ML18094A061
| ML18094A061 | |
| Person / Time | |
|---|---|
| Site: | Browns Ferry  |
| Issue date: | 03/01/1980 |
| From: | Thom T TENNESSEE VALLEY AUTHORITY |
| To: | |
| Shared Package | |
| ML18024B401 | List: |
| References | |
| NUDOCS 8003180380 | |
| Download: ML18094A061 (34) | |
Text
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, G ~
Plant Superintendent
TABLE OF CONTENTS Operations Summary Refueling Information Significant Operational Events Average Daily Unit Power Level
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3
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5
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10 Operating Data Reports Unit Shutdowns and Power Reductions.
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13
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16 Plant Maintenance
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19 Outage Summary
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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 Feedwater nozzle 0.00423 0.00323 0.00291
- 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
'ssemblies in the spent fuel storage pool.
The present storage capacity of 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 2/04/80 1912 Unit in refueling outage (EOC-3)
Fuel loading completed, commenced fuel resipping of sus-pected fuel leakers 2/06/80 1920 2/29/80 2400
'Fuel resipping handling completed, refuel outage continues Refuel outage in progress (EOC-3)
Si nificant Operational Events Unit 2
Date Time Event 2/01/80 0001 1300 1628 1800 2300 2/02/80 0022 0120 0530 1712 2/03/80 0805 1620 2035 2147 Reactor thermal power at 98%, sequence "B", max flow (rod limited),
Reduced thermal power from 98% to 75% for tests on "C" reactor feedpump turbine Tests on "C" reactor feedpump turbine completed, commenced power ascension Commenced PCIOMR from 95% thermal power Reactor thermal power at 98%,
max flow (rod limited)
Reduced thermal power from 98% to 80% for turbine CV tests and SI's Turbine CV tests and SI's completed, commenced power ascension Commenced PCIOMR from 90% thermal power Reactor thermal power at 98%,
max flow (rod limited)
Reduced thermal power from 98% to 50% due to "B" recircu-lation pump trip Commenced thermal power increase with one recirculation pump in service "B" recirculation pump placed in service, commenced power ascension Commenced PCIOMR from 73% thermal power 2/04/80 1627 2/06/80 0420 0500 0632 0710 1230 1610 1750 2300 2/09/80 0010 0115 0555 1500 Reactor thermal power at 98%,
max flow (rod limited)
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)
"B" recirculation pump placed in service, commenced power ascension "A" recirculation pump placed in seivice Commenced PCIOMR from 90% thermal power Reduced thermal power from 95% to 50% due to "A" recircu-lation pump trip (manual)
"A" recirculation pump placed in service, commenced power ascension Commenced,PCIOMR from 90% thermal power Reactor thermal power at 98%,
max flow (rod limited)
Reduced thermal power from 98% to 75% for turbine CV tests and SI's Turbine CV tests and SI's completed, commenced power ascen-sion Commenced PCIOMR from 95% thermal power Reactor thermal power at 98%,
max flow (rod limited)
Si nificant 0 erat'ional Events Unit Date Time Event 2/10/80 1612 2015 2225 Reactor scram no.
92 from 98% thermal power, reason unknown Commenced rod withdrawal Reactor critical no.
103 (sequence "A")
2/11/80 0155 0220 2330 Rolled T/G Synchronized generator, commenced power ascension Commenced PCIOi~ from 68% thermal power 2/12/80 0820 2015 2227 Reactor scram no.
93 from 74% thermal power, reason unknown Commenced rod withdrawal (sequence "A")
Reactor critical no.
104 2/13/80 0155 0213 2300 Rolled T/G Synchronized generator, commenced power ascension Commenced PCIOIR from 55% thermal power 2/15/80 1328 2/18/80 1530 1645 2/19/80 2140 Reactor scram no.
94 from 65% thermal power, reason
- unknown, reactor held in hot standby during scram investigation Commenced rod withdrawal Reactor critical no.
105 (sequence "A")
Reactor made subcritical, holding at hot standby (HPCI in-operable) 2/21/80 2320 2/29/80 1300 2400 Reactor in cold shutdown (HPCI inoperable)
HPCI operable holding due to primary containment leakage Reactor in cold shutdown due to primary containment leakage
Si nificant 0 erational Events Unit 3
Date Time Event 2/01/80 0001 1052 1230 1500 2345 Reactor thermal power at 98%, sequence "A", rod limited Reduced thermal power from 98% to 70% due to excessive fish impingement on the condenser circulating water (CCW) pumps traveling screens Fish impingement cleared from CCW pumps traveling screens, commenced power ascension Commenced PCIOMR from 93% thermal power Reduced thermal power from 98% to 80% for main turbine vibration checks 2/02/80 0030 0400 0500 1300 2130 Main turbine vibration checks completed, commenced power ascension Reactor thermal power at 90%, holding for control rod exercise SI Control rod exercise SI completed, commenced PCIOMR Reactor thermal power at 96%,
"C" reactor feedpump on "hold" due to high vibration 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 2030 "C" reactor feedpump maintenance completed and pump placed in service, commenced power ascension Commenced PCIOMR from 90% thermal power 2/05/80 0720 2/08/80 1025 1500 2/10/80 0005 0156 0230 1700 Reactor thermal power at 98%,
max turbine load Commenced power ascension Reactor thermal power at 99%,
max turbine load Reduced thermal power from 99% to 80% for turbine CV tests and SI's Turbine CV tests and SI's completed, commenced power ascension Commenced PCIOMR from 90% thermal power 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 0230 2/21/80 1500 2/22/80 2130 Turbine CV tests and SI's completed, commenced power ascension Commenced PCIOMR from 95% thermal power Reactor thermal power at 99%,
max turbine load 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 1600 Control rod sequence exchange from "A" to "B" completed, commenced power ascension Commenced PCIOMR from 75% thermal power 2/24/80 2300 2/29/80 2400 Reactor thermal power at 99%, at max flow (rod limited)
Reactor thermal power at 99%, at max flow (rod limited)
10 AVERAGE DAILYUiNITPOWER LEVEL DOCKET NO 50 259 UNIT DATE COMPLETED BY Bgowtts Ferry 1
TELEPHONE 205/729-6846 Februa 1980 DAY AVERAGE DAlLYPOWER LEVEL (MWe-Net)
..3 DAY AVERAGE DAILYPOWER LEVEL (ilIWe.Net)
~
17 18 19 20 21 7
8 9
10 ll 12 13 IS l6 22 23
, 24 25 26 27 28 29 30 31
-7
-10 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 DAILYUiVITPOWER LEVEL DO.CKET NO.
UNIT DATE 50-260
Browns Ferry 2
.\\
COMPLETED BY TELEPHONF 205/729-6846 MONTH Februar 1980 DAY AVERAGE DAILYPOWER LEVEL (MWe-Net)
I 1016 DAY AVERAGE DAILYPOWER LEVEL (MWe.iVet)
~
-13'7
..3 7
10 12 13 14 IS 16 1028 779 1048 1068 904 1067 1064 1043 525 249 473 639 359
-13 18 19 20 21 22 24 25
- 26 27 28 29 30 31
-13'13
-13
-13
-10
-10
-10
-10 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 DAILYUiVITPOWER LEVEL DOCKET NO.
UNIT DATE
- 50-296 ry 3 COhIPLETED BY TELEPHONE Don Green 205/729-6846 MONTH Februar 1980 DAY AVERAGE DAILYPOWER LEVEL (MWe-iVet)
I 1021 DAY AVERAGE DAlLYPOWER LEVEL (MWe iVet)
~
1098 17
..3 10 12 13 I4 IS 16 997 879 905 1063 1071 1074 74 1083 1055 1076 1089 1073 1076 18 19 20 21 22 23 25 26 27 28 29 30 31 1054 1055 1086 1076 1033 779 970 1071 1100 1066 1072 INSTRUCTI0VS 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 DATAREPORT DOCKET NO.
DATE 3l1PK COMPLETED BY Dna~
TELEPHONE ~~846 OPERATING STATUS 1152
- 1. Unit Name:
- 2. Reporting period:
Februar 1980
- 3. Licensed Thermal Power (ilIWt):
- 4. Nameplate Rating (Gross MWe):
- 5. Design Electrical Rating (Net MWe):
- 6. Maximum Dependable Capacity (Gross MWe):
- 7. Maximum Dependable Capacity (Net MWe):
8.4 Notes
- 8. IfChanges Occur in Capacity Ratings (Items Number 3 Through 7) Since Last Report, Give Reasons:
- 9. Power Level To Which Restricted, IfAny (Net i<IWe):
- 10. Reasons For Restrictions, IfAny:
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
~ 15. Unit Reserve Shutdown Hours i
- 16. Gross Thermal Energy Generated (MWH)
- 17. Gross Electrical Energy Generated (ilIWH)
- 18. Net Electrical Energy Generated (MWH)
- 19. Unit Service Factor
- 20. Unit Availability Factor
- 21. Unit Capacity Factor (Using <i(DC Net)
- 22. Unit Capacity Factor (Using DER Net)
- 23. Unit Forced Outage Rate
- 24. Shutdowns Scheduled Over i <ext 6 Months (Type, 696 0
0 0
0 0
0 0
0 0
0 1440 71.7 0
- 71. 7 0
23 547 973 61 960 57 164 5.0 5.0 3.7 0
Date. and Duration of Each):
48',938 28,348.98 4,689;61 0
74 320 645 24,580,420 23 859 132 56.6 56.6.
- 32. 9
- 25. IfShut D<iwn At End Of Report Period, Estimated Date of Startup:
- 26. Units In Test Status (Prior to Commercial Operation):
March 7
1980 Forecast Achieved INITIAL CRITICALITY INITIAL ELECTRICITY CO!<IMERCIALOPERATION (o/77)
OPERATING DATAREPORT DOCKET NO.
DATE COilIPLETED BY TELEPHONE 55-260
~'~zaon
-6846 OPERATING STATUS 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):
Notes
- 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, IfAny.
This iWIonth Yr..to.Date Cumuhtive
- 12. Number Of Hours Reactor Was Critical
- 13. Reactor Reserve Shutdown Hours
- 14. Hours Generator On-Line
<< IS. Unit Reserve Shutdown Hours
- 16. Gross Thermal Energy Generated (MlVH)
- 17. Gross Electrical Energy Generated (illlVH)
- 18. Net Electrical Energy Generated (MlVH)
- 19. Unit Service Factor
- 20. Unit Availability Factor
- 21. Unit Capacity Factor (Using MDC Net)
- 22. Unit Capacity Factor (Using DER iVet)
- 23. Unit Forced Outa <e Rate
- 24. Shutdowns Scheduled Over Next 6 illonths (Type.
358.05 0
321.45 901 327 1 102.05 0
1,065.45 0
25 702 650 46.2 74.0 38.3 38.3 63.4 63.4 53.8 26.0 Date. and Duration uf Each):
295 280 1 001 450 283,856 972,837
~
11 774.94
,.24,729..78 0
69 154 438 22 951 518 22.,304,306 56.4 56.4 47.8 47.8 36.4
- 25. IfShut Down At End Of Report Period, Estimated Date of Startup:
- 26. Units In Test Status {Prior to Commercial Operation):
Forecast Achieved INITIAL CRITICALITY INITIAL ELECTRICITY CORDIERCIAL OP ERATIOiV
OPERATING STATUS OPERATING DATAREPORT DOCKET NO.
50~296 DATE ~K COMPLETED BY ~Drive'n TELEPHONE 2Q5L~846
- 1. Unit Name:
- 2. Reporting Period:
ebruar 0
- 3. Licensed Thermal Power (MWt):
3293
- 4. Namephte Rating (Gross MWe):
- 5. Design Electrical Rating (Net MWe):
1065 t *..; ~~
- 7. Maximum Dependable Capacity (Net MWe):
Notes
- 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, IfAny (Net MWe):
- 10. Reasons For Restrictions, IfAny:
N/A 11 12 13 14
<<15 16 17 18 19 20 21 23 24 This Month Yr.-to Date 696' 440 Hours In Reporting Period Number Of Hours Reactor Was Critical Reactor Reserve Shutdown Hours Hours Generator On.Line Unit Reserve Shutdown Hours Gross Thermal Energy Generated (MWH)
Gross Electrical Energy Generated (MWH)
Net Electrical Energy Generated (MWH)
Unit Service Factor Unit AvailabilityFactor Unit Capacity Factor (Using MDC Net)
Unit Capacity Factor (Using DER Net)
Unit Forced Outage Rate Shutdowns Scheduled Over Next 6 Months 1 028.43
. 696 0
0
~ 1,004.93 0
20 068 684 696 0
2 199,842 1,049,920 1,020,188 743,940 725,906
- 69. 8 100 69.8 100 97.9 66.5 30.2 (Type. Date.and Duration of Each):
Cumulative 26'04 19 935.98 1,658;31 1'9 '442.74 0
56 220 066 18,452 500 17,907,961 73.9 73.9 3.9 63.9 10.4
- 25. IfShut Down At End Of Report Period. Estimated Date of Startup:
- 26. Units In Test Status (Prior to Commercial Operation):
Forecast Achieved INITIAL CR ITICALITY INITIALELECTRICITY COAIMERCIAL OPERATION (o/77)
4 UNITSIIUTDOWNS AND POWER REDUCTIONS REPORT hIONTII Feb<<<<y DOCKET NO.
UNITNAhlE DATE COhIPLETED OY TELEPIIONE 50-259 Browns Ferr 1
205 72 -6846 Nii.
Dare C
I rr Vl J
Licenscc Event Rcport 0'
'Cause Ec Corrective Action Io Prcvcnt Rccurrcnce
~ tt 108 800201 S
696 C'efueling F: Forced S: Scl) cd tilcrI Vt/77)
Reason:
A.Equipment Failure (Explain)
II hlaintenancc oi Test C-Rcfuclint; D.lteturiatory Restriction L'perator Trainint; h. Liccnsc Examination F-Administrative C.Opera lrvnal Lrror (Explain)
II Other (Explain) 3 hlcthod:
I hlanual 2 hianual Scram.
'-Automatic Scram.
4.Other (Lxplain) 4 Exhibit G - Instructions for Preparation of Data Entry Shccts I'or Licensee Event Report (Lilac)
File(NUREC-OI 6I )
5'xhibit I - Sante Source
UNITSIIUTDOWNS AND POWER REDUCTIONS REPORT hfONTH DOCKET NO.
UNITNAME DATE COhlPLETED BY TELEPIIONE 50-260 3180 Don Creen N>>.
~A I
r>
~fln CJ gr E
A 2 ~cd Q Ii>
Licenscc Event Report 8
~
'Cause &, Corrc>.tive Action to Prevent Rccurrcncc 117 800201 I
A Derated for tests on "C" Rx feedpump turbine 118 800203 Derated "Bu recirc um tri ed 119 800206 Derated "B" recirc pump tripped and "A" recirc um dischar e valve closed 120 121 122 800206 800209 800210 F
10.13 A
Derated when "A" recirc um tri ed Derated for turbine CV tests and SI's Unknown 123 800212 F
17.88 H
Unknown 124 800215 F
346.54 Unknown -"Unit remained down for maintenance to HPCI F: Forced S: Scl><<d<<lcd
('I/77)
Reason:
A.L'Iluipment Failure (Explain) lt-hlaintenance or Test
(. I(cI I>c I >I >g D )tet,ulatory Restriction I'..Ol>cr;IlofTraining Sc Liccnsc Examination I -AJ>ninist rat ivc G.OP<<rational Lrror (Explain)
I I Otl>cr (I'.xplain) hlethod:
I-hIanual
'.hlanual Scram.
3-Automatic Scram.
4.0tl>cr (Lxplain) 4 fj>d>ibit G - Instructions C>r Preparatiun of Data Entry Shccts for Li<<cnsec Event Report (I.I!R) File IWOREG-
~ DI6l )
5'xhibit I - Sante Source
UNITSIIUTDOWQS AND POWER REDUCTIONS REPORT hlONTII DOCKET NO.
UNITNAhlE DATE COhlPLETEI) IIY TELEPIIONE 50-296 205 729-68lr6 l)alc lr A ~
c qM
~ l/)
Licen sec Evenl Rcporl ¹
~
CN 4l 4l Vl cn Cr
'Cause 4, Corrective Action lo 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 S: Scil<<dtded
('t/77)
Reason:
A.Equipment Failure (Explain)
II-hlaintenance oi Test C.Rctucliog D Regulatory Restriction I:.-Operator Training I, License Exaolinalion F.Adnli>>islralivc G.Operational Lrror (Explain)
I I Olh<<r (Explain) hlethod:
I.hlanual 2-hlanual Scram.
3.Automatic Scram.
4 Otltcr (Explain)
Exhibit G - Instructions for Preparation or D.la Entry Shccls for Licellsce Event Report (LER) File(NOI(EG-OI 6 I )
Exhibit I - Sante Source
CSSC FnUIP;fENT BROWNS FERRY NUCLEAR PLANT UNIT
? fECHANICAL IfAINTENANCE SUIfMARY 2/5 SYSTi I HPCI CONPOiaiENT Barometric cond. strainer NATURE OF IfAINTENANCE gP high EFFECT ON SAFE OPERATION OF TilE REACTOR None CAUSE OF IfALFUNCTION Dirty strainer RESULTS OF MALFUNCTION Cleaned strainer ACTION TAKEfl TO PRECLUDE RECURRENCE Strainer-cleaned TR 137594 2/5 2/5 2/5 2/5 2/7 2/8 2/9
'/12 2/14 2/16 2/16 2/21 RCIC RCIC Off-Gas CRD Feedwater Core Spray EECW SI.C CRD RCIC R11R CRD Cunc} filter and oil Magnetic pickup FCV 66-94 "A" suction filter 18 feedwater check valve 1A drain pump FCV 67-50, 51, and -53 PRV 63-513 FCV 85-11A FCV 85-11B Turbine Pedestals FCV 74-71, -72
-73 "B" suction filter Water content too high IIMI 22 Sticking and leaking throu h High QP Will not seat Packing leakin Dirty strainers Improper relief ressure Leaking through Inspection Leaking ackin High None None None None None None None None None None None None Water content too high Worn magnetic pickup Bad solenoid valve Dirty filters.
Machine surfaces mismatching Tom seal Dirty strainer Relief press.
set too high Service Unknown Loose packing Dirty filters.
Contaminated oil Improper pickup Replaced solenoid valve High diff. press.
Leaking through Leaking seal Strainer dirty Relief press.
too high Roller disc worn and pitted Strip paint and PT for cracks Packing loose
'igh diff. press.
Cuno filter cleaned and oil changed.
TR 137590 Installed new magnetic pickup TR 137592 Installed new solenoid valve.
TR 142975 Installed new filter@
TR 151276 Removed
.30" off inner face of seat TR 144704 Replaced seal TR 107314 Installed new strainer.
TR 13020&
Corrected relief set press.
t TR 151066 Replaced roller discs TR 142971 DED analyzing problem TR 153007 Tightened packing TR 142370 Installed new filters TR 153124 I
CSSC E{SUIPHEllT BROWNS FERRY NUCLEAR PLANT UNIT 2
HECiIAIiICALHAIN'i'ENANCE SUI DIARY For thc Honth of February 19 80 DATE SYSTCH 2/6 HPCI COHPGNENT Ruptured disk NA'lli7Z OF HAINTENAKCE Ruptured disk EFFECT ON SAFE OPERATION GF THE REACTOR None CAUSE OF HALFUNCTION Disk ruptured RESULTS OF HAI.FUNCTION Blown disk ACTION TAKEN TO PRECLUDE RL'CURRFNCE Installed inner and outer disk.
2/11 CRD "B".discharge filter Dirty filter None Dirty filter High diff. press.
Installed new filter 2/12 CRD 2/16 HPCI and RCIC Hodule 50-31 Turbine pedes-tal Air leak Remove paint None None Tubing leak Unknown Control air supply reduced due to leak Removed paint and PT for cracks Installed new tubing DED analyzing piping problem.
TR 146604 2/19 HAIN Steam FCV 1-146 Binding None Service Packing gland binding against valve stem Leveled and tightenedg 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 and 53 Dirty strainer None Dir'ty strainer High diff. press.
Installed new filters TR 130214
BROWNS FERRY NUCLEAR PIAilT UNIT 3
HECHANICAL HAINTENANCE SUIMARY For the Honth of Feb 1980 SYSTEH COHPONENT NATURE OF HAINTENANCE EFFECT ON SAFE OPERATION OF THE REACTOR CAUSE OF HALFUNCTION RESULTS OF HALFUNCTION ACTION TAKEN io PRECLUDE RECURRENCF.
2/2 Diesel Generator Heat exchanger II3AII Clean heat exchanger None Dirty strainer Differential pressur Cleaned coolers and reduced installed new gaskets TR 158735 2/5 EECN FCU 67-50, -51 and -53 Inspect strai
None ers for clean liness Dirty strainer Differential pressur Cleaned strainers reduced TR 130217 2/8 2/16 CRD HPCI and RCIC Pdls 85-72 Turbine Pedestals Lines piped up wrong Inspect for cracks None None Lines crossed Inspection Reverse readings No cracks found Uncrossed lines TR 140246 DED study of h7 system.
TR 146605 2/19 IIPCI Steam trap Appears to be stopped up None None Steam trap works correct None.
TR 161589 2/22 Diesel Generator 3D D/G cooling water Clean coolers None Clams accumulated in coolers Decrease in flow rate Cleaned both coolers per HRI-303 and installed new gas-kets.
TR 136906 2/25 HPCI FCU 73-16 Stem packing leak None Loose packing gland nut Steam leak Tightened packing TR 145039
Not previously reported.
BRO!HIS FERRY NUCLEAR PLANT UNIT 1
ELECTRICAL MAINTENANCE SlMfARY Date System Component Nature of Haintenance E
ect on ate Operation of The Reactor Cause of Halfunction Results of i~falfunction Action Taken To Preclude Recurrence 1/24/80 SI 4 '.B-44 SI 4.2.B-44 Perform SI 4.2.B-44 ADS timer cali-bration (sec.
4,4)
None Bad relay Relay 2E-K34 would not time properly would only time out to. 93 seconds max.
Replaced relay 2E-K34, timed out correctly performed SI 4.2.B-44 and SI 4.2.B-44A.
TR l43422 LER BFRO-50-259/813 1/25/80 Reactor building SI 4.2.A-16 Perform SI 4.
2.A-16 reactor building iso-lation timer calibration (refuel floor reactor bldg.)
None Bad relay RelaY RlB sticking Replaced relay RjB, performed SI 4.2.A-16 OK.
TR 143418 LER BFRO-50-259/807
CSSC E UIPlKNT BROOKS PERRX NUCLEAR PLRET UUZT ELECTRICAL MINTENANCE Sl&kfARY System Component Nature of Haintenance E
ect on a e Operation of The Reactor.
Cause of Malfunction Results of R~lalfunction Action Taken To Preclude Recurrence 2/2/80 I
Reactor water re-circula-tion FCV-1-68-79 Perform EHI 16.and 18 on FCV-1-68-79 None Rotor cracked Rotor cracked Performed EHI 16 and 18, replaced cracked rotor.
TR 140428 2/3/80 HCV-1-74-49 HCV-74-49 full None open-limit switchbad'ad limit switch Limit switch actua-tor was broken Replaced limit switc actuator.
TR 139563 2/3/80 FCV-74-59 Limits out of None adj ustment Bad rotor L'imits out of ad-justment Replaced rotor, and performed EMI 18, valve checked OK.
TR 143432 2/4/80 Core spray cooling HCV-75-12 HCV-74-12 green light limit switch is loose, light. goes out each time run A or C core spray pumps Hone Limit switch out of adjustment Limit switch loose Tightened limit switch, lights work-ing OK.
TR 151270 2/7/80 R)lR 74-49 open limit switch 74-49 open limit switch has red light
- with, valve closed None r
ad limit switch Incorrect indication Replaced limit switch lights worked OK.
TR 151287
CSSC E UIBKNT RRORRR FERRY RUOLEAR PLP$ Y URLY ELECTRICAL MAINTENANCE SmkfARY Date 2/8/80 System Dr~sell blower Component 1B-2 Drywell blower motor Nature of Maintenance 1B-2 drywell blower. motor.
has a ground on it ect on a e Operation of The Reactor.
None
'ause, of Malfunction Bad-motor Results of Malfunction Drywell blower motor was grounded Action Taken To Preclude Recurrence Motor was sent to service shop to be rewound per EHI 33, motor returned to service.
TR 124276 2/10/80 Fuel pool FCV-78-7 cooling control switch deminerali sation FCV-.78-7.con-trol switch on local panel showing closed position with both red and green light None.
I Limit switch out Limit switch out of
'f ad)ustment ad)ustment Ad)usted limit switch, light now indicates correctly.
TR 151289 2/11/80 Contain-ment inerting FCV-76-17 Open limit lights stay'n sometimes when valve is fully closed None Bad limit switch Limit switch out of
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ad)ustment Read)usted limit
- switch, checked OK.
TR 161177 I
2/12/80 RHR ICV-74-33 RHR B HTX'man-ual discharge valve lights ot indicating orrectly one Bad switch Micro-switch stuck closed, condition of switch was rust and corrosion entire switch was bad Replaced switch checked OK.
TR 147890
BRO.its FERRY NUCLEAR PLANT UNIT ELECTRICAL >IAINTENANCE SUIIIIARY For the lfonth of, February 19 80 Date System Component Nature of Haintenance E
ect on a e Operation of The Reactor Cause of Malfunction Results of ifalfunction Action Taken To Preclude Recurrence 2/14/80 MIR HCV-23-49 MIR switch heat exchange inlet valve limit switch is bad None Bad switch Operator on switch out of adjustment Readjusted operatpr and switch and light worked good.
TR 152109 l2/17/80 Control bay lA control bay air hand-ling dis-charge damper lA control bay air handling discharge dam-per not open-ing up None Contacts stuck Auxiliary contacts stuck in ACB for air handling unit fan motor Freed and lubricated auxiliary contacts, damper worked properl TR 147888 2/17/80 CRD
)IS-85-48 CRD control switch stops broken Hone Bad switch Stop on plate broken off Replaced with. new plate.
Checked OK.
TR 152128 2/17/80 Battery charger 48V main bat-tery charger 48V main bat-tery charger-no output None Bad battery charger Bad coil in main contactor relay Replaced coil system, I
worked OK.
TR 152130 I2/18/80 RCIC FCV-71-14 RCIC turbine exhaust isola-tion valve limit switch does not work properly None Limit switch out Limit switch not of ad)ustment giving proper indi-.
cation Reassembled limit switch, ad)usted limit lights, worked OK.
TR 151012
CSSC E UIPMENT VRVLYIS PERRY RVCLEAR PLPRT VRIT ELECTRICAL MAINTENANCE SALARY For the!month of February
]9 80 Dct System Component Nature of Maintenance E iect on a
e, Operation of The Reactor Cause of Malfunction Results of Malfunction Action Taken To Preclude Recurrence 2/23/80 Hain steam Inspect and adjust all limit switches Inspect and adjust all limit switches on FCV-1-74,
-78, and -84 prior to stop valve None Bad limit switch One limit switch on FCV-1-74 not open Adjusted arm on limit switch and it operated.
Checked 0
TR 145384 2/26/80 Control room Control room air handling unit lA Control room air handling unit lA motor burned up None Bad motor Motor bad burned up Pulled motor and sent to service
- shop, reinstalled motor, checked OK.
TR 151065 i2/24/80 I
Contain-FSV-1-84-19 ment atmos phere dilu tion Switch out of adjustment None Bad limit switch Lights not indicatin properly Made adjustment on operator arm, lights functionally checke" OK.
TR 151014 g
2/26/80 Primary FCV-64-141 containmen limit switch Limit switch needs adjustin one Bad limit switch Limits were out of adjustment Adjus ted
- limits, working properly, TR 151002
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CSSC E UIPMENT EEOVHE PElVlP EVOLEAE PLEHT VVIT 3
l ELECTRICAL MAINTENANCE SIMfARY D"te System Component Nature of Maintenance E
ect on a e Operation of The Reactor Cause of Vclfuncciun Results of Malfunction Action Taken To Preclude Recurrence 12/12/79 RCIC Not pre-viously reported Replace EGM control box EGM control box None Bad potentio-meter on high trim of EGM RCIC unable to reach rated flow.
Replaced EGM box.
and calibrated per EMI 37, tested OK.
TR 146708, LER BFRO-50-296/
7926 2/3/80 3EA die-sel gene-rator Battery ex-haust hood fan for 3EA Battery ex-hause hood fan for 3EA diesel has bad bearing None Bad bearing Bearing bad in motor Replaced bearing checked rotation fan running quietly.
Checked OK.
TR 151575 03 2/6/80 R1lR FCV-74-73 Motor trips out when try-ing to run None Tooth broken off gear in, limit switch End bell loose on motor because of loose bolts and one broken bolt into
- stator, motor trip-ping out Drilled out broken bolt, replaced broken limit switch gear, put motor back togethe checked to verify not overloading afte
- repair, completed EMI 16 and 18.
-Checked OK.
TR 145241 2/23/80 Main steam Main steam line high temperature switches Check out test circuit for main steam lin high tempera-ture switches
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on panel 25-229 one Bad transformer Variable transformer bad on 29/229 Changed out trans-former in panel 29-
- 229, checked by SI 4 '.A.8.
TRP147682
CSSC E UIPMENT BROiRlS 1'ERRY NUCLEAR PLAIT UNIT l~ 2 < 3 INSTRlNiENT 1 fAINTENANCE SlMiARY DATE SYSTEM Unit ]
CO~ilPONENT NATURE OF MAINTENANCE EFFECT ON SAFE OPERATION OF THE REACTOR CAUSE OF MALFUNCTION RESULTS OF MALFUNCTION ACTION TAKEN TO PRECLUDE RECURRENCE 2-15 Radiation lonitoring RR-90-252 Repair None Faulty Amplifier Card No Pen Movement None Unit
'-11 Standby Liquid Con-trol LI-63-1A Calibrate None Instrument Drift Did Not Agree With Redundant Indicator None 2-24 Unit
'-6 Rod positio Information RllR Service Water probes 22-15, 50-27 PI-23-4 Replace Calibrate None None Grounded Switches Instrument.Drift 07 Superimposed On Visual Display Inc'orrect Indication None None 2-7 2-21 Feedwater Fire Pro-tection LM-3-53 PI-26-87B Replace Calibrate None None Non-Linear Modi-fier Instrument Drift Indicated 4" Higher Than Redundant Did Not Give Correct Indication None None 2-25 Radwaste FT-77 "16.
Calibrate None Instrument Drift Indicated Flow With
- Pumps Off None
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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