding at 74% power.

~ ~

15 AVERAGE DAILYUiVITPOWER LEVEL DOCKET iVO.

Browns Ferry 1 DATE 2-1-81 COMPLETED BY Ted Thorn TELEPHONE 205-729-6846 MONTH Januarv 1981 DAY AVERAGE DAlLYPOWER LEVEL DAY AVERAGE DAlLYPOWER LEVEL (MWe-Net) (MWe-iVet) '

I 874 17 1050 994 18 1058 1046 19 1045 1066 20 1017 1062 21 1049 1066 22 1041 1055 1009 23 1051 733 1058 25 936 10 1053 26 990 1060 27 1052.

]2 1057 28 1017 1067 903 13 29 1061 944 14 30 15 1055 1025 31 1059 16 INSTRUCTIONS On this format, list the average daily unit power level in M'iVe.Net for cachiday'in'the rcpiirting inonth. Ci>>nputc to the nearest whole me<,awat t.

I9(77 )

16 AVERAGE DAILYI'JNIT POWER LEVEL DOCKET NO.

50-260 2

UNIT Brotrns Ferzy DATE 2-1-81 COMPLETED BY Ted Thorn TELEPHONE 205-72'9-6846 MONTH January 1981 DAY AVERAGE DAILYPOWER LEVEL AVERAGE DAILYPOWER LEVEL (MWe-Net) (MWe.ilTet).,

108.'2 729 I I7 106,'2 1009 488 19 1065 98 20 106:3 875 1,070 967 22 1068 1030 '23 1052 1028 928 24 1043 25 1051 IO 1072 26 7'92 107.5 '27 1058 l2 1072 905 l3 108,1 853 29 1'078 30 894 15 1076 910 16 1066 INSTRUCTIONS On this format,!ist the avcraje daily unit pi>wer lei<<l in MtVe.NIet fIor each day in the rcpt>rting ini>nth.

Ci>ihputc rid the nearest whole megawatt.

I<)/77 I

17 AVERAGE DAlLYUNIT POWER LEVEL DOCKET NQ. 50 296 BI'owns Fex'~ 3 2-1-81 DATE COMPLETED BY TELEPHONE 205-729-6846 IO DAY AVERAGE DAILYPOWER LEVEL DAY AVERAGE DAILYPOWER LEVEL (LIIWe-Net) (MWe.Net) ~ ~

I

-7 l7 9

-10 61

-10 19 200

-a0 20 183 21 269 447 23

'74 839 1020 25 IO 26 914 805 27 903 I2 28 l3 a9 946 1026 14 30 800 IS 3l 16 INSTRUCTIONS

,On tltis format, list thc average daily unit power-'Icicl in Mac.Nct for each;day~in<the rcp'ortinl'lonttl. Colnputc to the nearest whole megawatt.

(t)/77'I

0 4l 18 OPERATING DATA REPORT DOCKET NO.

DATE COMPLETED BY Ted Them'.

TELEPHONE ~~o-6846 OPERATIi fG STATUS Notes

1. Unit iVame: Browns Ferzv 1

, 2. Reporting Period:

3. Licensed Thermal Power (lvIWt)t 3293 1152

4. Nameplate Rating (Gross MWe):

S. Design Electrical Rating (Net MWe):

mm 7..laxirnum Dep e nd able C a p acitv

. (Net hIWe:)

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

NA

9. Power Level To Which Restricted, If Any (iVet ilIWe):

10. Reasons For Restrictions, If Any:

/

This Month Yr..to-Date Cumulative

31. Hours In Reporting Period 744 744 57,026

12. iVumber Of Hours Reactor Was Critical 744 35,550.57

13. Reactor Reserve Shutdown Hours 5,098.87

14. Hours Generator On-Line 744 34,736.82

15. Unit Reserve Shutdown Hours 0 0 l6. Gross Thermal Energy Generated (MWH) 2,291,359 95,583,720 I'7. Gross Electrical Energy Generated (MWH) 775 790 31 539 080

18. iVet Electrical Energy Generated (MWH) 757,271 30,621.088

19. Unit Service Factor 100 60.9

20. Unit Availability Factor 100 .60.9

21. Unit Capacity Factor (Using iiIDC Net) 95 ' 50. 4

22. Unit Capacity Factor (Using DER iVet) 95.6 50.4

23. Unit Forced Outage Rate 0 0 28. 9

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

Refuel April, 1981 2S. If Shut Down At End Of Report Period. Estimated Date of Startup: 1

26. Units ln Test Status(Prior to Commercial Opemtiun): Forecast Achieved liNITIALCRITlCALITY liVITIAL ELECTR ICITY CO~I~IERCIAL OPERATIOiV (4/77)

,OPERATING DATA REPORT DOCKET IVO. 50-260 DATE 2-1-81 COi>IPLIETED 'BY ~>~hah.

TELEPHONE 2Q.'~29=$ 846 OPERATING STATUS Brows Ferr7 Notes, I. Unit iName: 2'.

Licensed Thermal Power (MWt):

4. Namephte Rating (Gross ilIWe):

"*"'*'i'::Pi"'":

6'. Maximum Dependable t apacity (Gross MWe): 1098.4

7. >IIaximum Dependable Capacity (Net >5>I'IVe):

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

NA

9. Power Level'To Which IRestric'ted, If Any (Net MWe):

10. Reasons For Restrictiotts, If Any:

/

This Month Yr..to.Date Cumulative ~

11. Hours In Reporting Period 744 744 51,937

12. Number Of Hours Reactbr Was Critical. 727.17 ~727.17 31 470.,78 ,

~

13. Reactor Reserve Shutdown Hoiars 16.83. . . , $ 6.P3, 12,470.,31 14.'ours Generator On-Line 713.57 713,. 57,' 30 454,.53 II

15. Unit Reserve Shutdown Hours, 0 0

16. Gross Thermal Energy Generated (MWH) 2 155~5i'0 2 1~55 570 85 228, 213

,17. 'Gross Electrical Energy Generated (>IIWH) 728 490 728,490 28,4!65, 678 IS. Net Electrical Fnergy Generated (il'IWH), 711, 450...'11,, 450 27,6I61,757

19. Unit Service Factor 95;9 95.9 '9

20. Unit Availability Factor 9 9 ~

21. Unit Capacity Fac'tor (Using MDC IVet) 89.8 89.8

22. Unit Capacity Factor (Using DIER Net) 9. )R.H 50.0

23. Unit Forced Outage Rate 4.1 4 32

24. 'Shutdowns Scheduled Over Next,6 Montlts (Type. Date, and Duration of Each):

25. If Shut Down At End Of Report Period, E!>timatedl Dale of Stdrtut5:

26. Units In Test Status IPrior to Comimercial Operation): Forecdst Achieved INITIALCRITICALITY l>VITIAL ELECTRICITY COiINIE',RCIALOPERATION (0)/77)

20 OPERATING DATA REPORT DOCKET NO.

DATE 2-2-~L COLPIPLETED I}Y ed Thorn TELEPHONE ~O-72 -6866 OPERATING STATUS Notes

1. Unit iVame Bzowns Ferrv 3

2. Reporting Period: Januar 1981

3. Licensed Thermal Power (MWt):

4. Nameplate Rating (Gross MWe):

1152

5. Design Electrical Rating (Net LWIWe):

6. idaximum Dependable Capacity (Gross iPIWe):

1098.4 1065

7. flax>mum Dependabl e C a p acit y (iVet 6'PIWe:

)

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

NA

9. Power Level To Which Restricted, If Any (iVet LPIWe):

10. Reasons For Restrictions, lf Any:

This Month Yr:to-Date Cumulative

11. Hours In Reporting Period 744 744 34 392

12. iVumber,Of Hours Reactor Was Critical 357.32 357.32 26 328.87

13. Reactor Reserve Shutdown Hours 16.08 16.08 ',826.97

14. Hours Generator On Line 320.87 320.87 25,710.87

15. Unit Reserve Shutdown liours 0 0 0

16. Gross Thermal Energy Generated (MWH) 671,059 671,059 75,036,087 I'7. Gross Electrical Energy Generated (MWH) 222,610 222,610 24,761,640

18. i let Electrical Energy Generated (iPIWH) . 213,503 213,503 24,037 826

19. Unit Service Factor 43.1 43.1 74.8

20. Unit Availability Factor 43.1 43.1 74. 8.

21. Unit Capacity Factor (Using AIDC iVet) 26.9 26.9 65.6

~H. Unit Capacity Factor (Using DER iVet) 26.9 26.9 65.6

23. Unit Forced Outage Rate 0 0 9.7

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

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

26. Units ln Test Status (Prior to Commercial Operation}: Forecast Achieved liVITIAL CRITICALITY liVITIALELECTRICITY

'CO!PDIE RCIAL OPERATION (o/77)

4h' I DOCKET NO.

UNIT SIIUTDOWNS AND POWER REDUCTIONS UNlq NAhIE Browns Ferr - 1 fl I ~Jan<a<

COhlPLEYEI) IIY 1caLXhaa-205-729-68th6 REPORT hl Off TELEPIIONF fa rh J Cause trc Corrective Liccnscc Eh C

0 IVll. Date aO Event N Action lo

~

a- V) Rcport Er w Cr C O Prcvcnt Recurrence 810123 "A" recirculation pump out for brush 163 replacement 164 810129 High river AT I': Forced Reason: hlethod: Exhibit G - Instructions S: Scheduled A-EEIuipinent Failure (Explain) I-hlanual for Preparation ol'Data ll.hlaintenance or Test . 2 hlanual Scram. Entry Sltects for Li>>cnsec C-Refueling 3-Automatic Scram. Event Report (I.ER) Fil>> INUREG.

D Regulatory Rest riot iun 4 Other (Explaitt) OI6I)

E-Operator Training h, Uccnsc Exanunation F.Administrative Ezhtbtt I Same Smtn.i G.Operational Error (Explain)

<<)/77) II Other (Explain)

DOCKET NO 50-260 UNIT SIIUTDOWNS AND POWER REDUCTIONS DA'T'E 2 1-81 COMPLETED it@ Tdd Thorn REPORThIONTII January 205-729-'6846

,TELEPIIONE L

r! Q tO iu IVrclnnrnn

~

Irur tI Cau'se Ar Corrective

~

Ir.'0 EI O V Vt! Date rn ft Event ~ n Q c! AI:lion tii I Q

.Repoit ~ Prevent

.~ III $

~

CJ R'ecuircnce'62 810103 30'. 43 PCS 5248 did nioi 'open Mithiint sevent (7) rvcles causing breaker failure rela .o erati'on and turbine tri

'63 810106 Control rod attern ad ustment 164 810108 1<ithdrawal of control rod 34-27 after

~ rr

~ IIVn i tt t nun irrut nrt n rr n 81011 6 , Control rod pattern',adjustm'ents, tur-bine control valve tests and SI's 166 810123 Control rod-.pattern-'djustments, tur-IUJllC 4 nAnnt VVllVLVJ rtl trnl ttn Ittlltv ~

nut'u va nnrt ST Is

~

Jvrl7r 1 nl A 1 ') rt High river 'hT..

168 810128 D Hi h river hT'i' 169 810129 river AT IlJ Ii r JVer t ~ u 1 r Artt rJ J 170 810129 91A111 VJVJVJ 'F Hiitii river AT 172 810131 D High river AT 3

I'!!rrcrt RC1son hlethod:

I.Manual Exllibit G - Instructions fiir Picparation of Data S: Sclicduled A.Equipment Failure (Explain) ... I'Q.

t84Iaintcnancc otr Tr st J\ ttt~tuituu t v Cr it u ~

.- Etttrv'SI!eels toi.!.me!!sec C.Refueling 3-Autoiitatic Scram'. Event Rcpo'll (LLIR) File,(NUREG 4 Other (Explain)

'16I)

D.Regulatory Restriction

.I;.OpCiatiif Traimfig ou( Lreeitse FXaliililutlunt F-Adnunist rat lac G Opcratioiial Error (Explain) Exhtrbit,l Sante Source~

it-Otlrnr (Explahi)

UNIT Sl(UTDOiVNS AND PONIER REDUCTlONS DOCKET NO.

Brotrns Ferr 3 DATE 2-1-81 COhlPLETED BY REPORT hhON'Phh ~haaaaa rh hah Llcenscc Eh Rh hh

() Rh Cause k Corrcctivc Nhh. l)atc aa Ph Fvent aa

'EE Action to m Cr r Report Er Q Prcvcnl Rccurrcnce CJ 154 810126 D Hi h river hT 155 810128 Ili 4 river AT 810130 S B S ter to test RTI-.32A 157 810131 lligh river AT F: Fiirced Reason: hlethod: Exhibit C - instructions S: Sclieduled A-Equipment Failure (Explain) I hlanual for Preparation of Data B.h(aintenance or Test 2 hlanual Scram. Fntry Sheets for Licensee C-Refueling 3-Auloinatic Scram. Ev nt Report (LER) Fil'(NUREG-D Regulatory Restriction 4 Otllcf (Explalll) 0161)

E Operator Training k, Liccnsc Examination F.Administrative G Operational Error (Explain) Exhibit I ~ Samnite Shiiirh,c (h)/77) I l.Other (Explain)

0

BRO!'HS FERRY NUCLEAR PLANT UNIT 1 ELECTRICAL HAIHTEHANCE SVlQ'fhRY poo Ohe Hooch of ~Jannao 19 81 Etkect on a e Action Taken D, re System Component Hature of Operation of Cause of ~ Results of To Preclude Haintenance The Reactor Halfunction '

Halfunction R=currence 1/5/81 Fire Fire protec- Meekly battery None During mainten- Two batteries were The batteries were Protection tion batteries check EMI 4A ance check the incapable of main- replaced. TR8193765 in panel specific gravity taining a sufficient 1-25-286 of two batteries charge.

was found to be lowe 1/14/81 Fire Smoke Detector Smoke detector This alarm would Bad smoke detec-, An inadvertent Replaced smoke detec-Protection XA 39-29-B alarmed and have masked alar tor. alarm. tor. TRII189453 would not 'signals from BFRO-50-259/8102 clear in the detectors in the relay room. r'clay room.

(Control Bay Elev. 3C) ll/19/81 Core Spray 1land Control HS 75-5A errat None, the mode HS 75-5A operat- Difficulty in trip- Replaced the hand I

Cooling Switch for lA ic. of failure did ing erratically. ping breaker with switch per EHI 23.

I Core Spray not make the hand switch. TR8203203 I Pump Core Spray Pump I

inoperable.

1/21/81 Radiation Annunciator Annunciator None Loose annuncia- Alarm inoperable Tightened annunciator Honitoring Alarm for the Alarm Inoper- tor card card, the alarm was System Stack Gas able tested and operated Radiation properly. TR//188911 Honitor 1/16/81 250 Volt Normal feeder Breaker None Morn stops on Normal feeder break DC Board breaker for inoperable main line contac er inoperable Repaired stops aligneP Vnit 1 back-up bar and the brea breaker and performedi Control Center er was out of EHI 7, breaker operat panel 23-32 alignment. ed properly. TR818946 TR8203426

Ie BRO!lNS 'FERRX'UCLEAR PL~ lT. UNIT'. I I

ELECTRICAL MAINTENANCE St&IHARY I I

For the Honth of January 19 81 I

E ect.on a e Action -Taken'o Date Component Nature of Operation of Cause of Results of Preclude System Haintenance The Reactor :falfunction. ,efalfunc tion R-currence 1/8/81 Fire attery -in Loose terminal None Loose terminal Loose. terminal, post, Replaced bat'tery-.

rotection 'anel 2-25-303 post post connection .was: not TR8106475 I!ell Ill broken.

I

(/12/81 Core Spray ,

CV2-.75-22'lve,would'ev None The feeder break vaive wouid'ot operJ- r Jglll elleu'lrcu J.l 4

'4UV 1J.l.lib vie rr I'e L4e e \ov e

rraee 1 rroao

~ )

'ot o ol ort vlrllllv or valve 'o6erated electrically thus not making. properly..- TRif203338 proper connectio JI./29/81 ontrol RD Water Tran Valve would None Feeder breaker no Valve- 85-8:woul'd'oi Properly racked in od Dri.ve., er Valve 85-8 not electri- fully racked in eiectricaiiy breaker, va~ve y s t eiTr .Cally operae.e .Operate ;opeyated properly TR8221135

- ~

BROWNS FERRY NUCLEAI'LANT U!IXT 3 ELECTRICAL HAINTENANCE SUMIARY E eeet on a e Action Taken Dn' System Component Nature of Operation of Cause of Results of To Preclude I

Haintenance The Reactor Nalfunction Nalfunction Recurrence

'1/1/81 Core Spray FCV-3-75-51 FCV-3-75-51 None Broken wire in Valve interlock Replaced broken cable Cooling would not cable. between FCV 75-51 valve operated proper i operate from and FCV 75-53 TR8203135 TR/)142229 1

control switch inoperable il/5/81 Diesel 3EC Diesel Annunciator None Bad annunciator . annunciator Replaced power supp y I Generators Generator inoperable power supply inoperative annunciator alarms I Annunciator operated properly.

I Panel TR8203159 Il/6/81 IIPCI HPCI Governor EHI 36 '/on-Unit in During perform- Trip circuit Replaced the bad coil cold shutdown ance of IIPCI inoperable and diode. Completed overspeed test, overspeed test.

the IIPCI failed TRPi219303 to trip due eo TR8190632';-

a bad coil and I diode in the I 73-18B PCV I

I I

circuit I

= '.1/9/81 Control Scram reset Switch binding None Switch operator Switch operated Replaced switch oI Bay Panels switch on and stiff spring broken stiff and binding tor, switch operated panel 9-5 properly. TR8203147 (1/10/81 Diesel DG 3A While perform- Hone SSPl and SSP2 DG 3A tripped Adjusted settings as Generator ing out of adjust- specified in ENI 72, (SI 4.9.A.1.B) ment which cause performed SI4.9.A.l.g Load Accept- the generator DG operated properly ance Test DG3A breaker to close TR8163870 tr'ipped. too soon. BFR0296/8104

BRO!iHS PERRY NUCLEAR PLANT UNIT 3 ELECTRICAL HAIHTEHAlVCE SU?R{ARY .

Por the ?{Onth of January 19 81 Et ect on G e. Action Taken Date Component Nature of Operation of Cause of Results of To Preclude System <<{al func t ion Haintenance The Reactor <<fnlfunction ~ Recurrence

.1/10/81 Core Spray HCV 75-1 & Inoperative None Bad cable from Inoperative Replaced the bad cabl Cooling HCV 75-12 indicating Panel 9-3 to indicating =light lights operated p'rope indicating lights for JB 3It79 circuit. L tittIlnhh1hh C V3 J 0 0 maalfhnhlah h f<< ft C V J J 07 l I LLGaa4 C "4 I ilrlf 7I 4LL4ul.4LgaaaaV I J=J.1 X.

aa TA II2041 58 TR8204157 IHCV 75-12 1/10/81 Reactor 5AR13C relay Problem None Relay contacts Problem in resetting Replaced burned conta)t on panel 9-.15 resetting in'ro'tection

< burned g scram when brought returned to service.

scram in by C Startup Rang TRft2v3102 hfhnitnv

~a P rima rai DCO-6l -16 React nr anne Hnne PDCO-64-16 Damper inoperable Replaced omdutrol Containment otor pressure limit- motor inopera- motor, dampers er open would tive operated properly mn Ii 1 C a'h 1 not annunciate lKftl0077l,

'LII LLIIhOL

~ a ~

iesel C Oth 1ed'nd Hone Auxihliary Local Aolll LVJ aW Jl l l

~ 'Clealleu 1 f a 4 aa ~ t aalu aalu JUII

~

L L4Q 4 4d

.eneratnrs Diesel'nelato1 fareen indicat- contacts sticking indicating lights auxiliary contact xhaust fan= ing lights burn inoperable mechanism, contacts

'ndicating ontinually worked properly.

mnIInnh1nn

?Light circuit If<<ffCVJ J77

/15/81 <<eactor oolillg unl.t Indicating Hone Actus tiiig G1iii Indieatinag ligaat Adjusted and st raioht" 4ailding 2 fan damper light inope1- on damper shaft circuit inoperable ened act'uator switch, losed able on bent thus not indicating light contacting with operated properly panel'-25 ooling iater position switc?1 mRga{)'l877 dffrinfi nneratinn cycle.

I s ~~

ERO'RTIS PERRY UUCEEiii PI.RRT UUXT ELECTRICAL HAINTENANCE SUl MARY For the .'month of January 19 81 E lect on 'a e Action Taken Nature of. Operatio>> of Cause of Results of To Preclude Date System Conponent lfaintenancc Thc Reactor ",fal func tion Nalfunction R"currcnce 1/15/81 Reactor Relay 3BKl Unit preferred Instruments and Relay contacts Corrected wiring and Control relay (Pnl9-5) breaker 602 controls Bus A an damaged due to impro replaced burned con-tripped when Unit Preferred per voltages and the tacts. TRIY203869 fuse failure Bus tied together tripping of breaker alarm came in through relay 602.

3BK1 due to in-proper wiring 1/16/81 Battery eactor Bldg. Ground on 480V None Terminal block in This ground caused a Replaced the bad 12 Board 3 nwatering Common Hd.3 Unwatering Pump ground on II3 Battery point terminal block, ump "B" Control power Control Station Hoard ground cleared.

losing grounded due to TR8203880 ircuitry corrosion.

1/17/81 80 Volt ormal feeder Inoperable None The breaker was Normal supply breake Repaired stops and ~

hutdown reaker 480V Breaker out of alignment inoperable. realigned breaker, oard hutdown Bd.3A and had worn stop . perform B!I 7, break-;

on main line con- er operated tact bar. TR8190530I properly.'R8204021

PIRO!'AS PEP%X'UCLEA1'- PLANT UNIT Common ELECTRICAL MAINTENANCE SU? &fARX For the?fonth of.'anuarY 19 81 f? feet on-. Actiotl Taken Component Na'tur e., o f. of ate'peration Cause of Results of To Preclud'e System Haintenance .The Reactor ".falfunction Ifalfunction Recurrence 1/13/81 High Pres- 'A" Fire Pump Strainer None Foward contactor The strainer was Cleaned and lubricate

-sure Fire trainer ACB inoperable use hung open. inoperable to -rotate mechanical parts of

'rotection and the coniacis LUL Iadl D,WdDI ~ \ gCJCa vere hnrned. led new co'ntacts,

~

strainer operated.

TR//20391~

properly.

'1/19/81 Air-Condi- B, .Control Ba Chill'er would None Oil pump motor Control Bay Chiller Replaced pump moior; tioning Chiller 'Oil not start sllaL L Woe ULula,CII IllJaaDII ~,'wad JIIUtacL

~  %%% nt'1%%

aaa Jc nina%%a%A 4 % %% ~ ~ % %%

nil fi1t'aar ahA

~ Imn replaced the recycle iieating) 'tim'er,-, chiller operat~

properly..

TR8190525 'aRI'I190526 nDdlt 2 ' II "

O'A4 U%%sa r s%%nA n h1 nkf u./ L3/ ul 4

tandby Gas umidity iieater iiumidity Heaier 1 Leldg I UJJ1 IIUIIIJaa JIa y aacaa.cro

%% Dn%% L%%

a'%%% t %  %  %%

%%%a%an%at

~ %%%% +% ~

I ran t maanl innnerabl 'Ia {nnnlartlblta .inoperable due to on relay, relay operab I

rain C bad relay coil properly.

t,'Relay R70B) TRf/220912 DD O'VD A<A 'ta 4I%0J I Al AA I.

1 LILIX aaa aav Jv . t v

%a@ ~

~ ~ ~ ~

DROWNS FERRY NUCLEAR PLANT UNITs 1,2&3 INSTRlktBNT MAINTENANCE SlkkfARY CSSC E UIPHENT FOR THE MONTH OF JanuarY 19 81 NATURE EFFECT ON SAFE CAUSE ACTION TAKEN DATE SYSTEM COMPONENT OF OPERATION OF OF RESULTS OF TO PRECLUDE MAINTENANCE THE REACTOR MALFUNCTION MALFUNCTION RECURRENCE Unit 1 1-15 Core Spray PDIS-75-28 Replace None Switch Would Two Previous LER's None Not Repeat 1-23 Radwaste LA-77-14A Replace None Faulty Meter'elay Alarm Would Not None Clear Unit 2 1-5 Radiation RE-90-132A Repair None Faulty, Reed Sw. Low Flow Alarm None Monitor Would Not Clear 1-20 Feedwater FM-46-4A Repair None Faulty Modifier Indicated Low Flow None Control Unit 3 Radwaste LS-77-149 Calibrate None Setpoint Drift Pump Would Not Cut None Off

.Jz 1-6 Core Spray FI-75-21 Calibrate None Instrument Drift Did Not Indicate None Correct Flow 1-12 Radwaste FT-77-16 Replace None Faulty Trans- Indicator Showed None mitter Flow with Pump Off

BROWNS FERRY NUCLEAR'LANT UNIT 1, llECHANICAL llAINTENANCE

SUMMARY

For the month of January 19 81 EFFECT ON SAFE 'CTION TAKEN NATURE OF OPERATION OF CAUSE OF RESULTS OF TO 'PRECLUDE DATE SYS TEN COMPONENT lfAINTENANCE THE REACTOR MALFUNCTION MALFUNCTION RECURRENCE 1/2/81 RCIC Turbine & Pump Low on oi-1 None Low oil level Low oil Add 3 pin'ts TR 198979 1/5 Diesel Gen. C diesel Gen. Blown gasket None Unknown Blown .gasket Unknown TR 189426 1/15 RHR Servic Off iine Smali ieakage None Fittings need Line leakage Capped iines wat er mnnHtnr cane Ttt 10OAA7 1/15 HPCI Drain Valve '

Leakage None Blown out Steam leak Repaired Valve ackin TR 198075 1/18 Diesei Air Diesel Gen Compressor None Bad compressor -Bearings worn out Replaced compressor nnntnreeenv

~ L% VVVL t-eA 4 1&A CJ A 4,% lJ

'Pl?

~

1001ttt JWJ/JkJV 1/18 Diesel Gen U 1 & 2 C Worn compress r None Worn bearings Bad:compressor -Replaced air compressor H & vent- diesel en TR 199118 1/20 FPC Valve 78-68 Leakage None Loose packing Packing leaking Tightened packing TR 203446 1/20 FPC llcv-78-551 Leakage None .Loose nacking Packing leaking Tightened packing ~

,TR'98075 1/21 Off gas Suction pumper Fan not closit g None Unknown Unknown Visually Inspected a

ran ee orr TR 188916 1/24 Control bai 18 control bav Stopped up Nnne 11{rt v et rn4ner Slnw flnw Cleaned strainer H & vent & chiller strainer TR '190533 AC 1/24 Controi'ag iB controi bay Broken vaive None Unknown BroKen valve Replaced valve H & vent & I c hiller TR 190533 AC

BROWS FERRY NUCLEAR PLANT UNIT 2 I fEClIAHICAf MAINTENANCE SUM fARY CSSC E UIPHEHT For the Honth of January 19 81 EFFECT ON SAFE ACTION TAKEN NATURE OF OPERATION OF CAUSE OF RESULTS OF TO PRECLUDE SYSTEH COMPONENT 1'fAINTENANCE TllE REACTOR HALFUHCTION lfALFUNCTION RECURRENCE 1/6/81 NPCI Pipe on bottom Leak None Unknown Pipe union leaking Tighten union oil tank I'R 102889 1/8 CRD CRD module Leak None Deep cut in Bad leak Installed new accumul-accum. wall ator TR 188935 1/14 HPCI Turbine oil Leak None Loose union Union leaking Tighten union sum TR 217584 1/16 CRD 1" vent to Loose clamps None Unknown Unknown Replaced clamps drain TR 174222 1/22 Rx buildin Tank Rx bldg Leak None Cap off line Valve leaking througl Placed cap on line cc water El 1/24 ai Purge 593'ontrol Broken valve None Valve broken Unknown Replaced valve

.Valve TR 190533

Page 1 of 2 BROWNS FERRY NUCLEAR PLANT UNIT 3, MECHANICAL MAINTENANCE SUffMARY CSSC E UIPMENT For the Month of January 19 81 .

EFFECT ON SAFE ACTION TAKEN CAUSE 'OF RESULTS .OF TO PRECLUDE SYSTEM COMPONENT NATlJRE OF OPERATION OF MALFUNCTION MALFlJNCTION RECURRENCE ffAINTENANCE THE REACTOR 1/3/81 CRD FCV-85-37A Valve locked None Locked valve Valve not operating Repositioned ha'nd-in open posit on wheel TR 1/6 Rx bldg FSV 3-64-19 Faulty valve None Bad valve Pressure port would Replaced solenoid valve vent no't close. TR 198984 rn A~va 1Jv'c R cI>> 1J44n cu Rx water Marada valve Vaive. not None Unknowli Sl icking 'valve vn 4vn

a. 'Gu JL4 n

a>>a X. 'Q7 nrrl

) u ar r traa~ rrnrkinn TR 158546 25-70 Main steam Valve 1-253A Out of adjust None Unknown Isolation valve Opened valve ment c].osed mn ]c86'r9 Sterna I a'nI>>

aaa art.T nrrt fa7V J1 11 IJ aa Ltn vnl

>>a a  % aaa nt4nn L v aa a l k at5 a a>>>>r a a a I>>Inn  %

Rl rat aa 1 nnan ROtatinar;, St em ,Atliusted plate TR 202967 1/7 HP Fire Fire pump Seal leaks None Loose packing Leakage Tightened rotection strainer' land TR 203006 hPCI FCV- I 3-].9 valve not Nonae 'Won- "e" ti"g As Lo tat J nt5 Adjuated n<late TR 202967 1/8 EECW 3-67-769 valve Chiller leak None Valve seat bad Leaking through, Installed new valve TR=137275 EECW 3-67-770 valve Chil.ler leak None Valve seats bad .Leakiaag. a.alrougha IaaatallQCul aaQ~w>> Val>>>>Q TR 137280 1/8 EECW Valve 3-67-760 Valve leaking None Seats bad Leaking valve Installed new valve TR 137274 Valve 3-67-763 Chiller leaK None Seats bad Chi].ler leaking Installed llew valv

'4 vrad TR 137277

. 1/8 EECW Valve'3-67-773 Chiller 38. None Seats bad Chiller 'lealcing Installed 'new valve leak TR 137284, 1/8 EECW Valve 3-67-779 Chiller 38

'one Seats bad ClIiller ].eakage Instaiied new vaive leak TR 13/279 Secondary Equip. Air loc -

Comes open wh n None Worn foot bolt 'Door wouldn't close New .foot bolt. & adjust-Containment Rx other are clo ed ed door TR 198986 1/8 Fire l.-rave pump Seal ieark None nr 3 .~

aa Jtatlaa. Uaa I i

vI 4eatcabe nn 1 i

<<uaikgned anl inn gl,ualu 2 Puu<<karl nl an>>I Pt'ot crt inn GliQnment TR 203019 1/8 CRD CRD,Pump 3A Dirty filter None Worn filter Replaced filter Unkno'w'n'ealcage TR 203173 1/8 HP coolant HCV 73-201A Valve packing None Handwhee]. missi Rep]aced handwheel. &

T

a. ~ a lnnt'lnn J '4 t >>>rr

% ~

1 aalr needed nat kinar added packing TR 202968

~ ~ ~ ~

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' 4 ~

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4

Cl 0 ~ 0 35 OUTAGE SUiiRY January 1981 The Unit 3 cycle 3 refueling outage which started November 23, 1980, was com-pleted January 18, 1981. The outage duration was 55 days which was 12 days longer than the 43 day duration projected prior to shutdown. This schedule overrun was primarily due to:

1. Delays in completion of the TIP work which, in turn, delayed Hydro.

a. CRD timing and friction testing combined with PCIS testing restricted drywell access.

b. Repairs to valve 85-37A, LPRM'onnectors repairs, additional repairs to "D" indezer and hydraulic control unit maintenance.

2. Equipment problems during H2/02 surveillance instructions (SI's)

(relay failures) which held up completion of PCIS SI's. This work was an RPV Hydro prerequisite.

3. Mi'sce3:laneous equipment failures and setpoint adjustments required several unplanned drywell entries prior to startup.

4. Additional HPCI turbine testing, which resulted from the late arrival of repair parts, and unscheduled maintenance on 3C turbine stop valve further delayed the unit 3 return to service.

Major work items accomplished during the Unit 3 cycle 3 outage included:

1. Refuel Floor Routine disassembly, LPRM replacement (8),

fuel shuffle, invessel TV inspections, and reassembly.

2. Turbine Floor Principal effort was limited to reactor feed pump maintenance since turbine inspections were deferred.

3. Main Steam Isolation Valves 7 (of 8 total) failed initial leak rate testing and were subsequently dis-assembled, refurbished, and tested satisfactorily.

4. Control Rod Drive Maintenance Replaced 6 CRD's (34-31, 34-39, 30-03, 30-39, 26-43, and 30-23).

4I 36 OUTAGE .

SUMMARY

(Continued)

January 1981

5. Low Pressure Coolant In ection Modificatiun (P0141/L1845)

This work modifies the automatic transfer scheme (swingbus)

.used in the power supply system to selected LPCI valves and, provides new batteries and a battery room in the miscellaneous equipment room of the diesel generator building Unit 3.

6. Balance of Plant Routine heat exchanger disassemblies, eddy-current inspections, repairs as required, and reassemblies. No major problems detected.

7. Condenser Circulatin Water CCW) Inlet Tunnel The need for repairs on 4 joints was identified late in the outage which involved'pproximately 6 days additional (unscheduled) work.

8. Raw Coolin Water Modification Preparations are underway for the upcoming Unit 1 cycle 4 outage scheduled to begin April 10, 1981. These preparations include:

Ordering, receiving, and staging material.

2. Procedure preparation.

3. Prefabrication work.

4. Modifications that do not require unit shutdown.

5. 'Personnel training.

JCi 45 4I