ML18025B397
| ML18025B397 | |
| Person / Time | |
|---|---|
| Site: | Browns Ferry  |
| Issue date: | 03/01/1981 |
| From: | Thom T TENNESSEE VALLEY AUTHORITY |
| To: | |
| Shared Package | |
| ML18025B396 | List: |
| References | |
| NUDOCS 8103170550 | |
| Download: ML18025B397 (46) | |
Text
TENNESSEE VALLEY AUTHORITY DIVISION OF POWER PRODUCTION BROWNS FERRY NUCLEAR PLANT MONTHLY OPERATING REPORT February 1,
1981 February 28, 1981 DOCKET NUMBERS 50-259, 50-260, AND 50-296 LICENSE NUMBERS DPR-33, DPR-52, AND DPR-68',t
'ubmitted By.
Plant Superintendent 8> 0817 0550
0 C
TABLE OF CONTENTS Operations Summary Refueling Information Significant Operational Events Average Daily Unit Power Level Operating Data Reports Unit.Shutdowns and Power Reductions.
16 19 22 Plant Maintenance
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25 Outage Summary
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37
4l 4k
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1 0 erations Summar February 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 eleven reportable occurrences and four revisions to previous occurrences reported to the NRC during the month of February.
Unit 1 There was one scram on the unit during the month.
On February 21, the reactor was manually scrammed so Unit 1 could swap from the spare phase trans-former back to "B" phase transformer and free the spare transformer for use by Unit 2.
Unit 2 There were two scrams on the unit during the month.
On February 25, the reactor was manually scrammed so Unit 2 could swap from the "2C" phase trans-former to the spare transformer and free the "2C" transformer for use by Unit 3.
The reactor was scrammed on February 28, due to a personnel error which led to having two inoperable APRMs in different RPS channels simultaneously out of bypass.
Unit 3 There were three scrams on the unit during the month.
On February 3, the reactor scrammed due to an APRM HI HI flux from a change in the "B" recirculation flow when the "B" recirculation HG set switched feeder breakers due to a spurious signal of unknown origin.
The reactor was manually scrammed on February 7, for a drywell entry to repair equipment. and check for drywell leaks.
On February 23,
Operations SuImnarg (Continued)
February 1981; the reactor was manually scrammed to place Unit 3 on the- "2C" phase -.tr'an4-former 'because the Unit. 3 phase transformer began generating combustibl'e gases and to performed needed:niaintenance'.
'Unit 's'tartup was-subsequently delayed due to coupling pi..obleins on the L'PCX MG sets.
W
~
- I t& P 4p=*
0 erations Summa (Continued)
February 1981 Fati ue Usa e Evaluation The cumulative usage factors for the reactor vessel are as follows:
Location Usa e Factor Shell at water line Feedwater nozzle Closure studs Unit 1 0.00501 0.24255 0.19832 Unit 2 0.00383 0.16511 0.13494 Unit 3 0.00329 0.12351 0.10049 Note:
This accumulated monthly information satisfies technical specification section 6.6.A.17.B(3) reporting requirements.
Common S stem Approximately 3.64E+05 gallons of waste liquid were discharged containing approximately 5.42E-Ol curies of activity.
Refuelin~Infor'mation February 1981'nit 1
Unit 1 is scheduled:Eor its fourth r'e'fueling beginning on or about April 10, 1981, with a scheduled'estart date. of July 23, 1981.
This
're'ueling will involve loading additional 88 R (retrofit) '.Euel assemlbies into, the core, the final:Eix os the sparg'er modification, power supply on LPCI modification generator brea'ker and ~unit station 'transformer tie-in (requires.Unit 2,to be,,shutdown)- and,tor'us.Imodifichti'ons,if,all,approvals are received.
There, are 764 fuel assemb>Lies in the'.reac'tor vi ssel.
Th', spent fuel
-storage pool presently contains 550 spent'
'X 7 fuel assemblies,
.fiv'e 8 X 8'pent fuel assemb/Lies, 72 new 8 X '8 R fue1 assemblies, arid one, spent 8 X 8 R fuel assembly.
Because of modification work to increa e spent 'fuel pool
'apacity to 3471 assemblies, present available capacity is limited'o 465 locations.
Unit 2 Uni't 2 is, scheduled:Eor its fourth r'efiheling'eginning on or about March 26,
- 1982, w:Lth a scheduled restax't date.of August 13, '1982.
This refuel'ing outage will involve completing 'relief valve modifica'tions, torus
'odifications if all approvals are received, "A" low pressuxe turbine in II
- spection, MG set:Lnstallation for LPCI mo'dification and loading additional 8 X 8 R fuel assemblies into the coxe.
There are 764 fuel assemblies in the reactor vessel.
~~it the end of the month, there were 132 discharged cycle 1 fuel assemblies, 156 discharged cycle 2 fuel assemblies, and 352 discharg'ed 'cycle 3 fuel assemblies in the
Refuelin Information (Continued)
February 1981 Unit 2 (Continued) spent fuel storage pool.
The present available capacity of the spent fuel pool is 160 locations.
With present capacity, the 1979 refueling was the last refueling that could be discharged to the spent fuel pool without exceeding that capacity and maintaining full core discharge capabiltiy in the pool.
- However, 949 new high density storage locations have been in-
- stalled, but cannot be used until Special Test 161 is completed.
Unit 3 Unit is scheduled for its fourth refueling beginning on or about September 25, 1981, with a scheduled restart date of February 7, 1982.
Thi's refueling involves loading additional 8 X 8 R (retrofit)'assemblies into the core, relief valve modification, turbine inspection, generator breaker and unit station transformer tie-in, and torus modifications if all approvals are received.
There are 764 fuel assemblies presently in the reactor vessel.
There are 124 discharged cycle 3 fuel assemblies, 144 discharged cycle 2 fuel assemblies, 208 dis'charged 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.
Si nificant 0 erational Events Unit 1 Date Time Event 2/04/81 1915 "Al" and "A2" high pressure heaters placed in ser-vice, holding at 95% thermal power due to condensate demineralizer problems.
2/05/81 1600 2200 2/07/81 0155 0305 0550 1030 Commenced PCIOHR from95% thermal power.
Reactor thermal power"at 99%,
maximum flow.
Reduced thermal power to 77% for cntrol rod pattern adjustment.
Increase thermal power to 90%, holding for CRD exercise.
CRD exercise
- complete, commenced PCIOHR.
,Reactor thermal power at 99%,
maximum flow.
2/08/81 0005 0112 0240 0700 Reduced thermal power to 70% for turbine control valve tests and SI's.
Turbine control valve tests and SI's complete, commenced power ascension.
Commenced PCIOMR from 91% thermal power.
Reactor thermal power at 99%,
maximum flow.
2/10/81 1010
.Reduced thermal power to 93% for removal of "A" string high pressure heaters from service for maintenance.
2/11/81 0345 0700 "A" string high pressure heaters in service, commenced power ascension.
Reactor thermal power at 99%,
maximum flow, rods limited.
2/13/81 0700 2255 Reactor thermal power at 98%,
maximum flow, rods limited.
Commenced reducing thermal power for "B" recirculation MG set brush replacement.
2/14/81 0100 0250 0330 0520 0830 0900 1230 Reactor thermal power at 40%, holding for "B" recir-culation HG set brush replacement.
"B" recirculation HG set in service, commenced power ascension.
Reactor thermal power at 50%, holding for turbine control valve tests and SI's.
Turbine control valve tests and SI's complete, commenced power ascension.
Reduced thermal power from 68% to 64% for control rod pattern adjustment.
Commenced power ascension from 64% thermal power.
Commenced PCIOHR from 67% thermal power.
2/15/81 2230 Reactor thermal power at 99%,
maximum flow rods limited.
44 V
Ei'~niffcant O~etatfanal Events Unit 1 Date Time Event 2/16/81 2300 Reactor thermal empower at 98%,
maximum flow,', r'ods limited.
2/17/81 0700 1930 2200 Reactcir thermal
]power at 97%,
maximum flow, rods limited.
Reduced reactor thermal power to 78% for'bnt'rol rod power'haping.
Control rod power shaping
- complete, commenced'CI~OMR.
2/18/81 1312 14'30 2300 Reduced thermal
~power from 98% to 90% fdr kontrdl rod power'haping.
Control rod'ower shaping complete, commenced'CIiOMR.
Reactor thermal power at 99~%, maximum flow,, rt>d
'imited.
2/19/81 1500 Reactor thermal powr at
'98%,
maximum flcIw> rod limited.
2/20/8i 2300 Reaictor thermal power at 99~%,
maximum fl'ow,', rbd
'imited.
2/21/81 0001 0145 1050'345
'700 1810 2130 2148 2300 2344 Connnenced reducing thermal power for shutdt>>wn td place the unit on 1B main transformer fr'om'the spare transformer.
Reactor Scram (manual)
No.
140 frcim 35% po~er to place the unit on 1B main transformer fr'om'th'e spare transformer in order t:o spare out 3A mai~n trahs>
forfner for maintenance (there was a buildup of com-bustible gases in 3A t:ransformer).
Connnenced riod withdrawal for startup.
Stopped withdrawing rods due t:o problems with'od 18-31.
Commenced rod withdrawal for startup, rod 18-31 tagged.
R'.eactor Critical Ho.
1.'61.
R.ol;Led T/G.
Synchronized generator, commenced power ascension.
Reactor thermal power at 15%, holding due to pro-blems wit:h control rod. select P.B. for rod 58-19, (wi:Ll not: deselect)
Rod 58-19 deselect problems
- resolved, commenced power ascension.
2/22/81 2230 2/23/81 2300 C'ommenced PCIOt>K friom 69% thermal power.
Reactor thermal power at 99%,
maximum fliow, rod limited.
Si nificant 0 erational Events Unit 1 Date Time Event 2/24/81 2335 Reduced thermal power to 96% for SI 4.3.A.2 (CRD exercise).
2/25/81 0035 0100 CRD exercise
- complete, commenced power ascension.
Reactor thermal power at 99%,
maximum flow, rod limited.
2/28/81 0005 0055 0700 2400 Reduced thermal valve tests and Turbine control commenced power Reactor thermal limited.
Reactor thermal limited.
power to 86% for turbine control SI's.
valve tests and SI's complete, ascension.
power at 99%,
maximum flow, rod power at 99%,
maximum flow, rod
Dace Time Sfgnifi ant Operatfonal E~re<<<<<<s
'Unit 2 Event 2/01/81 0001 0200 0812 1100 1600 1805 2300 Commenced reducing thermal powei from 87%,
due to high river hT.
Reactor thermal power at 63%, holding due to high river hT.
Commenced.
power ascensioti from 63%'hermal power.
Commenced PCIOHR from 91% t'hermal power.
Reactor thermal power at 94X, holdf.ng due to high river,dT.
Commenced, reducing thermal power due t:o lhigh rfver hT.
Reactor th'ermal power at 67%, holding due to high river hT.
2/02/81 0300 0400 0800 1430 1455 1500 2020 Commenced power ascension from 67% thermal po~er.
Commenced PCIGHR from 89% thermal power.
Reactor thermal power at 91%, holding due to "C" string high pressure heat:ers being out of s'ervice.
Commenced reducing reactor thermal power'o placIe "C" string hig'h pressure heater in servi/.e.'eac:tor thermal power at 83X, "C" string high pressuie heaters in service.
Commenced PCIONR from 83% thermal power.
Reactor thermal power at 94X, holding due to waste collector filter problems in radwasee pr6ventfng'ackwash and precoat of condensat;e demineralizers.
2/03/81 0915 2300 Commenced PCIO]<K from 94X thermal power.
Reac,toi.
thermal power,at 95%, holding due to waste collector filter problems in radwaste pr&venting'ackwash and precoat of condensat:e deminkraliderk.
'/04/81 2356 2/05/81 0100 2/06/81 2130 2200 2210 Commenced PCIO~i,K from 95% thermal power.
Reactor.
thexmal power,at 98%, VKLPD limited.
Commenced reducing thermal power to withdraw con-'rol rods afeer ST-191 which checks resphns'e dz scram discharge header water level monitors.
- Reactor, tlhermal power ae 76%.
Commenced power ascension from 76% therm<1 poacher.
2/07/81 0445 0700
,2/08/81 0120 Connnenced PCIO'.IR from 95% thermal power.
'eactor thermal power at 97%,
O'K'LPD liml.eeIi.
'educed thermal power to 86% for turbine cokerlol'alve teses and SI's.
Date Time Si nificant 0 erational Events Unit 2 Event 2/08/81 0245 0330 0700 Turbine control valve tests and SI's complete, commenced power ascension.
Commenced PCIOMR from 95% thermal power.
Reactor thermal power at 98%,
CMFLPD limited.
2/10/81
-2300 2/11/81 0910 2300 2/12/81 0700 2300 2/14/81 2217 2345 Reactor thermal power at 97%,
CMFLPD limited.
Reactor thermal power at 96%,
CMFLPD limited.
Reactor thermal power at 97%,
CMFLPD limited.
Reactor thermal power at 95%,
CMFLPD limited.
Reactor thermal power at 96%,
CMFLPD limited.
Reduced thermal power to 64% for control rod pattern adjustment, turbine control valve tests and SI's.
Control rod pattern adjustment, turbine control valve tests and SI's complete, commenced power ascension.
2/15/81 0050 1200 2300 Commenced PCIOMR from 87% thermal power.
Reactor thermal power at 99%,
maximum flow, rod limited.
Reactor thermal power at 98%,
maximum flow, rod limited.
2/16/81 0700 Reactor thermal power at 97%,
maximum flow, rod limited.
2/17/81 1210 1500 Commenced power ascension from 97% thermal power.
Reactor thermal power at 99%,
maximum flow, rod limited.
2/21181 0010 0036 0052 0630 Reduced thermal power to 87% for turbine control valve tests and SI's.
Turbine control valve tests and SI's complete, commenced power ascension.
Commenced PCIOMR from 95% thermal power.
Reactor thermal power at 99%,
maximum flow, rod limited.
2/25/81 0100 0148 Commenced reducing thermal power for shutdown to spare out 3A main transformer for maintenance.
Reactor Scram (manual)
No.
113 from 40% thermal power in order to spare out 3A main transformer for maintenance (there was a buildup of combust ble gases in 3A transformer).
4l 3.2 Si~nificant, i0~era'tional Events, Unit 2 Date Time Event 2/25/81 1500 1610 Commenced rod withdrawal fair.tartup.
Eteactor Critical No. 126.
2/26/81 0115 0212 2330 Enrolled T/G.
Synchr'onized generator, commenced power
'asden'sion.'ommenced PCIOMR from 82X thermal power.
2/27/81 0935 1015 2/28/81 1358 1757 2057 2318 2354 2400 Reactor thermal power at 89X, holding de t:o computer problems.
Cumputer problem.: resolved, holding at 89X po~er clue to "A" string high pressure heaters 'being'ut of,service.
Reactor Scram No,.
114 'rom 89X thermal power on (1)
EZRA's H3: while performing SI 4.1.Pi-15 (APBM gain).
Commenced riod,withdrawal for.tartup.
Reactor Critical No. 127.
Rolled T/G.
Synchronizeid generator, commenced power 'ascension.
Power ascension in progress.
13 Date Time Si nificant 0 erational Events Unit 3 Event 2/01/81 0001-0013 0731 1130 1730 1822 2300 Commenced reducing thermal power from 74% due to high river dT.
Reactor thermal power at 64%, holding due to high river AT.
Commenced power ascension from 64% thermal power.
Commenced PCIOMR from 95% thermal power.
Reactor thermal power at 99%,
maximum flow.
Commenced reducing thermal power due to high river AT.
Reactor thermal power at 77%, holding due to high river AT.
2/02/81 0300 0330 1730 2/03/81 0859 1805 2112 Commenced power ascension from 77% therma'ower.
Commenced PCIOMR from 87% thermal power.
Reactor thermal power at 99%,
maximum flow, rod limited.
Reactor Scram No.
91 from 99% thermal power, (2) during the performance of SI 4.2.A-3 a spurious signal of unknown orgin momentarily caused a
sudden increase in recirculation pump flow and APRM HI HI flux.
Commenced rod withdrawal for startup.
Reactor Critical No. 103.
2/04/81 0115 0142 1131 Rolled T/G.
Synchronized generator, commenced power ascension.
Commenced PCIOMR from 72% thermal power.
2/05/81 0130 0605 0700 1303 1320 1435 1800 2100 2110 Reactor thermal power at 82%, holding due to waste collector filter problems in radwaste preventing backwash and precoat of condensate demineralizers.
Commenced power ascenison from 82% thermal power.
Commenced PCIOMR from 89% thermal power.
Reducing thermal power from 96% due to 1/4 isolation signal on "A" main steam line pressure.
Reactor thermal power-at 93%, holding for SI 4.2.A-6 (main steam line lost pressure).
SI 4.2.A-6 complete, replaced bad relay, commenced PCIOMR from 93% thermal power..
Commenced reducing thermal power from 99% due to 1/4 isolation signal on "A" main steam line pressure.
Reactor thermal power at 94% ("A" main steam line pressure, signal) instrument mechanics began trouble shooting low pressure switch.
Commenced PCIOMR from 94% thermal power.
14 Significaht O~erational Events Unit 3 Date Time Event 2/06/81 0100
-0530 0700 1030 2330 Reduced thermal power from 99% to 94% due to group I half isolations,
("A" main
~>>team line low pressure).
Commenced power ascension from 94% thermal power.
Commenced PCIOMR from 96% thermal power.,
Reactor thermal power at 98%,
maximum flow.
Commenced reducing thermal power for shutdown for maintenance, on MSIV's and drywell equipment, drain sum'p pump.
2/07/81
- 0051, Reactor Scram (manual)
No.
92 from 38% thermal jpower for maintenance on MSIV's and drywell '-equip-ment drain sump pump.,
2/08/81 0815'829 Maintenance complete on MSIV's and drywell equip-ment drain sump pump, commenced rod withdrawal for
,startup.
- Reactor Critical No. 104.
2/09/81 0320 03592230'Rolled T/G.,
Synchronized generator, commenced power asqepsiqn.,
Commenced PCIOMR from 70% 'thermal power<
2/10/81 0815 1125 1330 2/11/81 0630 0955 1800 2029 2/12/81 0700 Reactor thermal power at 84%, holding for computer, outage.
Computer back in service, commenced power ascension.
Commenced E?CIOMR from 89% thermal powerl.
Reactor thermal power at 98%,
maximum flow, rod limited.
Received spurious 1/2 scram, commenced reducing thermal power.
Reactor thermal power at 97% due to 1/2 scram.
Commenced power ascension from 97% thermal power.
4 Reactor thermal power at 99%,
maximum flow, rod limited.
2/15/81 0010 0120 0200 0600 1017
-1035 Commenced reducing thermal power to 87% for turbine control valve tests ans SI's.
Turbine control valve tests and SI's complete, commenced power ascension.
Commenced
)PCIOMR from 97% thermal power.
Reactor thermal power at 99%>>
maximum flow, rod limited.
Commenced reducing thermal power for RTI-'2 (Refueling Test,Instruction Pr;essure Regulator).,
Reactor theaml power. at 95%>> RTI-22 irr progress.
~
15 Date Time Si nificant 0 erational Events Unit 3 Event 2/15/81 1300 1500 RTI-22 complete, commenced power ascension.
Reactor thermal power at 99%,
maximum flow, rod limited.
2/16/81 1230 1240 1330 1435 1445 1730 Reduced reactor thermal power to 71% due to loss of "D" main steam line flow indication.
Commenced power ascension form'1% thermal power.
Holding reactor power at 94% while performing main-tenance on "D" main steam line.
Maintenance complete on "D" main steam line flow indicator, (square root converter changed out),
commenced power ascension.
Commenced PCIOMR from 97% thermal power.
Reactor thermal power at 99%,
maximum flow, rod limited.
2/20/81 2340 Reduced thermal power to 87% for turbine control valve tests and SI's.
2/23.'/81 0001 0230 0430 Turbine control valve tests and SI's complete, com-menced power ascension.
Commenced PCIOMR from 98% thermal power.
Reactor thermal power at 99%,
maximum flow, rod limited.
2/23/81 2100 2201 Commenced reducing thermal power for shutdown to remove 3A transformer from service.
Reactor Scram (manual)
No.
93 from 39% thermal power to remove 3A 'transformer from service for maintenance (there was a buildup of combustible gases in this transformer).
2/26/81 0746 0920 1310 1404 Commenced rod withdrawal for startup.
Reactor Critical No. 105.
Rolled T/G.
Synchronized generator, commenced power ascension.
2/27/81 0130 2231 Commenced PCIOMR from 75% thermal power.
Reactor thermal power at 88%,
maximum flow, rod limited.
2/28/81 2043 2400 Reduced thermal power to 64% for control rod pattern adjustment.
Reactor thermal power at 64%, control rod pattern adjust ent in progress.
(1)
Personnel Error
"(2)
Equipment Malfunction
0
16 AVERAGE DAlLYUNITPOWER LEVEL DOCKET iVO.
DATE COiIPLETED GY Browns Ferry 1 3-1-81 TELEPHONE 205-729-6846 MONTH Febru<<y DAY AVERAGE DAILYPOWER LEVEL (MWe-Net) 886 2
DAY AVERAGE DAlLYPOWER LEVEL (i>1We.>Net) 1004 17 986 10 12 13 l6 1003 1030 1059 1039 1063'029 1058 1045 685 9761048'9 20 21 22
'>3 24 25 26 27 2S 99 30 31 1057 1058 49 616 925 1056 1055 1054 1044 liNSTRUCTIONS On this tortnat.!ist the average daily unit pi>wer Ie<<l tn lltVe Net t>>r each day iti the rep>>rrinc ini>nth. Ci>inpute to the nearest ivh>>le me aivat t.
Ii>I 7 71
AVERAGE lpAILYUNITPOWER L'EVEL'OCKET iVO UNIT DATE C<PiIPLETED IIY Teci Thorn TELEPHONE
<<$10<NTHFehlzUezv
<<'AY AVERAGE DAIL'YPOWER LEVEL (MWe-iVet),
805 7
1019 1025 1063 1046'050 1054 1I050 DAY 17 IS 19
,20 21
'22
'23.
'4 25 AVERAGE DAlLYPOWER LEVEL thIWe-<Vet) 1060 1072 DQZ2-1075 1066 1074 1081 1078 59
~
~
10 12 13 14 IS 16 lI059 lI046 1I036 1I035 1I016 1036 1040 76 27 2S
'79 30 31 5I05 9,50 543 liVSTRUCTIONS On this t'onnat.!ist the uvera<,e <Icily unit p<iwer lesel iri ~I<<Ye.<Vet for <<.aeh'<Iay in th>> report tn.i rni<nth. Ciitnp<ite to the nearest
<whole rnc.<ivutt.
l<IIg7)
18 AVERAGE DAILY'UNITPp'WER LEVEL DpCKET iVp 50-296 Browns Perry 3 3-1-81 COMPLETED IIY Ted Theta TELEPHONE 205-729-6846 iIOVTH February DAY AVERAGE DAILYPOWER LEVEL
(~iIWe-iVet)
I 8
8 996 DAY AVERAGE DAILYPOWER LEVEL (MWe iVetI ao75 17 18
'5 10 13 15 16 390 632
'74 1044
-13 523 905 1049 1067 1075 ao74 1062 1062 19 20 21
'22
'23 25 26 27 28 a9 30 31.
1077 1079 1072 1069 975 180 884 900 INSTRUCTIOVS On tl>>s rbrrnat.!ist the avcrayc daily unit pi>iver level iii ~I'tVe iVct ter each dai',<<t th<<rcpnrttnc tnnnth. Cutnputc to 1
the nearest wlnilc m<<vivat t.
Ii)1771
.1'9 OPERATII4IG DATAREPOR1I'OCKET iVO.
DATE 3-1-81 CO<<IPL'ETED B'Y
.Zgd T~onl ~
TELEPHONE.~~2~-%846 OPERATING STATUS
- l. Unit Name:
Browns Ferry 1 February HFE
'2. Reporting Period:
- 3. Licensed Thermal Piower (MfVt):
- 4. Nameplate Rating (Gro<s iaaf'IVe):
- 5. Design'Electrical Rating (Net <lf'lVe): 1065
- 6. hfaximu'm Deoendable Capacity (Gross 33ffVe):
- 7. Xfaximum Dependable Capacity (Net'ibfWe):
1065
.Notes,
- 82~1fiChan's;Occur,in
- Capdcity.'Ratings3(Items Numb3er:3 Througlhi73).Since,Last:Report.,Give<Reason<s:
-NA
- 9. Power Level To Which Restricted;If Any (I'Iet INWe):
- 10. Reasons For Restrictioris; IfAny:
I
~
This I3<fonth Yr.-t3o-Date Cttmulativ!e 1416 672' I. Hours In Reporting Perllod
- 12. 13Iumber Of Hours Reactor 1!Vas Critical
- 13. Reactor Reserve Shutdown Hours.
- 14. Hours Generator On.Line
- 15. Unit Reserve Shutdown Hours
- 16. Gross Thermal Energy Generated (bfWH)
.17. Gross Electrical Energy Generated
{31IWH)
- 18. Net Electrical. Energy Generated (i~fWH) 19 Unit Service Factor
,20. IJnit Availability Faictor I. Unit Capacity Factor IUsing hlf)C Nct)
- 22. Unit Capacity Factor (Using DER Net)
- 23. Unit Forced 0'utage Rate
- 24. Shutdowns Scheduled Over Ne3tt 6 Months Refuel ng April, 1981 1,399.58 292 655.58 Z
651. 95, 1.395. 95 0
0 2 011,925 664.:320 4,303.284.
1440,110 1,406,541 649,'770, 97.0
'98.6
- 90. 7 93.3
- 90. 7 93.3 3.0 1.'
IType. Dati.. and D'urat'ion of Each'I:
57,698 36, 20M
~ 1M
>,.IT3~~
35,,38,8. 77, 0
97,. 59'5, 645 32,203,1600 31,270935o 61,.3
,61,.3
50,. 9, 50,9 o.
9
.25. IfShut Ooiin At End-Of Report Periodl. Estiinated Date i)fStartup:
- 6. Units ln Test Status IPrior ro Cominercial Operation):
'ore'cast'chieved 31<itITIAL<CRI'TIC'ALIT>Y INITIAL ELECTRICITY
'CO!31.'<IERCIAL OPEIRA1I ION
20 OPERATING DATAREPORT DOCKET lI'O.
50-260 DATE COMPLETED BY TELFPHONE ~~6846 OPERATING STATUS Notes I
Unit game Bro~s Ferry 2 e ruary
- 2. Reporting Period:
- 3. Licensed Thermal Power (MWt):
- 4. Nameplate Rating (Gross LIIWe):: aas2
. aos
- 5. Design Electrical Rating (Net INIWe):
- 6. Maximum Dependable Capacity (Gross MWe):
e endable Ca acit Net MWe:
- 7. ilaxtmum D p P
y(
)
- 8. IfChanges Occur in Capacity Ratings (Items incumber 3 Through 7) Since Last Report. Give Reasons:
.i%A NA
- 9. Power Level To which Restricted, IfAny (Net IIIWe):
- 10. Reasons For Restrictions. IfAny:
This hlonth Cumulative 52 609 32,135.39 12,477.70 Yr.-to.Date 672 1416 664.61 1,391.78 24.22 7.39 1.351.24 31,092.20 0
0 0
4,140,476 97.711,119 1,984,906 663,200 646.806 29,128,878 28.308.563 1,391,690 1 358.256 95.4 59.1 94.9 s9.a 95.4 94.9 50.5 90.1 90.4 90.4 90.1 50.5
-4.6 5.1 31.9 ype. Date. and Duration of Eachl:
'Lfatwt>Pi BB C
O o
- 11. Hours In Reporting Period
- 12. Number Of Hours Reactor Was Critical 13.. Reactor Reserve Shutdown Hours
- 14. Hours Generator On-Line I'5. Unit'Reserve Shutdown Ilours
- 16. Gross Thermal Energy Generated (i~1IVH)
- 17. Gross Electrical Energy Generated (IIIWH)
- 18. 'Bet Electrical Ener y Generated (MWH)
- 19. Unit Service Factor
- 0. Unit Avaiiability Factor
- 21. 'Unit Capacity Factor (Using MDC Net)
- 22. Unit Capacity Factor (UEing DER Net)
- 23. Unit'Forced Outa e Rate
- 4. Shutdowns Scheduled Over Next 6 Months (T
- 25. IfShut Uuwn At End Of Report Period. EBtimated Date uf Startup:
I Eo-
- 6. Uniti ln Test Status {Priorto Commercial Operation):
Forecast Achieved lNITIAL CRITlCALITY IIBITIAL ELECTRICITY COiOIERCIALOPERATION
OIPER ATING DATA,REPOR'T DOC)'ETNO. -50 296 DATE 3-1-81 I Oi(PLETED SY ~~J2233..
TEL EPHONE 20>
"':68 OPERATING STATUS Notes
- 1. Unit Nan>e:
33rovn.: -Perr~-.
3
- 3. Licensed Thermal Power'(i1Wt):
3293 4.
nameplate'Rating (Cross iiPVe):
DXG'>
- 5. Design Electrical Ratirii! (Net M,We):
- 6. ilaximum Dependable
>Capacity (Gross >i(We):
- L098. 4' 06 7.,Max>mum Dependable ICapac>ty (Net >MWe):
.~8;.~lf)Changes'Occur>in>Capacity! Ratings (lltemis Number:3>>Th>'oug'h 7ijl'Sin'ce,'Last:Report.. Give'Reasons:
NA
- 9. Power Level To )Vhich '.Restricted, I'fAny (INet MWe):
IO..Reasons For Restrictio>ts;If Any:
This Month Yr.-to-Date Cumulative
'1, 41'6 672
- 11. Hours In Reporting Period
- 12. Number Of Huun Reactor Was Critical
- 13. Reactor Reserve Shutdown Hours
- 14. Hours Gener'ator On.Line
- 15. Unit Reserve Shutdnwn Ilours
- 16. Gross Thermal Energy Generated (M)VH) 17 Gross Electrical Energy Cenerated (MWH)'S.,Net Electrical Ene'rgy Gene!rated (>ilWH)
- 19. Unit Service Factor
- 20. Unit AvaiLability.Factnir I. Unit Ca(iacity Factor (Usin
>MDC Net)
- 22. Unit Capaiity Factor (Using DER Nct) 23'. Unit Forced Out;ige'Rate
- 24. Shutdowns Scheduled Over Next 6 >il>>>>ths 916.43 113.17
~ 558. f)3, 113.17 860.97 540.1 0
0 2,281,,603.
~1.61
.542 544,610 767,230 529,j90...,
>,'43; 09,3
- 60. 8 60'8
- 80. 4 80.4 74,. 01 19.6 13.3 (Type. Date. arid Duration <>f Eachl:
'5;7, 698
'26,887., 70 1,940;14 26,250,,97 0'6,6'46'629 24,306,250 65.8,
- 65.8, 9,9
, 25.. IfShut Di>wn At End Of Rep>>rt Perioill. Estimated Date uf Star!up:
- 6. 'niti I>> Test Status (Prii>r t'o Cum>nercial Operhti>>n t:
'>>re'ca'~t A>.'hieved
.. '.. (9/77)
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)
IUTDO'lUNS AND POWER RE REPORT MONTII I
UltITSl DUCTIONS
)
)>>
)
I DOCKET NO.
Brogans Ferr
- 1 COMPLETI:D BY l)atc Liccnscc Fvcnl Report ~
i 4l V'n
~<<
0c
)
p3 Cause A ( orrcclivc Acl)ol) to Prevent Rcc<<rrcoce
~ ~
165 2-1-81 Iligh river hT 166 2-7-81 Control rod pattern adjustment 167 2-7-81 Turbine control valve tests and SI's 168 2-13-81 "Bo recirculation HG set brush re-placement 169 2-2$-.81 20.05 Reactor scram to place unit on 1B main transformer I
F: F<<)ced S: S.hcd<<lcd (It/77)
Reason:
A E)luipment Failure (Explain)
II hlaiotcimnce oi Test C.Refueling
, I) Reg<<latory Restriction I'. Ope)ator Trainiog 8: Liccnsc Examination
~ I"Adolioistrative Operational L'rror (Explain)
II Other (Explain I I
Method:
I-hfanual 2.Manual Scram.
3-Auloolalic Scram.'
Other (Explaut)
Exhibit G - Inst roclions fof Prep)Ital)oo ol Data L)llr)'i)citslof I.)ccoscc Event 'Rcport (I.I)RI File (NUREG.
0161)
Exhibit I - Saute Source
~ el I
e I 0
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1 r
r UNITSIIUTI)OWNS AND POWER REDUCTIONS I
REPORT hlON'flI February DOCVET NO.
Itrowns Feri. -
3
(.'Oh(PLL'Tl:I)It/
fl I.f.'PIIONf
.205-729-'6846 No.
Ihte
~AI
~r A<<J J
~C Vl Llecnscc Evert I Rcport >
4l 4l'n cn Cr CJ~
0c F ~
O Cause A Corrective Action lr>
Prcvertt Recurrence 58 2-1-81 D
lligh river AT 59 2-3-81 16.72 During performance of SI 4.2.A-3, two leads shorted which. caused a sudden increase in recirculation flow
( ersonnel error 60 2-7-81 S
51.13 Maintenance o'n MSIV's and drywell e ui ment drain sum jr
~
61 62 2-16-81 2-23-81 S
- 64. 05
~
g Loss of oDo main steam line flow indication Maintenance on 3A transformer start-up delayed as a result of cooling problems on HPCI MG sets I
. ~
F: Forced S: S;Ii'L.l<<lcrl s
(9177)
~
I sr Reasoll:
A.(xluipmcnt Fai(ure (Explain).
ll hlaintenance or Test
( Refoelutg I) ltceplJlory Restriction',
I ()pcrator TrainInhk, IJI:ense Examination I'.Arlrrdrristrative G Opqratio>>al I:rror (lixqlain)
II ()tlter (lixplai>>)
'I II hlethod:
I-hlanu'al 2 hlanual Scram.
3-Autotnatic Scram.'
Otltcr (Lxplain) 5 Exhrbrt G - Instruct tons for Prctsaratron i)t DJta Fntry Slteels lor Lieerrsee Event Report (I.ill()I'ile INUREG-OIOI)
Exltibit I
~ Sante Source
Ih
l BRO',i'HS FERRY NUCLEAl'LANTUNIT 1
ELECTRICAL HAIHTENANCE SUl'MRY Date 2/7/81 2/10/81 System Control Rod Drive Control Rod Drive CcllIPOnent I!and Switch 85-48 LA-85-085A Nature of lla intenance lland switch repair Annunciator alarm inoper-able Etiect on
'a e
Operation of Thc Reactor Hone
'None Cause of Nalfunction Broken stop on lls 85-48 Loose annuncia-tor card.
Results of Malfunction Required care to be taken while operat-ing switch to avoid rotating switch passed desired setting.
Annunciator alarm inoperabl'e.
Action Taken To Preclude R'currence Replaced broken switch stop, switch operated properly TR//188904 Inspected and tight-ened card, alarm operated properly.
TR//203458 2/13/81 RCIC Relay 13A>>K43 Relay was found to have a broken coil retainer.
- None, the relay was operable, Broken coil retainer.
Although relay was
- operable, corrective action was required.
Replaced relay, relay operated properly.
TRII129355 2/15/81 Standby Liquid Control "1A" SLC Pump "1A" SLC pump suction line heater inop-erable None-repairs were made befor temperature dropped below Tech Spec limit.
Suction line heater trans-former bad.
Suction line heater inoperable.
Replaced transfor-mer, heaters operat-ed properly.
TR8203546 2/20/81 I
~
Annunica-tor SysteI Annunciator Panels on Panel 9-5 Annunciator.
Panels on Panel 9-5 in-operative.
None Bad inverter.
Annunciator Panels inoperative Replaced inverter, annunciator panels operated properly.
February 21, 1981, the inverter malfune.
tioned causing a
ground in the ann.
circuitry, the new inverter was replac-ed, ground cleared.
No further problems occurred.
TR8203520 TR8204911
BRO!'HS FERRY NUCLEAR PLANT UNIT 1
ELECTRICAL ffAINTEHANCE SALARY For the !fonth of February 19 81 Date System Component Nature of tlaintenance E rect on Sa e
Operation of The Reactor Cause of'"falfunction Results of Na 1func tion Action Taken To Preclude Recu".'rence 2/24/81
~
R4'H
.Fuse failure alarm on Pan 9-28 Fuse failure alarm would not clear, None Bad relay co'il.
Received a false fuse failure alarm.
Replaced relay "KKB'use failure alarm.
onerat ed" pronerlv.
TR8203498
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BRO lVS FI'lRRY NUCLEAl'LANT,UNIT
. 3 ELECTRICAL 'MAINTENANCE Sly!IARY l~
Date.
2/2/81 I
System It i Rllll I
lt Component 3D RllR Ptttnp Nature of
'.laintenance During the norformanCe of SI4.5.8.16 3D RllR,pump woULd not dtdVI QLllLl
~
ET!'ect on Sa e
Operation of.
The Rc".ctor RllR heat ex-.
rltantTer 3R nut'f service.
Cause:of
.'fn 1func tion',
The 4kV pump breaker t rinnod free on -a close signal, due to a'.
loose, trip link ddd
~ t)l
~
Results of
~
Naif unc tion 3D Rl!R pump inoper-nh1o
-Action Tat.es To-Preclude R currence,
,Changed-out the.'breaker,=
the pump
'perated properly.
TR920tt297 TRtI'190611'ERI/RPRO 5n 296/81 2/3/il l
l2 Diesel Generator 3C D'/G 3C D/G failed to trip from Remvt.t tt.Jp during sur-veillance testing.
ltould not roi torl None No'thing was
'ound which woul IlaVe pl.evelltJve
-the diesel from starting.
Tlie'CR and'TL01'elays were'isrovorod ba'tj
-during investi-
'gation.
3C.D/G, in'operable.
Replaced
'the-'bad.
relays,, completed
'll
.l.nnt dUJYUJJJallvc LcdLR
'iese1 generator operated'- properly.
TR8204281 mR'Jt i9 n 7 c a
., LER8BFRO-50-296/8109
't ItlItt 1 1
l ( Nt VL
'l 9
t 2/6/81 Mnl~t vnn
~llillLVl~
Monitorinl Diesel Gci'iT raiors ftnlt R1 nnt
~'\\vv vtLvvn
, Monitor "B."
I 3A D/G Aiiniiiicis to l.
Piincl tn 18 nt VVllLV llVL return RBM "B" to servic while it was Jl ~ Uytladd status.
Receivdd a
false over speed alarm on panel 9 RttM innndvdhl d
~llll~
JllVQ% LVVJl
~
Hone Rnll hl nr Ir mnni tn
~l V VVl
~ ~
'switch was bad.
Annunciator cJrcuitry card was loose 'in annunciator panel.
R
.RRM innnorab1 o Received a false alarm on 'pailel 9 23' Rinlar od tho bad.
, switch, rod: block monitor '-'B",operat-
- ,ed properlytl
'RIl'7')1LA1 N
tL Tightened.car'd, alarm.- cleared rRI/221316 1
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CSSC E UIPtiENT BROWNS FERRY NUCLEAR PLANT UNIT Common MECliANICALMAINTENANCE SU>QIfARY DATE
i DATE i
SYSTEl1 COHPOHEH'1 EFFECT ON SAFE NATURE OF'PERATION OF HAIHTEHAHCE THE REACTOR CAUSE OF HALFUNCTION, RESULTS OF HALFUNCTION ION TAKEN ACT TO PRECLUDE RECURRENCE 2/12/81 Ii, 2/27 Controi Bay NVAC CRD 18 chiller 1-84-503 Clean oil cooler Leak Hone None Hud in tubes Faulty valve Unknown Leakage Cleaned cooler and replaced heads TR 190880 Installed new relief vs J.ve TR. 182505'
CSSC E VIP SROHNS FERRY NUCLEAR PLANT UNIT 2
5KQiANICALHAINTENANCE
SUMMARY
For the Month of February
]981 i<<
~
D-V
)l
),g3:
~
~,<<
)i% ~
f II
))
~)'
~
<<)
i ~ g f)
<<f ~ <<f f
f,a'.
~ /14
<<<<l
'g/20 '"
< <<;,g 25 -,-.-.
SYSTEH CRD CRD CRD COHPONENT CRD 42-31 Pump D
2-85-229 NATURE OF MAINTENANCE Air leak Leak Leakage EFFECT ON SAFE OPERATION OF TllE REACTOR None None None CAUSE OF MALFUNCTION 0-ring worn Loose pressure re ulator ca Horn valve stem RESULTS OF MALFUNCTION Air leak Pump leak Stem packing leak ACTION TAKEN TO PRECLUDE RECURRENCE Replaced 4 o-ring inside coil TR 221186 Tighten regulator cap TR 103789 Replaced stay val stem packing TR 188939
BROHNS PERRY NUCLEAR PLANT UNIT 3'EQh8+Ah hlAINTENANCE SUlMARY'1--
DATE ls SYSTEM COMPONENT EFFECT ON SAPE'ATURE OF OPERATION OF MAINTENANCE TllE REACTOR-CAUSE OP MALFUNCTION..
RESULTS OF MALFUNCTION TION TAKEN AC TO'RECLUDE.
RECURRENCE 2/1/81 2/3 2/5 2
7 2/8
~ I.
l2 17 s
2/ll Control Bay liest Or
~ I hn w s s ~ s sa sa'v D/G I
n In vIv Hain Stc alia SeI Onilarv Conta ir>me Hain a n High Pres sure Cool an t In ec Residual Heat R mox Control Bay Chillers 3C D/G oil.
level switch, float.
n ln On isIv J'v 3-FCV-1-51 "D" DrvWI 1 1 ner-t sonnel access door 3-FCV-1-38
.3-FCV-1-52 MlSIV-3-~7-MSIV 3-1-51 3-73-3 3-74-73.
al Hater found in freon Fi 1 s nvs.
~ ka s vav Frozen float tthl 1
~v v
~
na.sx nvs.
aust 40 rpm Leakage Insnect door.
~ow set Leakage Leakage
. None.
None 0+v ss ssIJsas None None None None None Plug'ame out of tube Float stuck ussrsssnssss Ma a sw s s wa wl a ~
Blown'iston s'sa)
Unknown None Unkonwn Loose pa'cking nu Loose packing nuts Unknown-Inoperable Leaking air through Unknown
'orre Unknown Small leak on
-pacKing-Packing gland leakin
'Plugged: tube and
.cleaiied; TR 199142
, Removed: plate and frees
'loat
'rK-tuff//ff Rl ntw I tjn sides of start'ing-system TR 2 19 224.
.Changed 4-way valve-WD 1 A'0 '1 1.1
'aw 4vJ/a@
'-: Cle'a'ned sealing. surface TR:190893 Oil level OK TR.103183.
Ti'ghten packing nuts TR 199027 Added lo oz ~, oil Ap B'nd C MSIV anrl timed s
TR.221315
'Tightened packing TR 199026 2/26 2/26 I)".
/26 I
2/24 i ~,.- ~
t Fire Protectior D/G D/G D/G 3B fuelpool coolin um D/G 3D 3C air bank 1
Leakage Oil level too high Oil level too Clean filters'one None None Loose plug
,Unknown Unknown Pump leaking Unknown Unknown Unknown
- Tighten plug TP, 19'9149 Drained..oil to-.pioper'ropei
. TR: 219230.
Drainea oil to proper'evel
'R:219230 Cleaned, & replaced'. ai"r-yalve.
rn 91O99O,
CSSC I
UIPHENT BRONNR FERRY NUCLEAR FIANT UNLT~3Ceneinued)
HEClfANICALMAINTENANCE SUM1ARY I
I IFor the Honth of February 19 81 RATE f/25 SYSTI.'H Fire Protectio>
COl 1PONENT 8 Fire Pump
-NATURE OF HAINTENANCE,
'Bro'ken pin EFFECT ON SAFE OPERATION OF TflE REACTOR None CAUSE OF lfALFUNCTION Sheared pin at top of strainer RESULTS OF lfALFUNCTION Unknown ACTION TAKEN TO PRECLUDE RECURRENCE Replaced pin TR 204863 1(
i I
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5
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SSC E UIPfll'.
BRUUNB PURRY NUULUBR PIANT UNIT lt INSTRl&fENT MAINTENANCE SUlflfARY FOg gfE HONTll OF
- February, j9 81 SYSTEM NATURE COIifPOHEHT OF 1fAIHTENANCE EFFECT OH'AFE OPERATION OF TllE REACTOR CAUSE'F MALFUNCTION'ESULTS OF MALFUNCTION ACTION TAKEN TO PRECLUDE RECURRENCE.
IJnit l 2-~
reeawarer Cnntrn1 rri-46-48 Calibrate None T
L L n "UL~
JIISI RUIIIUIII IPLI I.I nZW RI L n fLOW IJJU IIVI VVIllitaLQ Rfnnn llVtl&
2-15 J-1 Unit 2 RHR Service Water PT-23-11'alibrate None Transmitter Froze Indicator Did-Not Agree with RedUndanlt Tntlitntnr None pt Uni.t B
PnvA Qnv Alt wL%
PilLa7 PT 75 21 Dnnn6 v
~ t% rQLL RiAnn l1Vlll Mniat.ttvn in Vvana
~ lVAVLQ Al L Lv mitter Tndinat ed Plow fJi th Pumps Off None 2v3 Containment Inerting PIC-76-.94 Clean None Hoist'ure and Im-purities in Rotometer Co'uld Have Caused Le'ak in -Drywell Flow Problems Even- 'epaired tually jt,:.
2-5'I 2-l6 Core Spray Hain Steam Feedwater Contro)
FT-75-21 PH-75-21 PS-1-72 Calibtate Calibrate Replace None None None Instrument Drift n-JL1 T
IOSSJ.DJ.U ItUVUU Sensing Line Clamp Faulty Flow Modi-fier Indicated Flow With Pumps Off apus.XVUV II4XL LnO=
0 4
IY 1C T
lations Loss of 'Plow Indlca-t1 on None Rln 'n ItVI I'oiie I-16
'f~.
R r 2-17t':
2-,2)
RllR Service Water Primary Containment Primary PI-23-93
'I'H-64-62 TI-64-62 TR-80-1 Replace Calibrate Repair None.
None None Sensing Line Proze Gage Indicated Full Scale
'V
~ 1L 0
I'UJ.I 7 LPUL VV Motor UIJ1 6 VII~ I s ltltti.l GLED 61 1 n 4
~
T A4 nt'n Same Temperature.
Instrument Drift Indicators Did Not Agree None None Mnnn nVLB
37 OUTAGE
SUMMARY
February 1981 Preparations are in progress for the Unit 1 end-of-cycle 4 refueling outage and the Unit 2 short outage both of which are scheduled to begin in April.
The Unit 1 outage includes extensive torus modifications and internal reactor vessel work.
Preliminary installations are underway for the Unit 2 station'ervice transformer, permanent connections to the main generator busses and 4kV boards will be made during the upcoming Unit 2 short outage.
The major emphasis of outage preparation and other ongoing work includes:
1.
Preparation for piping tie-ins to the two recently constructed condensate storage tanks are underway.
Sandblasting is in pro-
-2.
gress on the tanks in preparation for coating.
-Fire-protection system installation at the pump intake structure.-
3.
Refuel Floor a.
Tool and equipment checkout and refurbishment.
b.
Removal of existing fuel racks in the Unit 1 spent fuel storage pool for replacement with high density fuel storage system modules.
c.
Repairs to the reactor building overhead crane cable cat-track.
d.
Receipt of new fuel.
~f 1