ML18025B278

Forwards Monthly Operating Repts for Dec 1980

ML18025B278
Person / Time
Site:	Browns Ferry
Issue date:	01/09/1981
From:	Abercrombie H TENNESSEE VALLEY AUTHORITY
To:	NRC OFFICE OF MANAGEMENT AND PROGRAM ANALYSIS (MPA)
Shared Package
ML18025B279	List: ML18025B278 ML19351F621
References
NUDOCS 8101130582
Download: ML18025B278 (46)

Text

ACCESSION NBR:

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ABERCRUMt3IEPH PEC IP ~ NAAlg.

REGULATQ jNFORLlATION DISTRIBUTION TER (RIDS) 8101130582 OOC ~ DATE'- 8'1/01/09

!AlOTARIZED: NO Browns Ferry lnuclear Power Stati ni Unit 2E Tennessee o

n rnwns Ferry Nuclear Power Stations Unit 3F Tennessee AUTHvR AFFILIATION Tennessee Valley Authority RECIPIENT AFFILIATION Office of 'sanaaement and Proaram Analysis DOCKET 05000260 05000296 SUB.IECT:

For wards montnly oeeratina rents for Dec 1980

'ISTRISOTIOA!

COOS:

AOOSS COPIES OECE IVES:LTR I F!!CL g SIZE:

TITLE: Annual, Semi-annual tt mon tbl y Operation Reoor ta (OL Stage)

NOTES:

HAEC IP IE>>T ID CODE/NAt'E ACTIUbi:

IPPOL I TO, T ~

04'NTERNAL:

AEOD

'I" F D I V OF LIC t<P A lS L BR09 HEG FILE 01 COPIES LTTR ENCL 7

7 1

1 1

2 1

1 1

1 REC I Eo I ENT ID CODE/NA~E

'VARGA,ST 04 D/OIPPHUM FAC07 I3,E 06 NRC PDR 02 OR ASSESS BR 10 COPIES LTTR ENCL 7

7 1

1 2

2 1

1 1

1 EXTERNAL: ACRS

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TOTAL NU~BER OF COPIES RE4lUIREO:

LTTP 29 ENCL 29

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J

Browns Ferry Nuclear Plant P.

O'.

Box 2000

Decatur, Alabama 35602 JAilv'8 t98l Nucl'ear Regulatory Commission Office of Management Information and Program Control Washington, DC 20555 Gentlemen:

Enclosed is the December 1980 Monthly Operating Report for Browns Ferry Nuclear Plant Units 1, 2, and 3.

Very truly yours, TENNESSEE VALLEY AUTHORITY H. L. Abercrombie Plant Manager Enclosure cc:

Director, Region II Nuclear Regulatory Commission Office of Inspection and Enforcement 101 Marietta Street Suite 3100

Atlanta, GA 30303 '(1 copy)

Director, Office of Inspection and Enforcement

'Nuclear"Regulatory Commission Washington, DC 20555 (10 copies)

Mr. A. Rubio, Director Mr.. Bill Lavallee, NSAC Electric Power Research Institute P. '0. Box 10412 Palo Alto, CA 94304

p P

TENNESSEE VALLEY AUTHORITY DIVISION OF POWER PRODUCTION BROWNS FERRY NUCLEAR PLANT MONTHLY OPERATING REPORT December 1,

1980 December 31, 1980 DOCKET NUMBERS 50-259, 50-260, AND'0-296 LICENSE NUMBERS DPR-33, DPR-52, AND DPR-68 Submitted By:

/

Plant Manager

TABLE OF CONTENTS Operations Summary

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Refueling Information Significant Operational Events Average Daily Unit Power 'Level,.

Operating Data Reports Unit Shutdowns and Power Reductions.

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12 15 18 Plant Maintenance 21 Outage Summary 33

il

0 erations Summar December 1980 The following summary describes the significant operational activities during the reporting, period.

In,support of this, summary, a chronological log of significant events is included in this report.

There were twenty-three reportable occurrences and thirteen revisions to previous occurrences reported to.the NRC during the month of December.

Unit 1 There was one scram on the unit during the month.

On December 29, the reactor was manually scrammed to accommodate rep'lacement of the stator cooling filters.

Unit 2 There was one scram on the unit during the month.

On December 27, the reactor scrammed from MSIV not full open during a SI when the unit operator

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

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

Operations Summar~ (Continued)

December 1980 Fati ue Usa e Evaluation The cumulative usage factors f'r the reactor vessel are as follows<

Location Unit 1 Unit 2 Unit 3 Shell at water line Feedwater nozzle 0.00497 0.2'4040 0.00381 0.00315

'0.16081 0 '1746 Closure studs 0.1'9766

'0.13425 0;09816 Note:

This accumulated monthly information satisfies technical specification section 6.6.A)17<B(~3)~ reporting requirements.

Common S stem Approximately 1.15E+06 gallons of waste 3.ibid were discharged containing approximately 1.28K+00 curies of activity.

Refuelin Information December 1980.

Unit 2 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 assembl'ies into the core, the final fix on the sparger modification, power supply on LPCI modification, and torus modifications if all approvals are received.

There are 764 fuel assemblies in the reactor vessel.

The spent fuel storage pool presently contains 550 spent 7 X 7 fuel assemblies, five 8 X 8 fuel assemblies, and one 8 X 8 R fuel assembly.

Because of'odification work to increase spent fuel pool capacity to 3471 assemblies, present available capacity is limited to 1193 locations.

Unit 2 Unit 2 finished its EOC-3 refueling outage and began cycle 4 during the month.

Unit 2 is scheduled for its fourth refueling beginning on or about March '26, 1982, with a scheduled 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'oading 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

capacity, the 1979 refueling was the

Refuelin~Information (Continued)

December 1980 Untt 2 (Conttnned) 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, but cannot be used until, Special Test 161 is completed.

Unit 3 Unit 3 was in,its EOC-3 r'efueling outage during the month.

Unit 3 is scheduled for its fourth refueling beginning',on, or, about September 25, 1981, with a scheduled restart date. of February,7, 1982.

This EOC-.4 re-fueling, involves loading additional 8 X 8 R (retrofit) assemblies into the core, relief valve modification, turbine inspection, and torus modi'ications if. all approvals are received.

There are 764 fuel assemblies presently in 'the r'cantor vessel.

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

The present available storage capacity of the, spent fuel pool is~10~12 ~1ocat~ions.

With present

capacity, the 1980 refueling will be the, 1@st rdfuhling that could be discharged to the spent fuel pool without exceeding that capacity and maintaining full core discharge capability in the pool.

Si nificant 0 erational Events Unit 1 Date Time Event

'2/01 0001 2300 Reactor thermal power at 77%,

PCIO~i

in progress sequence

"A".

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

12/02'0700 1406 1500 Reduced thermal power from 96% to 94% due to Xenon buildup.

Commenced rod withdrawal for power ascension.

Reactor. thermal power at 96%,

maximum flow.

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

12/04 0248'425 2300 Control rod pattern adjustment

complete, commenced PCIOMR 'from'86% thermal power,sequence "A"

"A" reactor feedpump in service, PCIOMR in progress.

'Reactor thermal power at 99% steady state, thermal limited; 12/05 2335 Reduced thermal power from 99% to 60% for MSIV closure,and turbine control valve tests.

12/06 0250 0800'500 MSIV and turbine control valve tests

complete, commenced power ascension.

Commenced'CIOMR from 88% thermal power sequence "A".

Reactor thermal power at 99%, thermal limited.

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

12/13 0425 0440 1500 Turbine:

CV, tests and SI.'s completed, commenced power ascension.

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

Reactor thermal power at 99%,

maximum flow.

12/22 0305

.0345

'Commenced'educing thermal power from 99% to 70% for turbine control valve tests and SI's.

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

.'I~inificant ~Oierational:Events Unit:,1 Date Time

Event 12/22 0700 1045 Commenced PCIOMR from 94/ thermal power -'equence-'"A".

Reactor thermal power at 99/,

maximum flow.

12/23 J

2350 Commenced reducing thermal power from 99/ to remove "A"'ecirculation MG set, "A" reactor feedpump-and~"B"'on densate booster pump from service for maintenance.

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

0505 0625 0830 1155 1430 1730 2030 "B" condensate booster pump placed in.service, reduced thermal power to 50/ for maintenance on "A" reactor feedpump and "A" recirculation MG set.

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

Reduced reac1 or thermal power to 45/ for control rod sequence exchange from "A" to '"B".

Control rod sequence exchange

complete, increased there'll power to 47/ and holding for scram testing control rods,.

Scram test complete, commenced power a. cension from 47/ thermal power.,

Commenced PCIOMR from 57/'hermal power sequence "B".

Placed "A'" reactor feedpump in service.

12/26 1500 12/27 0015 0330 1126 Reactor ther'mal power at 99/,

maximum flow.

Reduced thermal power to 85/ for turbine contr61 valve test.

and SI's.

Turbine control valve tes1 and SI's complete, commenced PCIOMR - sequence "B"'eactor thecal power at 99/,

maximum flow.

12/29 0822 1012 2226 Commenced reducing thermal power.Eor shutdown due to stator cooling fil'ter problems.

Reactor

scram, manual, No,.

139 from 41/ thermal power to per:Eorm maintenance on stator coollng water system.

Maintenance complete on stator cooling water, system commenced rod withdrawal f'r startup.

Si nificant Operational Events Unit 1 Date Time Event 12/30 0125 0725 0754 2145 Reactor Critical No. 160.

'Rolled T/G.

Synchronized generator, commenced power ascension.

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

12/31 0130 0310 0420 1501 2030'203 2400 Reactor thermal, power at,82%. holding for possible feed-water heater leak.

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

'Commenced PCIONR from 82% thermal power sequence "B".,

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

Reactor thermal'ower at 99%,

maximum flow.

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

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

S~inificant~O>erati,onal Events Unit 2,

Date Time Event 12/01 0001 0135 0848 Reactor thermal power at 40% (RTI-32) xecirculation, pump ramp te. t in progres..

RTX-32 complete, connnenced power ascension from 40%

thermal power.

Commenced PCXOMR from 60% thermal power, - sequence "A".

12/02 2330 12/03 0040 1500 2050 Reactor thermal power at 99%,

maximum flow.

Reduced reactor thecal power to 96% due to "B" recirculation puli speed control problems.

Reduced reactor thecal power to 94% due to "B" recirculation pump maintenance (mechanical and

.electrical stops and speed indication),

Maintenance complete on "B" recirculation

pump, commenced PCIOMR from 94% thernlal power.

12/04 0030 Reduced reactor thecal power from 97% to 95% for isolation of Bl and B2 high pressure heaters to repai.r leaks..

12/05 0140 0445 12/06 1220 1500 1600 Bl and B2 high pressure.

heaters back in service, commenced PCXOMR from 95% thermal power sequence "A".

Reactor thermal power at 97%, full core flow.

Commenced reducing reactor thermal power.for control rod pattern adjustment.

Reactor thermal power at 55%, control rod pattern adjustment in progress.

Control rod

. equence exchange complete,,

chinked'ower ascension from 55% thermal power.

12/07 1000 2305 Commenced PCIOMR from 80% thermal power sequence

'"A",

React. or thermal power at 90%, holding to,run a set of TXP's.

12/08 0240 0440 0500 1801 2227 Reduced thermal power to 80% fax turbine control valve tests and SI"s.

Turbine control valve tests and SX's complete commenced power ascension.

Commenced PCIOMR 'f'rom 82% thermal power' sequknc4 "A",'.

React. or thermal power at 99%, thermal limited.

Reducing thermal power from 99% for MSXV SX's and con-trol rod pattern adjustment.

Si nificant 0 erational Events Unit 2 Date Time Event 12/09 0130

'300

.0400 Reactor thermal power at 65%, MSIV SI's and control rod pattern adjustment in progress.

'MSIV SI's and rod adjustment

complete, commenced power ascension.

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

12/11 0700 Rea'ctor thermal power at 99%, thermal limited.

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

12/13 0001 0229 0230 12'/14 0700 12/17 2230 2300 Reactor thermal power at 85%, turbine control valve tests and.SI's in progress.

Turbine control valve tests and SI's completed, com-menced power ascension.

Commenced PCIOMR'rom 89% thermal power sequence "A".

Reactor thermal power at 99%,

maximum load (electrical).

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

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

12'/18 1320 2300 Maintenance

complete, Al and A2 heaters back in service, commenced power ascension from 95% thermal power.

Reactor thermal power at 99%,

maximum load (electrical).

12/22 0350 0515 0520 0830 1014 1100 1600 Reduced reactor thermal power to 85% for control valve tests and SI's.

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

Control rod exercise

complete, commenced power ascension from 91% thermal power.

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

,to oil line.

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

fluid coupling, oil line',

commenced power ascension from 47% thermal power.

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

Reactor. thermal power at 99%,

maximum flow.

S~i nificant.~O erational Events Unit 2 Date Time Event 12/23 2047 2340 Reduced, thermal power to 70% for maintenance on control rod,driye 38-.35', ~

Ma:Lntenance complete on CRD 38-,35, commenc!ed power ascension.

12/24 1500 12/27 0225 1737 2125 Reactor thi rmal power at '99%,,

maximum flow.

Reactor Scram, No.

111 'rom 99% thermal powei (1) when main steam line high radiation monitor was not reset,p'roperly.

Commenced rod withdrawal for startup.

Reactor Critical No. 122.

12/28 0035 0103 1930 Rolled T/G.

Synchronized, generator, commenced

.power ascensi'on'.,

Commenced PCIOMR from 72% thermal power 'sequence

".A".

12/29 0942 1230 1516 Reactor thermal power at 99%,maximum 'flow.

Reduced 'thermal power to 90% for control rod drive.

exercise.

CRD exercise

complete, commenced PCIOMR from~ 90%

thermal power sequence "A".

12/3O 0005 Reactor thermal power at 99%,,

maximum load (electrical).

12/31 2400

Reactor thermal pow'er at 99%, maximum load (electrical).

Si nificant 0 erational Events Unit 3 Date Time Event 12/01 0001 12/04 0550 12/22 2200 12/29 0600 12/31 2400 EOC-3 refuel outage in progress.

Fuel moves started.

Fuel movement completed.

Tensioning.reactor vessel head.

Preparations for RPV hydro and startup test in progress.

(1) Personnel Error

il

AVERAGE DAILY.UNITPOWER'LEVEL.

Browns Perry 1

DATE TEI EPHPyE 205-729-6846 MONTH December 1980 DAY AVERAGE DAILYPOWER'LEVEL IMWe-Net) 909 DAY AVERAGE DAILYPOWER L'EVEL I>SIWe>>et) 1063 l7 I8 13 1012'64 1058 1068 1063 1057 lOSS-1031 l9 7O 21 22 23 24

'>5, 27 19 1056 1050 1050 1052 1025 1032 105 420 l5 ie I

1063 1058 3l 880

'INSTRUCTIONS On this t'>>r>tlat.!ist lhe uveru 'e daily unit P<>wer!eiel in M'iVe Nel l'>>r each Jay in'the rel)>>rtin>. ln>>>lth. C>>It>i>ute t>)

the lleufest 9 hul>'ne>,:tivut t.

~'>l/77

)

1>

AVERAGE DAILYUNITPOWER LEVEL DOCKET NO.

56:2 60 Bt.otms Feiry - 2 0ATE ~SL COMPLETED BY Ted Thorn TELEPHONE

>llONTH ~ec.ember DAY AVERAGE DAILYPOl>VER LEVEIL (M'LVe.N>'t) 713 DAY AVERAGE DAILYPO)VER LEVElL.

('MtVe.N>!t )

1083 1044 1002 l9 1037 1072 1073 876 973 2l 1628-1037 1061 l0 93'8 1075 10~79 I >, ~6:I 684'3 103

>~

1080 108'7 29 3(l3l'007 1067 1070 INSTR L'CTlONS

()>a alai% I>>!>>alt,.Itt t a>: Ja'>:fJ>!>'Icily ucait pa>wc;c I>'a>ll an >ilV>.'!N>.'t'.'a>rIa du~y an tla>'cp>>!tiaac a>ac>nail>. (.>>>alp>at>.'a>

llaa.'at'J!c$ l >vita>l>! >>ac!a! Jhv:>t t,

{9/7'71

14 AVERAGE DAILYUNITPOWER LEVEL DOCKET NO.

Browns Ferry 3 DATE COMPLETED BY Ted Thorn TELEPHONE 205 729 6846 ilIONTH DAY AVERACE DAILYPOWE R LEVEL (MWe.Net)

-9 DAY AVERAGE DAlLYPOWER LEVEL (MWe.Net )

6 l8'9 20 2I "2

'73

-4 I

0'2 l3 l5

)5 26 27 28

'l9 30 3l

-5

'INSTRUCTIONS On tllls tntnlnt. Ittt tile event ie Jell) nnit In>avt level in M'5'e.Net I'nt each tiny in tlte tepnt ling nnitttlt. Ciintput<< ltt tile ne Jfcsl Iellnle nteeelvJ(l.

(0/77 )

0 i

15 OPERATING DATAREPORT DOCKET NO.

DATE COKIPLETED BY J)~~n TELEPHONE ~~i846 OPERATING STATUS Notes Browns Ferry Unit 1

l. Unit Name:

p d

December 1 9 0

2. Reporting Period:

3. Licensed Thermal Power (~IBVt):

3293 11

4. Nameplate Rating (Gross MWe):

5. Design Electrical Rating (Net Mme):

1065 Net >>I'IVe:

1065

7. <>Iaxintum Dependable Capacity (

)

S. IfChang<<s Occur in Capacity Ratings (It<<ms Number 3 Through 7) Since Last Report. Give Reasons:

NA

9. Power. Level To Which Restricted, IfAny (Net MWe):

10. Reasons For Restrictions, lf.Any:

This Month Yr..to-Date Cumulative

11. Hours In Reporting Period

12. Number Of Hours Reactor Was Critical 13..Reactor Reserve Shutdown'Hours

14. Hours Generator On-Line 722.30 6 380.09

15. Unit Reserve Shutdown, Hours

16. Gross Therinal.Energy Generated (MWH) 2,242,925 19 155 868

~11.111- - -,~

Ig. iNet Electrical Energy G<<neratcd,(MWH) 723 052 6 061 849

19. Unit Service Factor 97.1

72. 6

20. Unit Availability Factor

22. Unit Capacity Factor. (Using DER Niet)

91. 3

23. Unit Forced Outage Rate 2.9 7.5

4. Shutdowns Scheduled Over Nest 6 ><>Ionths(Typ<<, Date, and Duration of Each):

Refuel A ril 1981 56,282 34,806.57 369KY7 "

'3 992. 82, 0

93,292,361 763 290.

29 863 817 60.4 60.4 49.8 49.8 29.3

25. IfSliut I)own At Fnd Of Report Period. Estimated Date of Startup:

6. Units In Test Status IPri<>r to Conimercial Op<<rationl:

F<>rc<<ast Achieved INITIAL CRITICALITY INITIALELECTRICITY CORI<>IERCIALOPERATION (o/77)

aa 16 OPERATIabpG DATAREPORT DOCl<ET iVO. 50 260 CO41IPLETED DY Dt)n.~m~

TELLPHONE 205=Z2.'M846 OPERATING STATUS

i. Unit Nanre: ~Bnds08~xx!s=~ijJ~

2. Reporting Period:

Decembe>r 1~8)

3. Licensed Thermal Power PI>Vt):

3293

4. Namcphtc Rating (Gross 41IWc):

115.'2 S.,Design Electrical Rating (Net i I '):

10i65 1098.4

6. iiaximam Dependable Cepaeiry [Grass SSSaei:

Notes

7. biaxiraam Dependabie Cepaeiry lNer biWe):.~!55~

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

NA

19. Power Level To Which Restricted, lfAny (Net II'We):

.JO. Reasons For Restrictions, IfAny:

This Month Yr.-toi-Date Cumulative J I. Hours ln Reporting Period

.J'7. Number Of Hours Reactor Was Criti:al

13. Reactor Reserve Shutdown Hours

14. Hours Generator Ott-Linen

15. Unit Reserve Shutdown',llours

16. Cruse Thermal Ener y Gencratcd (MWH) 17.'ross Electrical, Energy Generated (sl IIVH)

18. Net Electrical'Energy Generated (MWH)

19. Unit Service Factor

20. bnit Availability Factor Zl. Unit Capacity. Factor (Using x~lDC Nctl

22. Ut)it Capacity Factor (Using DEIR Net)

23. Unit Forced Outage Rate

4. Sltutilowns Scheduled Over I'blcxt 6 lrlonths 744 8,784 51,193 19.0

~~74'~-

6 B.,5n4 12,453.48 721.37 6~076.65 720,719 5~6j'~8838 97 ~ 0 69.

%~7. 0

69. 2 91.0 60.1

&1~.0.

60. 1 3~

(Type. L)ateand Duration of Each):

~29 74i0. g,'6 0

83, 57i0, 6,43,

~2t~LJ29 26 950 307, 58.1 58.1 49.4 49.4 0

0 2., FP), 2Y(~,,

3,7, $15643 738 400 5 787 120

$. IfSliut I)@wit At End Of Report I'eriod. Estimated l)ate of Starjtup.

3tp. Units ln Test Status t Prior tii Cumiiierciil Operation):

Forecast Achieved IisITIALCRITICALII'Y INITIALELECTR, !CITY CObb(ilERCIAL OIPERATIION (it/77)

17 OPERATING DATAREPORT OPERATING STATUS DOCKET NO.

DATE 1-4-81 CO!>IPLETED BY~~

TELEPHONE 2Q5='~%46

1. Unit Name:

2. Reporting Period:

December 1980 3..Licensed Ther>nai Power (MWt):

4. Name late Rating (Gross Mac):

1152

5. Design Electrical Rating (Net 1>I'lVe):

6. >>Iaxi>num Dcpendablc Capacity (Gross MWe):

l a i

u e )cndable a acit Net MIVc:

1065

7. il )inl mD I

C p y(

)

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

NA

.. 9. Poiver Level To Which Restricted, IfAny (Nct MWe):

.10. Reasons For Restrictions, IfAny This Month Yr..to-Date 744 7, 064 152.58 9

21,257,162 0

7,136,450 6,936,660 0

I l. Hours In Reportin

~ Period 0

..12.

>Number Of Hours Reactor Was Critical

13. Reactor Reserve Shutdown Hours

14. Hours Generator On.Linc

15. Unit Reserve Shutdown llours 0

16. Gross Thermal Energy Gcneratcd (MIVIC)

17. Gross Electrical Energy Generated (MPH)

18. Net Electrical Energy Generated (l>IWH)

19. Unit Service Factor 79.1

20. Unit Availability,Facti>r

22. Unit Ca>>acity Factor IUsing DER Niet) 0

23. Unit Fi>reed Oiltage R:ite 0

11.7

24. Sliutd>>ivns Scheduled Over iNert 6 i>I>>nths(Type. Date. and Duration of Each):

Cumulative 33 648 25,971.55 1,810.89 25,390 0

74 365 028 24,539,030 23,824,323 75.5 75.5 9.8

25. IfShut Di>ivn At End Of Rcport Peri>>d. Estimated Date uf Startup:

'6. Units ln Test Status lprii>rI>> C>>n>mcrcial ()pcrati>>n):

F>>recast Achie'veil INITIALCRITICALITY I> >ITIALELECTRICITY CO,'>It>IERCIAL OPERATION (t)/77)

0 0

4

UNITSIIUTDOWNS AND PO'IVER REDUCTIONS REPORT MONT!Idecember lllk"" f11.:jft~

DATE ~~1 COMPLETED EY ~~m A

o EJ T/)

Lice))see Event Rcport-C O

i Q

Cause A, Corrcit)vc Action Ii)

Prevent Rceurrcn<<e 158 801205 B

Derated for turbine control valve and MSIV tests and SI's 159 801222 B

Derated for turbine. control valve tests and SI's 160 801233 Maintenance to "A" reactor feedpump "A" recirculation MG set and "B" condensate booster pump 161 801229 F

21.70 A

Maintenance to stator cooling system (Replace filters) 162 801231 Derated for control rod pattern adjustment F: Fi)r;ed S: Schcduleil

('t/77)

Rcasi)ll:

A Equipment Failure (Explain)

B.hIaintenance or Test C. Re fueling D Reyilatory Restriction I'..Operator Trainint; &. Liccnsc Exan)ination F-Ailn)inistra tive G Operational Lrri>r (Explain)

I I.Other (Explai>>)

hlcthod:

I.hla nual 2 h(anual Scram.

3-Auto)natic Scratn.

4 Other (Explain)

Exhibit G - Instructions for Preparation i)fData linlrySheets I'or Licensee Event Report (LL'R)Fili (NURI'.G.

OI 6I )

Fxhibit.l - Sainc Source

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~ II

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UNITSIIVTDOWNS AND POWER REDUCTIONS REPORT hlONTII ~eetrdser DOCKET 80>

UNITNAME DATE COMPLETED BY TELEPIIONE

3 6

SaumMr~~

3 J3o~ mao=

~66 I)JIc I

A I/>

Llccllscc F.vent Report =

C C>

O 6>

C +

Cause A Corrective Action to Picv>.nt Rct.urrcn<<

153 Cont.

801201 744 C

EOC-3 Refuel Outage I

F:

I orced S: Schedoie(l Reason:

A E>luipment Failure (Explain)

II hlaintcnance or Test C.Refueling D.Regulatory Restriction I Operat>>r Training 4 License Exami>ration F.Administrative G Op rational Lrror (I:xpl>nnl I I Other (Explain l Method:

I Marlual 2.hlanual Scram.

3.Autontatic Scratn.

4.Other (Explaini Exhibit G ~ Instructions for PrepafJllon of Oat J Entry Sheets lor Licensee Event Rcport (I.I R) File INUI(I'.G.

OI6l l Exlnbit I

~ Sa>nc Source

0 Ik

e BROliNS FERlB NUCLEAR PLAVRT UNIT ~rrron ELECTRICAL HAINTENANCE SORRY lor the Honth of December 1980 Date Sys terr.

Component E

ect on Sa e

Nature of Operation of Haintenance The Reactor Cause of Halfunction Results 'of Half unc tion Action Taken To Preclude Recurrence 2/1/80 Diesel Generator

'O'iesel Generator Scheduled None, the redundant diesel generato start test was operable.

811 3

A bad coil on signal unit duration relay, The bad coil caused slow operation of the SUDR relay allowing an arc to remain across relay contacts 1-2 thus not allowing DG fast start circuit to reset.

Replaced bad coil.

on SUDR relay, completed EHI 3.

SUD relay operated proper ly,'R fj194429 t I

i j

I 12/3/80 Diesel Generator 12/ll/80 CO2 Fire Protection System 12/14/8(

Diesel Generator

'O'iesel Generator Refrigerant compressor on Card'ox unit located at units 1 6 2 diesel gene '-

rators

'D'iesel Generator Output bkr.

1812 opened during sur-v'eillance testing (SI 4.9.A.l.a.)

Compressor lines freezing Audio alarm relay was found to be hanging up during sur-veillance testing (SI 4.9.A.l.d)

NONE None.

C02 fire protection system remained in service NONE A shorted diode in over-speed trip alarm circuit.

Filter giyer became saturated causing lines to freeze.

DG alarm panel relay mechani-cally hanging Up A shorted diode in over-speed trip alarm circuit tripped breaker 1812.

Capacity to cool CO was slightly reduced.

Audio Alarm inop-erable Replaced shorted diod.

Reran survei)lance est, diesel'enerate operated properly~

TR 1I189406 BFRO 50-259-8088 I

lReplaced filter ryer and checked xpansion valve, drooling unit opera~

I3roperly.

TR !ll7~

I l

I Replaced bad relay, alarm operates

)eopeely TR919.7031

UPOiiNU PUiUil lWCLLVII PLIIViT UIIZT 1.

ELECTRICAL HAINTENANCE SlMfMY Unte Sj'stem I Component I

Nature of

,Haintenance E

ecton 'ae Operation of The Reactor

'ause of Halfunction Results of lHalfunction

'ction Taken To Preclude Recurrence 12/2/80 Reactor Protection System 1A, RPS HG set HG set was removed from service due to smoke coming from HG set control hnv

¹ne.

Equipmen responded in safe direction and gave 4 scram.

Hinor fire was local-ized and rnn-tained within the equipment enclosure; Relay contact arm retainer >l..

rings were made of flamma-ble, materials.

I Burned relays, wiring and trans-former.

Replaced w'iring and trans'former,.

changed relays to non-flammable.'type,.

retainer rings-.

mrr t$ 1 OnrlC7 rl1ni1n1~

LLL ÃJV7LVI )

LL7CVJ 12/4/80 Radwaste

'System FSV 77-15B Not receiving

a closed'n-dicat J.ng licht in the

'ontrol room.

NONE Closed limit switch was out'f adjust meAt.

Received no closed indicating light inl cvntrol rooim ~

'A'dju'sted limit switch indicating lights Operate propeLlyL TR fI189278 717n /tt Aa p

~ vl v Dv4lrrnvrr l L XII~ilLJ

'ontainment System Deli fl, 1l,n vr v I R IV unllrn pnni I inn' indicating lights not operating v'vA v

~r trLvtrr L1J

~

NnND

~i\\rr rrr Limit. srritr hes out,of adjust-ment.

Ihdirat inlr 1 inh ts nn panel 9-3 did not opera't'e properly.

I Adjusted limit switches, indicati~

lights and switch~

operate properly.

TR

/$203251 12/21/8 HPCI FCV 73-6

~

Not receiving a'alve inul-cating.light for.open posit'ion o'

panel 9-3.

NONE Open limit ~

S'PLLcll GPVLLLLvL arm was loose.

Open indicating J.l.gill. invPeLcltiYe ~

Tighte'ned open opera-avm

] irlriP sirwiPct now operates propert TR 8203247 12/22/80 1IPCI Closed indicat-ing light for ru 7'2 lD Vr I J Vlr Vll anel was inop-NONE'ad resistor Closed indicating light =fgr FCV 73-65 1

0 7 4rrri hv Vll trnllr L 7 J I rlVtrr L a tive.

I Re'placed resister, in-icating light oper-.

rlvonnv 1y TP'i 203245

BROliNS EENTSY NUCLEAR PLANT UNIT~'

ELECTRICAL MAINTENANCE SRQhRY Por the Honth of December 1989 Date Sys tert.

Component Nature of Haintenance E

ect on a e Operation of The Reactor Cause of

- Halfunction I

Results,'of

~ifalfunction I

Action Taken To Preclude Recurrence 12/29/80 Associated Electrical System Indicating

'ights on panel 9-8 Handswitch for normal-alter-nate feed to 480V.shutdown board 1B has no indicating lights NONE Blown fuse in indicating light circuit.

Handswitch indicat-ing lights were inoperative.

I I

C Replaced fuse, indi-cating lights operate pzaj eely.

TR 8201

BROtPifS FERRY NUCLE)'J< PLANT UNIT 2.~

ELECTRICAL MAINTENANCE SlkQfhRY For the Honth of December 19 80 Date System Component Nature of Maintenance ect on

'a e Operation of The Reactor Cause of Malfunction Results of Malfunction Action Taken To Preclude

-R"currence 12/6/80 EEClf FCV 67-49 Open indicat-ing light on local conirol

~wi t ch innn-erative NONE Bad pushbutton light transfor-v m&L ~

Local control open indicating light inonel aiive Replaced bad trans-former, open indicat-ing light transformer is operable.

TR II 197013 12/7/ 80 Neuiron Monitorin System Neuiron 2A Battery I

ttl hVUUJ G'll t

3 1

maintenance EMI 4C

NONE, Syst em continued to operate pro-perly.

Durintt EMI 4C found neutron 2A battery post broken.

Neutron 2A battery was inoperative.

't O7n 1 4 J7 IVA>

Replaced broken battery per SEMI 27.

TR I/193740t 1/8795t Core Spray Cooling System FCV 75-39 Both open and closed indica zing lights are en-with

'valve.closed.

NONE Bad terminal block on limit traino Indicating lights fail to operaie

~vevnv1u rLVt% I, ag

~

Replaced bad terminal block.

TR vl89321 12/28/8 Fire D'vnt.ant a n L ~

TA J9 110 Neat-detected or power failure alarm t;fnND Shnr t-ed re] av due to conden-sation in zone detector box.

,'ondensation acted as a conductor

.across the relay coniacis of the heat det et tor (TA 39-110) thus giving a false alarm 1

Removed condensati from relay and dr detector box, annunc ator 1

r d.

Ttt ll 202843 4

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CSSC E UIPllENT BRO'iXIR PERRX iXUCLE/Z PLAiNT UIILT 3.

'LECTRICAL HAINTENANCE SQQfARY December 19 80 For the Honth of Date System Component Nature of Haintenance E

ect on Sa e

Operation of The Reactor Cause of Halfunction Results of

,'talfunction-ion Taken Act I

To Preclude Recurrence properly at local panel TRlll89572 I.2/24/80 CRD Relay 5AK13C located at

~~1 0 1g P44444 J, J

J.a o Relay 5AK13C sometimes arciRlcl caulsinE/

relay 5AK15 and'AK15C to chatter.,

HONE Relay contacts A. ~

i~

4ELI JAIL \\AUC 4V contact mis-alignment.

Relay 5AK13C some-4 4maa svn4na 4 J.ill% 9 0 Li J.ill) causinn relay 5AK15 and 5AK15C.

to chatter.

Aligned relay con-contacts contacted'perated properly.

TR II203130

CSSC E VIPMENT BROWHS FERRY NUCLEAR PLANT UNIT ALL INSTRUMENT MAINTENANCE SEQUNY FOR, THE MONTH OF December 1980 BATE l

)NIT L2-ll L2-17 SYSTEM Radiation Monitoring Containmen Inerting C(&PONENT TA-90-144 H M-76-39 2

NATURE OF MAINTENANCE Calibrate Replace EFFECT ON SAFE OPERATION OF THE REACTOR None None CAUSE OF MALFUNCTION Setpoint drift End of sensor life RESULTS OF MALFUNCTION Indicated abnormal temperature Low sensor output ACTION TAKEN TO PRECLUDE RECURRENCE None New system-to replace GE syste JNIT l.2-2 L2-ll Radiation Monitoring Residual Heat Removal FI-90-165 FI-74-56 Calibrate Repair None None Instrument drift Faulty amplifier Annunciator would not clear Indicated 'flow with pump off None None L2-22 Residual Heat

-Removal TI-74-1368 Repair None PCB corroded Room temperature indicated downscale None

!/1/80

!/15 1 Ieara

<<Ic<<

2/10 CSSC E UIPMENT COMPONENT SYSTEM NATURE OF HAINTENANCE Steam line drai Valve bonnet pot isolation 1'eak valves RCIC Valve 71-201A RCIC Valve seat steam leak CRD Modules 22-31, 26-31 26-39, 18-39 sn in J.

a J7a Jar aJ 14-43, 18-43 22-43, 26-43 30-43$

22-39 scram iiot val Replaced dia-phragms and valve internal CRD es eplaced dia-hragms and alve internal CRD Modules R

30-35, 26-35 p

22-35-18-35 v

14-35, i.0-39 06 47 10~7 14-47, 18-47 22-47, 26-47 scram ilot val es Fuel Pool Cooling Valve 78-, 66 Va ve ell'ined ccaceccll FCV-85-llA and FCV-85-11B Bad seat BROWNS FERRY NUCLEAR PLANT UNIT MECHANICAL MAINTENANCE SUlfffARY For the Month of December

] 9 80 EFFECT ON SAFE OPERATION OF THE REACTOR CAUSE OF MALFUNCTION eeking valve a

None (elva leaking None None reventive faintenance reventive faintenance None alee eesll kind None ad seat None RESULTS OF ffALFUNCTION Leaking valve Valve leaking None Betad. ShaVinga COamalaa os when operated Flow in excess of minimum requirement ACTION TAKEN TO PRECLUDE RECURRENCE Replaced bonnet gasket on valves TR 166790 Replaced bonnet gasket on valve Tn 16Fi7A7 Changed. out repair kit<<

and diaphragms TR 198949 Changed out repair kit.

and diaphragms TR 198949'.

RGPalrzaa Packlnag glen(

on valve TR 202996 Replaced-seat with new One I,'

~ rr TR, 158658 fa 1586159

CSSC E UIP1fENT BROMNS FERRY NUCLEAR PIANT UNIT 2

MECHANICAL MAINTENANCE SU1%fARY Por the Month of 19~

SYSTEM RCIC COMPONENT 2-71-570 NATURE OP 1fAINTENANCE Steam Leak EFFECT ON SAPE OPERATION OP THE REACTOR None CAUSE OP 1fALFUNCTION Packing leak RESULTS OF HALFUNCTION Unknown ACTION TAKEN TO PRECLUDE RECURRENCE Tightened nuts on packing gland on valve TR 198933 HPCI Tes't connection Steam blowing on FCV 73-3 through 73-584

& 73-585 None eak on test connection Unknown Replaced the'/2" pipe plug to stop leak TR 217527

BROWNS FERRY NUCLEAR PLANT UNIT 1

MECHANICAL MAINTENANCE

SUMMARY

I For the Month of December 19 80 DATE SYSTEM COMPONENT EFFECT ON SAFE NATURE OF OPERATION OF MAINTENANCE THE REACTOR CAUSE OF MALFUNCTION RESULTS OF MALFUNCTION ACTION TAKEN TO PRECLUDE RECURRENCE

!/23/80 High Press ure Fire Protection HCV-0-26-994 6

HCV-0-26-1400 Hater leaking i;

None 2" water line ruptured Hater leakage Replaced section ~f 2" PVC pipe Tr 203410 p.

33 OUTAGE

SUMMARY

December 1980 Refuel floor activities progressed well through the month of December with completion of fuel shuffle at 2200 hours0.0255 days <br />0.611 hours <br />0.00364 weeks <br />8.371e-4 months <br /> on December 22.

Core verification work was completed at 0100 hours0.00116 days <br />0.0278 hours <br />1.653439e-4 weeks <br />3.805e-5 months <br /> on December 24, and vessel reassembly work started shortly thereafter.

Vessel reassembly efforts in preparation for the RPV hydro were complete at 0200 hours0.00231 days <br />0.0556 hours <br />3.306878e-4 weeks <br />7.61e-5 months <br /> on December 30.

At this time emphasis shifted to the drywell valve work remaining in preparation. for hydro.

All outage preparations for RPV hydro were complete by the end of this reporting period.

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

1.

LPCI modification (L1845) completed installation and testing of Loop I Motor-Generator sets.

Loop II terminations and testing are scheduled during the next reporting period.

2.

Install raw cooli'ng water pump and strainers (P0214) strainers and pump have, been placed and minor piping and electrical wbrk remains.

3.

Replace GE H20 Analyzer Conduit and Cable.,(L2079) piping work was approximately 60% complete and electrical approximately 90% complete.

Other areas of outage involvement include:

1.

Limited turbine floor work because turbine disassembly was deferred until the next outage.

The principal effort has been with reactor water feed pumps, oil pumps, and associated refurbishment.

2.

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

3.

Main steam relief valve removal for off-site testing and repairs.

These valves have been reinstalled in preparation for RPV hydro testing.

4.

Main steam isolation valve testing revealed seven (of eight total) valves required repairs.

The repairs were performed and the valves are being returned for functional testing.

l

• is

~yg~

34 0

OUTAGE

SUMMARY

(Continued)

December 1980 Schedule Remarks The refuel floor activities, which are critical path, have been on schedule when assessecl p'her the revised 46 day~ outage schedule.

Currently the expected return to shervice date for Unit 3 Xs Sanctuary 9, 1981.

Pactors which may affect this date are H O., modificator.on work, scram discharge 2

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