ML18094A061

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Monthly Operating Rept for Feb 1980
ML18094A061
Person / Time
Site: Browns Ferry  Tennessee Valley Authority icon.png
Issue date: 03/01/1980
From: Thom T
TENNESSEE VALLEY AUTHORITY
To:
Shared Package
ML18024B401 List:
References
NUDOCS 8003180380
Download: ML18094A061 (34)
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TENNESSEE VALLEY AUTHORITY DIVISION OF POMER PRODUCTION BROGANS FERRY NUCLEAR PLANT MONTHLY OPERATING REPORT February 1, 1980 February 29, 1980 DOCKET NUMBERS 50-259, 50-260, AND 50-296 LICENSE USERS DPR-33, DPR-52, AND DPR-68 Submitted By: ~. 4, . 'f, ~

Plant Superintendent G

TABLE OF CONTENTS Operations Summary ~ ~ ~ 1 Refueling Information ~ ~ ~ 3 Significant Operational Events ~ ~ ~ 5 Average Daily Unit Power Level ~ ~ ~ 10 Operating Data Reports ~ ~ ~ ~ ~ ~ 13 Unit Shutdowns and Power Reductions. ~ ~ ~ 16 Plant Maintenance ~ ~ ~ 19 Outage Summary ~ ~ ~ 30

0 erations Summar February 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 (plus two supplemental reports) reported to the NRC during the month of February.

Unit 1 Unit 1 was in its scheduled refuel outage (EOC-3) during the entire month.

Unit 2 There were three scrams on the unit during the month. On February 10, 12, and 15, the reactor scrammed due to unknown reasons. The unit was placed in hot standby after the February 15 scram until investigations and recommendations could be completed on the unexplained scrams. On February 21, the unit was placed in cold shutdown due to HPCI being inoperable.

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

0 erations Summar (Continued)

February 1980 Fati ue Usa e Evaluation The cumulative usage factors for the reactor vessel. are as follows:

Location Usa e Factor Unit 1 Unit 2 Unit 3 Shell at water line 0.00423 0.00323 0.00291 Feedwater nozzle 0. 20361 0.13883 0.10715 Closure studs 0.18265 0.11671 0.08728 Note:. This accumulated -monthly information satisfies technical specification section 6 '.A.17.b(3) reporting requirements.

Common S stems Approximately 1.91E+06 gallons of waste liquid were discharged containing approximately 8.77E-Ol curies of activity.

Refuelin Information February 1980 Unit 1 Unit 1 began its third refueling (EOC-3) on January 3, with a projected restart date of March 7, 1980. This refueling will involve loading additional 8 x 8 R (retrofit) fuel assemblies into the core, replacing presently loaded 7 x 7 fuel, LPCI modifications, installing acoustical monitors on MSRV's, and containment isolation modifications.

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, one 8 x 8 R fuel assemblies, and 20 new P 8 x 8 R assemblies.

Because of modification work to increase spent fuel pool capacity to 3471 assemblies, present capacity is limited to 1152 assemblies.

Unit 2 Unit 2 is scheduled for its third refueling beginning on September 1, 1980, with a scheduled restart date of October 7, 1980. Resumption of operation on that date will require a change in technical specifications pertaining to the core thermal limits. Licensing information in support of these changes will be submitted to the NRC before the outage. This refueling involves replacing some more 7 x 7 fuel assemblies with 8 x 8 R (retrofit) assemblies.

There are 764 fuel assemblies in the reactor vessel. At the end of the month, there were 132 discharged cycle 1 fuel assemblies and 268 discharged cycle 2 fuel assemblies in the spent fuel storage pool. The present storage capacity of the spent fuel pool is 1080 assemblies. With present capacity,

Refuelin Information (Continued)

February 1980 Unit 2 (Continued) the 1979 refueling would be the last refueling that could be discharged to the spent fuel pool without exceeding that capacity and maintaining full core discharge capability in the pool.

Unit 3 Unit 3 is scheduled for its third refueling beginning on October 17, 1980, with a scheduled restart date of November 22, 1980. Thi's EOC-3 refuel-ing involves loading additional 8 x 8 R (retrofit) assemblies into the core.

There are 764 fuel assemblies presently in the reactor vessel. There are 144 discharged cycle 2 fuel assemblies and 208 discharged cycle 1 fuel in the spent fuel storage pool. The present storage capacity of 'ssemblies the spent fuel pool is 1528 assemblies. With present capacity, the 1980 refueling would be the last refueling that could be discharged to the spent fuel pool without exceeding that capacity and maintaining full core discharge capability in the pool.

Si nificant Operational Events Unit 1 Date Time Event 2/01/80 0001 Unit in refueling outage (EOC-3) 2/04/80 1912 Fuel loading completed, commenced fuel resipping of sus-pected fuel leakers 2/06/80 1920 'Fuel resipping handling completed, refuel outage continues 2/29/80 2400 Refuel outage in progress (EOC-3)

Si nificant Operational Events Unit 2 Date Time Event 2/01/80 0001 Reactor thermal power at 98%, sequence "B", max flow (rod limited),

1300 Reduced thermal power from 98% to 75% for tests on "C" reactor feedpump turbine 1628 Tests on "C" reactor feedpump turbine completed, commenced power ascension 1800 Commenced PCIOMR from 95% thermal power 2300 Reactor thermal power at 98%, max flow (rod limited) 2/02/80 0022 Reduced thermal power from 98% to 80% for turbine CV tests and SI's 0120 Turbine CV tests and SI's completed, commenced power ascension 0530 Commenced PCIOMR from 90% thermal power 1712 Reactor thermal power at 98%, max flow (rod limited) 2/03/80 0805 Reduced thermal power from 98% to 50% due to "B" recircu-lation pump trip 1620 Commenced thermal power increase with one recirculation pump in service 2035 "B" recirculation pump placed in service, commenced power ascension 2147 Commenced PCIOMR from 73% thermal power 2/04/80 1627 . Reactor thermal power at 98%, max flow (rod limited) 2/06/80 0420 Reduced thermal power from 98% to 75% due to "B" recircu-lation pump trip and "A" discharge valve went closed ("A" recirculation pump tripped also) 0500 "B" recirculation pump placed in service, commenced power ascension 0632 "A" recirculation pump placed in seivice 0710 Commenced PCIOMR from 90% thermal power 1230 Reduced thermal power from 95% to 50% due to "A" recircu-lation pump trip (manual) 1610 "A" recirculation pump placed in service, commenced power ascension 1750 Commenced,PCIOMR from 90% thermal power 2300 Reactor thermal power at 98%, max flow (rod limited) 2/09/80 0010 Reduced thermal power from 98% to 75% for turbine CV tests and SI's 0115 Turbine CV tests and SI's completed, commenced power ascen-sion 0555 Commenced PCIOMR from 95% thermal power 1500 Reactor thermal power at 98%, max flow (rod limited)

Si nificant 0 erat'ional Events Unit Date Time Event 2/10/80 1612 Reactor scram no. 92 from 98% thermal power, reason unknown 2015 Commenced rod withdrawal 2225 Reactor critical no. 103 (sequence "A")

2/11/80 0155 Rolled T/G 0220 Synchronized generator, commenced power ascension 2330 Commenced PCIOi~ from 68% thermal power 2/12/80 0820 Reactor scram no. 93 from 74% thermal power, reason unknown 2015 Commenced rod withdrawal (sequence "A")

2227 Reactor critical no. 104 2/13/80 0155 Rolled T/G 0213 Synchronized generator, commenced power ascension 2300 Commenced PCIOIR from 55% thermal power 2/15/80 1328 Reactor scram no. 94 from 65% thermal power, reason unknown, reactor held in hot standby during scram investigation 2/18/80 1530 Commenced rod withdrawal 1645 Reactor critical no. 105 (sequence "A")

2/19/80 2140 Reactor made subcritical, holding at hot standby (HPCI in-operable) 2/21/80 2320 Reactor in cold shutdown (HPCI inoperable) 2/29/80 1300 HPCI operable holding due to primary containment leakage 2400 Reactor in cold shutdown due to primary containment leakage

Si nificant 0 erational Events Unit 3 Date Time Event 2/01/80 0001 Reactor thermal power at 98%, sequence "A", rod limited 1052 Reduced thermal power from 98% to 70% due to excessive fish impingement on the condenser circulating water (CCW) pumps traveling screens 1230 Fish impingement cleared from CCW pumps traveling screens, commenced power ascension 1500 Commenced PCIOMR from 93% thermal power 2345 Reduced thermal power from 98% to 80% for main turbine vibration checks 2/02/80 0030 Main turbine vibration checks completed, commenced power ascension 0400 Reactor thermal power at 90%, holding for control rod exercise SI 0500 Control rod exercise SI completed, commenced PCIOMR 1300 Reactor thermal power at 96%, "C" reactor feedpump on "hold" due to high vibration 2130 Reduced thermal power from 96% to 80% for removal of "C" reactor feedpump from service due to high temperature on inboard turbine bearing 2/04/80 1925 "C" reactor feedpump maintenance completed and pump placed in service, commenced power ascension 2030 Commenced PCIOMR from 90% thermal power 2/05/80 0720 Reactor thermal power at 98%, max turbine load 2/08/80 1025 Commenced power ascension 1500 Reactor thermal power at 99%, max turbine load 2/10/80 0005 Reduced thermal power from 99% to 80% for turbine CV tests and SI's 0156 Turbine CV tests and SI's completed, commenced power ascension 0230 Commenced PCIOMR from 90% thermal power 1700 Reactor thermal power at 99%, max turbine load 2/17/80 2355 Reduced thermal power from 99% to 85% for turbine CV tests and SI's 2/18/80 0030 Turbine CV tests and SI's completed, commenced power ascension 0230 Commenced PCIOMR from 95% thermal power 2/21/80 1500 Reactor thermal power at 99%, max turbine load 2/22/80 2130 Reduced thermal power from 99% to 42% for control rod sequence exchange from "A" to "B"

Significant 0 erational Events Unit, 3 Date Time Event 2/23/80 0140 Control rod sequence exchange from "A" to "B" completed, commenced power ascension 1600 Commenced PCIOMR from 75% thermal power 2/24/80 2300 Reactor thermal power at 99%, at max flow (rod limited) 2/29/80 2400 Reactor thermal power at 99%, at max flow (rod limited)

10 AVERAGE DAILYUiNIT POWER LEVEL DOCKET NO 50 259 UNIT Bgowtts Ferry 1 DATE COMPLETED BY TELEPHONE 205/729-6846 Februa 1980 DAY AVERAGE DAlLYPOWER LEVEL DAY AVERAGE DAILYPOWER LEVEL (MWe-Net) (ilIWe.Net) ~

17 18

..3 19 20 21 22

-7 7 23 8 , 24 9 25 10 26 ll 27 12 28 13 29

-10 30 IS 31 l6 INSTR UCTIONS On this forinat.!ist the average daily unit pi>wer levci'n ill'tVe iNet for each day in the reporting iniinth. Ciiinpute to the nearest whole megawatt.

(<) f77 I

AVERAGE DAILYUiVIT POWER LEVEL DO.CKET NO. 50-260 UNIT Browns Ferry 2

.\

DATE COMPLETED BY TELEPHONF 205/729-6846 MONTH Februar 1980 DAY AVERAGE DAILYPOWER LEVEL DAY AVERAGE DAILYPOWER LEVEL (MWe-Net) (MWe.iVet) ~

I 1016 -13'7 1028 18 -13'13

..3 779 19 1048 -13 20 1068 21 -13 904 22 -10 7

1067 -10 1064 24 -10 1043 25 -10 10 - 26 525 27 12 249 28 13 473 29 639 14 30 IS 359 31 16

-13 INSTR UCTIONS On this for>nat.!1st the average daily unit p<>wer lcvei'n ~Ice.iVet for each day in the rept>rting tni>nth. Compute to the nearest whole n>e,awat t.

(9/77)

12 AVERAGE DAILYUiVIT POWER LEVEL DOCKET NO.  : 50-296 UNIT ry 3 DATE COhIPLETED BY Don Green TELEPHONE 205/729-6846 MONTH Februar 1980 DAY AVERAGE DAILYPOWER LEVEL DAY AVERAGE DAlLYPOWER LEVEL (MWe-iVet) (MWe iVet) ~

I 1021 17 1098 997 18 1054

..3 879 19 1055 905 20 1086 1063 21 1076 1071 22 1033 1074 23 779 74 970 1083 25 1071 10 1055 26 1100 1076 27 1066 12 28 13 1089 29 1072 I4 30 IS 1073 31 16 1076 INSTR UCTI0 VS On this format.!ist the avera8e daily unit oiiwer lever in hIWe.iVet for ea<<h tiay in the reportine montti. Ciimpute to the nearest whole megawatt.

13 4

OPERATING DATA REPORT DOCKET NO.

DATE 3l1PK Dna~

COMPLETED BY TELEPHONE ~~846 OPERATING STATUS Notes

1. Unit Name:
2. Reporting period: Februar 1980
3. Licensed Thermal Power (ilIWt):
4. Nameplate Rating (Gross MWe): 1152
5. Design Electrical Rating (Net MWe):
6. Maximum Dependable Capacity (Gross MWe): 8.4
7. Maximum Dependable Capacity (Net MWe):
8. IfChanges Occur in Capacity Ratings (Items Number 3 Through 7) Since Last Report, Give Reasons:
9. Power Level To Which Restricted, If Any (Net i<IWe):
10. Reasons For Restrictions, If Any:

This Month Yr.-to-Date Cumulative 696 1440 48',938

11. Hours In Reporting Period 0 71.7 28,348.98
12. Number Of Hours Reactor Was Critical 0 0 4,689;61
13. Reactor Reserve Shutdown Hours 0 71. 7
14. Hours Generator On. Line Unit Reserve Shutdown Hours i 0 0

~ 15.

Gross Thermal Energy Generated (MWH) 0 23 547 973 74 320 645 16.

17. Gross Electrical Energy Generated (ilIWH) 0 61 960 24,580,420 Net Electrical Energy Generated (MWH) 57 164 23 859 132 18.

Unit Service Factor 0 5.0 56.6 19.

Unit Availability Factor 0 5.0 56.6.

20.

Unit Capacity Factor (Using <i(DC Net) 0 3.7 21.

0

22. Unit Capacity Factor (Using DER Net) 0 0 32. 9
23. Unit Forced Outage Rate
24. Shutdowns Scheduled Over i <ext 6 Months (Type, Date. and Duration of Each):
25. If Shut D<iwn At End Of Report Period, Estimated Date of Startup: March 7 1980
26. Units In Test Status (Prior to Commercial Operation): Forecast Achieved INITIAL CRITICA LITY INITIAL ELECTRICITY CO!<IMERCIALOPERATION (o/77)

OPERATING DATA REPORT DOCKET NO. 55-260 DATE COilIPLETED BY ~'~zaon TELEPHONE -6846 OPERATING STATUS Notes I. Unit iVame.

2. Reporting Period: n
3. Licensed Thermal Power (tlIWt):
4. iVameplate Rating (Gross tlIWe):

S. Design Electrical Rating (Net MWe):

6. Maximum Dependable Capacity (Gross ttIIVe):
7. Maximum Dependable Capacity (Net ilIlVe):
8. IfChanges Occur in Capacity Ratings (Items Number 3 Through 7) Since Last Report, Give Reasons:

h

9. Power Level To lVhich Restricted, IfAny (Net tliWe):
10. Reasons For Restrictions, If Any.

This iWIonth Yr..to.Date Cumuhtive

12. Number Of Hours Reactor Was Critical 358.05 1 102.05
13. Reactor Reserve Shutdown Hours 0 0 ~

11 774.94

14. Hours Generator On-Line 321.45 1,065.45 , .24,729..78 0 0

<< IS. Unit Reserve Shutdown Hours

16. Gross Thermal Energy Generated (MlVH) 901 327 25 702 650 69 154 438
17. Gross Electrical Energy Generated (illlVH) 295 280 1 001 450 22 951 518
18. Net Electrical Energy Generated (MlVH) 283,856 972,837 22.,304,306
19. Unit Service Factor 46.2 74.0 56.4
20. Unit Availability Factor 56.4
21. Unit Capacity Factor (Using MDC Net) 38.3 63.4 47.8
22. Unit Capacity Factor (Using DER iVet) 38.3 63.4 47.8
23. Unit Forced Outa <e Rate 53.8 26.0 36.4
24. Shutdowns Scheduled Over Next 6 illonths (Type. Date. and Duration uf Each):
25. If Shut Down At End Of Report Period, Estimated Date of Startup:
26. Units In Test Status {Prior to Commercial Operation): Forecast Achieved IN ITIAL CRITICALITY INITIAL ELECTRICITY CORDI ERCIA L OP ERATIOiV

OPERATING DATA REPORT DOCKET NO.

DATE COMPLETED BY

~K 50~296

~Drive'n TELEPHONE 2Q5L~846

~

OPERATING STATUS Notes

1. Unit Name:
2. Reporting Period: ebruar 0
3. Licensed Thermal Power (MWt): 3293
4. Namephte Rating (Gross MWe):

1065

5. Design Electrical Rating (Net MWe):

t *..; ~

7. Maximum Dependable Capacity (Net MWe):
8. IfChanges Occur in Capacity Ratings (Items i(umber 3 Through 7) Since Last Report, Give Reasons:

N A

9. Power Level To Which Restricted, If Any (Net MWe):
10. Reasons For Restrictions, If Any: N/A This Month Yr.-to Date Cumulative 11 Hours In Reporting Period 696' 440 26'04 12 Number Of Hours Reactor Was Critical

. 696 1 028.43 19 935.98 13 Reactor Reserve Shutdown Hours 0 0 1,658;31 14 Hours Generator On. Line 696 ~ 1,004.93 1'9 '442.74

<<15 Unit Reserve Shutdown Hours 0 0 0 16 Gross Thermal Energy Generated (MWH) 2 199,842 20 068 684 56 220 066 17 Gross Electrical Energy Generated (MWH) 743,940 1,049,920 18,452 500 18 Net Electrical Energy Generated (MWH) 725,906 1,020,188 17,907,961 19 Unit Service Factor 100 69. 8 73.9 20 Unit Availability Factor 100 69.8 73.9 21 Unit Capacity Factor (Using MDC Net) 3.9 Unit Capacity Factor (Using DER Net) 97.9 66.5 63.9 Unit Forced Outage Rate 30.2 10.4 23 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 In Test Status (Prior to Commercial Operation): Forecast Achieved IN ITIAL CR ITICALITY INITIAL ELECTRICITY COAIMERCIA L OPERATION (o/77)

4 DOCKET NO. 50-259 UNIT SIIUTDOWNS AND POWER REDUCTIONS UNIT NAhlE Browns Ferr 1 DATE Feb<<<<y COhIPLETED OY REPORT hIONTII 205 72 -6846 TELEPI ION E C rr Lice nscc 'Cause Ec Corrective Nii. Dare I Vl Event Action Io J

Rcport 0' Prcvcnt Rccurrcnce

'efueling

~ tt 108 800201 S 696 C (Lilac) 3 4 F: Forced Reason: hlcthod: Exhibit G - Instructions S: Scl) cd t ilcrI A.Equipment Failure (Explain) I hlanual for Preparation of Data II hlaintenancc oi Test 2 hianual Scram. Entry Shccts I'or Licensee C-Rcfuclint; '-Automatic Scram. Event Report File(NUREC-D.lteturiatory Restriction 4.Other (Lxplain) OI 6I )

L'perator Trainint; h. Liccnsc Examination F-Administrative C.Opera lr vnal Lrror (Explain) 5'xhibit I - Sante Source Vt/77) II Other (Explain)

UNIT SIIUTDOWNS AND POWER REDUCTIONS DOCKET NO. 50-260 UNIT NAME DATE 3180 COhlPLETED BY Don Creen REPORT hfONTH TELEPI IONE gr E

r> A

~ A Licenscc 'Cause &, Corrc>.tive N>>. I

~

n fl 2 ~cd Event Action to CJ Q

Ii> Report 8 ~

Prevent Rccurrcncc 117 800201 ' A Derated for tests on "C" Rx feedpump I

turbine 118 800203 Derated "Bu recirc um tri ed 119 800206 Derated "B" recirc pump tripped and "A" recirc um dischar e valve closed 120 800206 A Derated when "A" recirc um tri ed 121 800209 Derated for turbine CV tests and SI's 122 800210 F 10.13 Unknown 123 800212 F 17.88 H Unknown 124 800215 F 346.54 Unknown -"Unit remained down for maintenance to HPCI 4

F: Forced Reason: hlethod: fj>d>ibit G - Instructions S: Scl><<d<<lcd A.L'Iluipment Failure (Explain) I-hIanual C>r Preparatiun of Data lt-hlaintenance or Test Scram.

'.hlanual Entry Shccts for Li<<cnsec

( . I(c I I >c I >I >g 3-Automatic Scram. Event Report (I.I!R) File IWOREG-D )tet,ulatory Restriction 4.0tl>cr (Lxplain) ~

DI6l )

I'..Ol>cr;Ilof Training Sc Liccnsc Examination I -AJ>ninist rat ivc G.OP<<rational Lrror (Explain) 5'xhibit I - Sante Source

('I/77) I I Otl>cr (I'.xplain)

DOCKET NO. 50-296 UNIT SIIUTDOWQS AND POWER REDUCTIONS UNIT N Ahl E DATE COhlPLETEI) IIY REPORT hlONTII TELEPIIONE 205 729-68lr6 lr A ~

Licen sec CN 'Cause 4, Corrective 4l 4l l)alc c qM Evenl Vl Action lo

~ l/) Rcporl ¹ ~ cn Cr Prevent Recurrence 116 800201- Derated due to excessive fish impingement on CCM pumps traveling water screens 117 800222 S Derated for control rod sequence exchan e from oA" to "8" I

F: Forced Reason: hlethod: Exhibit G - Instructions S: Scil<<dtded A.Equipment Failure (Explain) I.hlanual for Preparation or D.la II-hlaintenance oi Test 2-hlanual Scram. Entry Shccls for Licellsce C.Rctucliog 3.Automatic Scram. Event Report (LER) File(NOI(EG-D Regulatory Restriction 4 Otltcr (Explain) OI 6 I )

I:.-Operator Training I, License Exaolinalion F.Adnli>>islralivc G.Operational Lrror (Explain) Exhibit I - Sante Source

('t/77) I I Olh<<r (Explain)

BROWNS FERRY NUCLEAR PLANT UNIT '

CSSC FnUIP;fENT  ? fECHANICAL I fAINTENANCE SUI fMARY EFFECT ON SAFE ACTION TAKEfl SYSTi I CON POiaiENT NATURE OF OPERATION OF CAUSE OF RESULTS OF TO PRECLUDE IfAINTENANCE TilE REACTOR IfALFUNCTION MALFUNCTION RECURRENCE 2/5 HPCI Barometric gP high None Dirty strainer Cleaned strainer Strainer- cleaned cond. strainer TR 137594 2/5 RCIC Cunc} filter Water content None Water content Contaminated oil Cuno filter cleaned and and oil too high too high oil changed.

TR 137590 2/5 RCIC Magnetic IIMI 22 None Worn magnetic Improper pickup Installed new pickup pickup magnetic pickup TR 137592 .

2/5 Off-Gas FCV 66-94 Sticking and None Bad solenoid Replaced solenoid Installed new leaking valve valve solenoid valve.

throu h TR 142975 2/5 CRD "A" suction High QP None Dirty filters. High diff. press. Installed new filter@

filter TR 151276 2/7 Feedwater 18 feedwater Will not seat None Machine surfaces Leaking through Removed .30" off check valve mismatching inner face of seat TR 144704 2/8 Core Spray 1A drain pump Packing None Tom seal Leaking seal Replaced seal leakin TR 107314 2/9 EECW FCV 67-50, 51, Dirty None Dirty strainer Strainer dirty Installed new

'/12 2/14 SI.C CRD and -53 PRV FCV FCV 63-513 85-11A 85-11B strainers Improper relief ressure Leaking through None None Relief press.

set too high Service Relief press. too high pitted strainer.

Corrected set press.

TR 151066 TR 13020&

relief Roller disc worn and Replaced roller discs TR 142971 t

2/16 RCIC Turbine Inspection None Unknown Strip paint and PT DED analyzing problem Pedestals for cracks TR 153007 2/16 R11R FCV 74-71, -72 Leaking None Loose packing Packing loose Tightened packing

-73 ackin TR 142370 2/21 CRD "B" suction High None Dirty filters. diff. press.

'igh Installed new filters filter TR 153124 I

BROWNS FERRY NUCLEAR PLANT UNIT 2 CSSC E{SUIPHEllT HECiIAIiICAL HAIN'i'ENANCE SUI DIARY For thc Honth of February 19 80 EFFECT ON SAFE ACTION TAKEN DATE SYSTCH COHPGNENT NA'lli7Z OF OPERATION GF CAUSE OF RESULTS OF TO PRECLUDE HAINTENAKCE THE REACTOR HALFUNCTION HAI.FUNCTION RL'CURRFNCE 2/6 HPCI Ruptured disk Ruptured disk None Disk ruptured Blown disk Installed inner and outer disk.

2/11 CRD "B".discharge Dirty filter None Dirty filter High diff. press. Installed new filter filter 2/12 CRD Hodule 50-31 Air leak None Tubing leak Control air supply Installed new tubing reduced due to leak 2/16 HPCI and Turbine pedes- Remove paint None Unknown Removed paint and PT DED analyzing piping RCIC tal for cracks problem. TR 146604 2/19 HAIN Steam FCV 1-146 Binding None Service Packing gland binding Leveled and tightenedg against valve stem gland lub. stem TR 151688 2/26 HPCI FCV 73-18 oil leak None Loose flange Oil leak Tightened flange TR 142586 2/28 EECW FCV 67-50, -51 Dirty None Dir'ty strainer High diff. press. Installed new filters and 53 strainer TR 130214

BROWNS FERRY NUCLEAR PIAilT UNIT 3 HECHANICAL HAINTENANCE SUI MARY For the Honth of Feb 1980 EFFECT ON SAFE ACTION TAKEN SYSTEH COHPONENT NATURE OF OPERATION OF CAUSE OF RESULTS OF io PRECLUDE HAINTENANCE THE REACTOR HALFUNCTION HALFUNCTION RECURRENCF.

2/2 Diesel Heat exchanger Clean heat None Dirty strainer Differential pressur Cleaned coolers and Generator I I 3AII exchanger reduced installed new gaskets TR 158735 2/5 EECN FCU 67-50, -51 Inspect strai None Dirty strainer Differential pressur Cleaned strainers and -53 ers for clean reduced TR 130217 liness 2/8 CRD Pdls 85-72 Lines piped None Lines crossed Reverse readings Uncrossed lines up wrong TR 140246 2/16 HPCI and Inspect for None Inspection No cracks found DED study of h7 RCIC Turbine cracks system. TR 146605 Pedestals 2/19 IIPCI Steam trap Appears to None None Steam trap works None. TR 161589 be stopped up correct 2/22 Diesel 3D D/G cooling Clean coolers None Clams accumulated Decrease in flow rate Cleaned both coolers Generator water in coolers per HRI-303 and installed new gas-kets. TR 136906 2/25 HPCI FCU 73-16 Stem packing None Loose packing Steam leak Tightened packing leak gland nut TR 145039

BRO!HIS FERRY NUCLEAR PLANT UNIT 1 ELECTRICAL MAINTENANCE SlMfARY Not previously reported.

E ect on ate Action Taken Date System Component Nature of Operation of Cause of Results of To Preclude Haintenance The Reactor Halfunction i~falfunction Recurrence 1/24/80 SI 4 '.B- SI 4.2.B-44 Perform SI None Bad relay Relay 2E-K34 would Replaced relay 2E-K34, 44 4.2.B-44 ADS not time properly timed out correctly timer cali- would only time out performed SI 4.2.B-44 bration (sec. to. 93 seconds max. and SI 4.2.B-44A.

4,4) TR l43422 LER BFRO-50-259/813 1/25/80 Reactor SI 4.2.A-16 Perform SI 4. None Bad relay RelaY RlB sticking Replaced relay RjB, building 2.A-16 reactor performed SI 4.2.A-16 building iso- OK. TR 143418 lation timer LER BFRO-50-259/807 calibration (refuel floor reactor bldg.)

BROOKS PERRX NUCLEAR PLRET UUZT CSSC E UIPlKNT ELECTRICAL MINTENANCE Sl&kfARY E ect on a e Action Taken System Component Nature of Operation of Cause of Results of To Preclude Haintenance The Reactor. Malfunction R~lalfunction Recurrence 2/2/80 Reactor FCV-1-68-79 Perform EHI None Rotor cracked Rotor cracked Performed EHI 16 and I

water re- 16.and 18 on 18, replaced cracked circula- FCV-1-68-79 rotor. TR 140428 tion 2/3/80 HCV-1-74-49 HCV-74-49 bad'ad open- limit switch full None limit switch Limit switch tor was broken actua- Replaced actuator.

limit switc TR 139563 2/3/80 FCV-74-59 Limits out of None Bad rotor L'imits out of ad- Replaced rotor, and adj ustment justment performed EMI 18, valve checked OK.

TR 143432 2/4/80 Core spray HCV-75-12 HCV-74-12 Hone Limit switch out Limit switch loose Tightened limit cooling green light of adjustment switch, lights work-limit switch ing OK. TR 151270 is loose, light. goes out each time run A or C core spray pumps r

2/7/80 R)lR 74-49 open 74-49 open None ad limit switch Incorrect indication Replaced limit switch limit switch limit switch lights worked OK.

has red light TR 151287 with, valve closed

RRORRR FERRY RUOLEAR PLP$ Y URLY CSSC E UIBKNT ELECTRICAL MAINTENANCE SmkfARY ect on a e Action Taken Date System Component Nature of Operation of 'ause, of Results of To Preclude The Reactor. Malfunction Malfunction Recurrence Maintenance 2/8/80 Dr~sell 1B-2 Drywell 1B-2 drywell None Bad-motor Drywell blower motor Motor was sent to blower blower motor blower. motor. was grounded service shop to be has a ground rewound per EHI 33, on it motor returned to service. TR 124276 I

2/10/80 Fuel pool deminerali FCV-78-7 . FCV-.78-7 .con-cooling & control switch trol switch on local panel None.

'f Limit switch out Limit switch out of Ad)usted limit switch, ad)ustment ad)ustment light now indicates correctly. TR 151289 sation showing closed position with both red and green light 2/11/80 Contain- FCV-76-17 Open limit None Bad limit switch Limit switch out of Read)usted limit ment lights stay'n

~

ad)ustment switch, checked OK.

inerting sometimes TR 161177 I when valve is fully closed '.-

2/12/80 RHR ICV-74-33 RHR B HTX'man- one Bad switch Micro-switch stuck Replaced switch ual discharge closed, condition of checked OK. TR valve lights switch was rust and 147890 ot indicating corrosion entire orrectly switch was bad

BRO.its FERRY NUCLEAR PLANT UNIT ELECTRICAL >IAINTENANCE SUIIIIARY For the lfonth of, February 19 80 E ect on a e Action Taken Date System Component Nature of Operation of Cause of Results of To Preclude Haintenance The Reactor Malfunction ifalfunction Recurrence 2/14/80 MIR HCV-23-49 MIR switch None Bad switch Operator on switch Readjusted operatpr heat exchange out of adjustment and switch and light inlet valve worked good. TR limit switch 152109 is bad l2/17/80 Control lA control lA control bay None Contacts stuck Auxiliary contacts Freed and lubricated bay bay air hand- air handling stuck in ACB for air auxiliary contacts, ling dis- discharge dam- handling unit fan damper worked properl charge damper per not open- motor TR 147888 ing up 2/17/80 CRD )IS-85-48 CRD control Hone Bad switch Stop on plate broken Replaced with. new switch stops off plate. Checked OK.

broken TR 152128 2/17/80 Battery 48V main bat- 48V main bat- None Bad battery Bad coil in main Replaced coil system, I charger tery charger tery charger- charger contactor relay worked OK. TR 152130 no output I2/18/80 RCIC FCV-71-14 RCIC turbine None Limit switch out Limit switch not Reassembled limit exhaust isola- of ad)ustment giving proper indi-. switch, ad)usted tion valve cation limit lights, worked limit switch OK. TR 151012 does not work properly

VRVLYIS PERRY RVCLEAR PLPRT VRIT CSSC E UIPMENT ELECTRICAL MAINTENANCE SALARY For the!month of February ]9 80 E iect on a e, Action Taken Dct System Component Nature of Operation of Cause of Results of To Preclude Maintenance The Reactor Malfunction Malfunction Recurrence 2/23/80 Hain Inspect and Inspect and None Bad limit switch One limit switch on Adjusted arm on steam adjust all adjust all FCV-1-74 not open limit switch and it limit limit switches operated. Checked 0 switches on FCV-1-74, TR 145384

-78, and -84 prior to stop valve 2/26/80 Control Control room Control room None Bad motor Motor bad burned Pulled motor and room air handling air handling up sent to service shop, unit lA unit lA motor reinstalled motor, burned up checked OK. TR 151065 i2/24/80 Contain- FSV-1-84-19 Switch out of None Bad limit switch Lights not indicatin Made adjustment on I ment atmos adjustment properly operator arm, lights phere dilu functionally checke" tion OK. TR 151014 2/26/80 Primary FCV-64-141 Limit switch one Bad limit switch Limits were out of Adj us ted limits, containmen limit switch needs adjustin adjustment working properly, TR 151002 g

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EEOVHE PElVlP EVOLEAE PLEHT VVIT 3 l

CSSC E UIPMENT ELECTRICAL MAINTENANCE SIMfARY E ect on a e Action Taken D" te Nature of Operation of Cause of Results of To Preclude System Component Malfunction Recurrence Maintenance The Reactor Vclfuncciun 12/12/79 RCIC Replace EGM EGM control None Bad potentio- RCIC unable to Replaced EGM box.

Not pre- control box box meter on high reach rated flow. and calibrated viously trim of EGM per EMI 37, tested reported OK. TR 146708, LER BFRO-50-296/

7926 2/3/80 3EA die- Battery ex- Battery ex- None Bad bearing Bearing bad in Replaced bearing sel gene- haust hood hause hood motor checked rotation rator fan for 3EA fan for 3EA fan running quietly.

diesel has Checked OK. TR 151575 03 bad bearing 2/6/80 R1lR FCV-74-73 Motor trips None Tooth broken End bell loose on Drilled out broken out when try- off gear in, motor because of bolt, replaced ing to run limit switch loose bolts and one broken limit broken bolt into switch gear, put stator, motor trip- motor back togethe ping out checked to verify not overloading afte repair, completed EMI 16 and 18.

-Checked OK. TR 145241 2/23/80 Main Main steam Check out test one Bad transformer Variable transformer Changed out trans-steam line high circuit for bad on 29/229 former in panel 29-temperature main steam lin 229, checked by SI switches high tempera- 4 '.A.8. TRP147682 ture switches ~

on panel 25-229

BROiRlS 1'ERRY NUCLEAR PLAIT UNIT l~ 2 < 3 INSTRlNiENT 1 fAINTENANCE SlMiARY CSSC E UIPMENT NATURE EFFECT ON SAFE CAUSE ACTION TAKEN DATE SYSTEM CO~ilPONENT OF OPERATION OF OF RESULTS OF TO PRECLUDE MAINTENANCE THE REACTOR MALFUNCTION MALFUNCTION RECURRENCE Unit ]

2-15 Radiation RR-90-252 Repair None Faulty Amplifier No Pen Movement None lonitoring Card Unit

'-11 Standby LI-63-1A Calibrate None Instrument Drift Did Not Agree With None Liquid Con- Redundant Indicator trol 2-24 Rod positio probes 22-15, Replace None Grounded Switches 07 Superimposed On None Information 50-27 Visual Display Unit

.Drift Inc'orrect Indication

'-6 RllR Service PI-23-4 Calibrate None Instrument None Water 2-7 Feedwater LM-3-53 Replace None Non-Linear Modi- Indicated 4" Higher None fier Than Redundant 2-21 Fire Pro- PI-26-87B Calibrate None Instrument Drift Did Not Give Correct None tection Indication 2-25 Radwaste FT-77 "16. Calibrate None Instrument Drift Indicated Flow With None

- Pumps Off

30 OUTAGE SUciRY February 1980 During this reporting period, the fuel loading on Unit 1 was completed.

The reassembly of the reactor vessel was completed and is now ready for the RPV hydro, scheduled to begin after repairs to the RWCU system suction piping are complete. Several unanticipated events caused the outage to drop several days behind schedule. Among these were: having to wait for a control rod pattern from General Electric to run a shutdown margin test prior to vessel reassembly; critical-path time for repairs to feedwater line check valves; replacement of a RWCU suction line elbow due to a crack identified by radio-graphy; as well as replacement of both HPCI turbine pedestals. Presently, repairs are underway on the RWCU suction line as well as replacement of both governor and coupling end bearing pedestals on the HPCI turbine. The HPCI pedestal replacement has been identified as the critical-path work item with a new on-line date of March 15; 1980.

Nonoutage related work on the Unit 3 condenser pullout area radwaste storage modi.fication, the hypochlorite modification, condensate storage tank modification, cooling tower modifi.cations, and security modifications is continuing.

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