ML20069C230
| ML20069C230 | |
| Person / Time | |
|---|---|
| Site: | Browns Ferry  |
| Issue date: | 03/01/1983 |
| From: | Jones G, Thom T TENNESSEE VALLEY AUTHORITY |
| To: | |
| Shared Package | |
| ML20069C219 | List: |
| References | |
| NUDOCS 8303170467 | |
| Download: ML20069C230 (44) | |
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TENNESSEE VALLEY AUTHORITY DIVISION OF NUCLEAR POWER BROWNS FERRY NUCLEAR PLANT 4
MONTHLY OPERATING REPORT 1
February 1, 1983 - February 28, 1983 DOCKET NUMBERS 50-259, 50-260, AND 50-296 LICENSE NUMBERS DPR-33, DPR-52, AND DPR-68 t
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Submitted by:
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W Plant S'u r ntendent g3170467830310 ADOCK 05000259 R
TABLE OF CONTENTS Operations Summary......................
1 Refueling Information....................
3 Significant Operational Instructions.............
5 Average Daily Unit Power Level................
11 Operating Data Reports....................
14 Unit Shutdowns and Power Reductions.
17.
Plant Maintenance.
20 34 Field Services Summary.....
Errata....,.......................
39
1, Operations Su==nry February 1983 The following summary describes the significant operation activities during the reporting period.
In support of this summary, a chmnological log of significant events is included in this report.
There were 11 reportable occurrences and one revision to previous -
reportable occurrences reported to the NRC during the month of February.
Unit 1 There was one scram on the unit during the month.
On February 5, the reactor scrammed when the turbine tripped (low oil pressure trip) due to oil pressure fluctuations caused by loss of nitrogen on the EHC nitrogen accumulator.
Unit 2 The unit was in its EO C-4 refueling outage the entire month.
Unit 1 There was no scrams on the unit during the month.
2 l
Operations Summary (Continued)
Februcry 1983 Fatigue Usage Evaluation The cumulative usage factors for the reactor vessel are as follows:
Location Usane Factor Unit 1 Unit 2 Unit 3 Shell at water line 0.00581 0.00455 0.00391 1
Feedwater nozzle 0.28196 0.19575 0.14871 Closure studs 0.22021 0.16602 0.12705 NOTE:
This accumulated monthly information satisfies Technical Specification Section 6.6. A.17.B(3) reporting requirements.
Common System Approximately 1.32E+06 gallons of waste liquids were discharged containing I
approximately 3.48E+00 curies of activities.
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3 Ooerations Summary (Continued)
February 1983 Refueling Information Unit 1 Unit 1 is scheduled for its fif th refueling beginning on or about April 15, 1983 with a scheduled restart date of August 15, 1983 This refueling will involve loading 8 X 8 R (retrofit) fuel assemblies into the core; finishing the torus modification; turbine inspection; finishing THI-2 modifications; post-accident sampling facility tie-ins; core spray changeout; and changeout of jet pump hold-down beams.
There are 764 fuel assemblies in the reactor vessel.
The spent fuel storage pool presently contains 52 new fuel assemblies, 260 EOC-4 fuel assemblies, 232 E00-3 fuel assemblies, 156 E00-2 fuel assemblies, and 168 EOC-1 fuel assemblies. The present capacity is 1,148 locations.
Modification work and testing are in progress to increase the spent fuel pool capacity to 3,471 assemblies.
_ Unit 2 Unit 2 began its fourth refueling on July 30, 1982 with a scheduled restart date of March 12, 1983 This refueling outage will involve completing relief valve modifications, torus modifications, "A" low-pressure turbine inspection, generator inspection, MG set installation for LPCI modification, loading additional 8 X 8 R fuel assemblies into the core, TMI-2 modifications, post-accident sampling facility tie-ins, and changeout of jet pump hold-down beams.
-. ~ _
4 Operations Su===ry (Continued)
February 1983 Refuelina Information i
Unit 2 (Continued)
There are 764 fuel assemblies in the reactor vessel.
At the end of the month there were 248 EOC-4 fuel assemblies, 353 EOC-3 fuel assemblies, 156 E00-2 fuel assemblies, and 132 EOC-1 fuel assemblies in the spent fuel storage pool. The present available capacity of the spent fuel pool is 861 locations.
Unit 3 Unit 3 is scheduled for its fifthe refueling on or about October 1, 1983, with a scheduled restart date of January 31, 1984. This refueling will involve loading 8 X 8 R (retrofit) assemblies into the core, finishing i
the torus modifications, post-accident sampling facility tie-in, core spray changeout, finishing THI-2 modifications, turbine inspection, and changeout of jet pump hold-down beams.
There are 764 fuel assemblies presently in the reactor vessel.
There are 280 EOC-4 fuel assemblies,124 EOC-3 fuel assemblies,144 E00-2 fuel l
l assemblies, and 208 EOC-1 fuel assemblies in the spent fuel storage pool.
l The present available capacity of the spent fuel pool is 993 locations.
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5.
Significant Ooerational Event Unit 1 Date Time Event 2/01 0001 Rolling turbine generator for startup.
0023 Synchronized generator, commenced power ascension.
0400 Commenced PCICMR from 74 percent thermal power.
2/02 0500 Reactor thermal power at 98 percent, maximum flow, rod limited.
1400 Reactor thermal power at 96 percent, maximum flow, rod limited.
1444 Commenced reducing thermal power for removal of "A"
string high-pressure heaters from service for maintenance.
1542 "A" string high-pressure heaters out-of-service, reactor power at 79 percent.
1640 Commenced power ascension, "A" string high-pressure heaters out-of-service for maintenance.
1710 Reactor thermal power at 84 percent, "A" string high-pressure heaters limited.
2/03 0252 "A" string high-pressure heaters back in service, com-menced power ascension.
0315 Commenced PCIOMR from 85 percent thermal power.
1235 Reactor thermal power at 99 percent, maximum flow, rod limited.
2/04 0920 Commenced reducing thermal power for removal of "A" string high-pressure heaters from service for mainte-nance (repair leak).
1050 "A" string high pressure heaters out-of-service for maintenance, reactor power at 79 percent.
2120 "A" string high-pressure heaters back in service, com-menced power ascension.
2/05 0022 Reactor Scram No. 167 from 93 percent thermal power due to turbine stop valve closure. During weekly turbine checks (OI-47) while performing the overspeed trip test (oil trip) and resetting the turbine overspeed trip system lockout valve, the turbine tripped.
Investiga-tion revealed the EHC N accumulator, designed to absorb p
pressure fluctuations in the oil system, had lost its N charge. During the process of resetting the trip lock 2 out valve, oil pressure fluctuations were sufficient to bring in the low oil pressure trip.
Following the scram, relief valve PCV-1-22 failed to fully reseat.
The unit will remain down for investigation and repair of PCV-1-22.
0700 Maintenance complete on EHC system.
1410 Reactor in cold shutdown for replacement of relief valve PCV-1-22.
6 Sinnificant Ooerational Event
)
Unit 1 1
Date Time Event Unit 1 (Continued) 2/ 06 2145 RHR valve FCV 74-52 tagged for maintenance on motor.
2/07 2225 Maintenance complete on valve FCV 74-52.
2/08 0008 Commenced rod withdrawal.
0135 Reactor Critical No. 187 0330 Received alarm on relief valve temperature instrumenta-tion, PCV-1-22 leaking.
0350 Comr.enced inserting control rods, reactor sub-critical, holding due to leak from PCV-1-22.
1300 commenced bringing reactor to cold shutdown for drywell entry to inspect PCV-1-22.
1645 Reactor in cold shutdown for inspection of PCV-1-22.
Inspection revealed that relief valve PCV-1-22 would have to be replaced with a relief valve from unit 2, maintenance continues on that valve.
2/09 2126 Changeout of PCV-1-22 complete. Commenced rod with-drawal for startup.
2215 Reactor Critical No. 188.
l 2/10 0245 Cycled PCV-1-22, reactor pressure 255 PSI.
j 0300 Personnel entered drywell for leak check on PCV-1-22.
l 0305 Personnel out of drywell, no leaks found.
Increasing reactor pressure to 1000 PSI.
1253 Reactor pressure at 1005 PSI.
1312 No leak found on PCV-1-22, decreasing reactor pressure.
1350 Reactor at rated pressure.
1837 Rolled turbine generator.
1920 Synchronized generator, commenced power ascension.
2/11 1730 Commenced PCIOMR from 84 percent thermal power.
2/12 1200 Reactor thermal power at 95 percent, maximum flow, rod limited.
2/13 0015 Commenced reducing thermal power from 91 percent for control rod pattern adjustment.
0030 Reactor thermal power at 85 percent for-control rod pattern adjustment.
0100 Control rod pattern adjustment complete, commenced power ascension.
0200 Commenced PCIOMR from 89 percent thermal power.
1800 Reactor thermal power at 99 percent, maximum flow, rod limited.
I
l Significant Ooerational Event Unit 1 Date Time Event Unit 1 (Continued) 2/14 1200 Reactor thermal power at 98 percent, maximum flow, rod limited.
2/15 0700 Reactor thermal power at 97 percent, maximum flow, rod limited.
2/ 16 0520 "C" condensate booster pump and "B" reactor feedwater pump tripped when unit preferred voltage began to decrease, reducing reactor thermal power to 70 percent.
0541 "C" condensate booster pump and "B" reactor feedwater pump back in service, commenced power ascension.
0637 Reactor thermal power at 97 percent, maximum flow, rod limited.
2/ 17 1500 Reactor thermal power at 96 percent, maximum flow, rod limited.
2/19 0400 Commenced reducing thermal power for turbine control valve test and SI's.
0410 Reactor thermal power at 95 percent for turbine control valve test and SI's.
0415 Turbine control valve test and SI's complete, commenced power ascension.
0500 Reactor thermal power at 96 percent, maximum flow, rod limited.
2/20 0900 Reactor thermal power at 95 percent, maximum flow, rod limited.
2/21 0700 Reactor thermal power at 94 percent, maximum flow, rod limited.
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2/24 0700 Reactor thermal power at 93 percent, maximum flow, rod limited.
2/25 2300 Reactor thermal power at 92 percent, maximum flow, rod limited.
2/28 2300 Reactor thermal power at 92 percent, maximum flow, rod limited.
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Sinnificant Onerational Event Unit 2 Date Time Event 9
2/01 0001 End-of-cycle 4, refuel outage continues.
2/28 2400 End-of-cycle 4, refuel outage continues.
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9, Sinnificant Operational Event Udt3 f
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Date Tina Event i
d 2/01 0001 Reactor power at 32 percent holding due to main turbine vibration.
j 0230 Commenced rod withdrawal for power ascension.
0700 Reactor power at 45 percent, holding for investigation of high vibration on No. 8 main turbine bearing.
1048 Commenced power ascension from 45 percent thermal power.
2300 Reactor thermal power at 71 percent, computer out-of-service.
l 2/02 0700 Reactor thermal power at 67 percent, holding computer 8
out-of-service.
1345 Computer back in service, commenced power ascension.
1500 Reactor thermal power at 75 percent, holding for inspec-tion of A2 waterbox.
l 1530 A2 waterbox in service, reactor power at 75 percent.
l l
1542
,B2 waterbox out-of-service for inspection, reactor power at 75 percent.
2255 Commenced rod withdrawal for power ascension, B2 water-box out-of-service.
2320 B2 waterbox back in service, power ascension in i
progress.
2/03 0030 Commenced PCIOMR from 88 percent thermal powdr.
0830 "B" reactor feedwater pump tripped'on low oil pressure when auxiliary oil pump was removed from service, reduced thermal power from 94 percent to 73 percent.
0840 "B" reactor feedwater pump back in service, - commenced q
power ascension.
1030 Commenced PCIOMR from 94 percent thermal power.
2/04 1000 Reactor thermal power at >99 percent maximum flow, rod limited.
l 2/05 0145 Commenced reducing thermal power for turbine control j
valve test and SI's.
0200 Reactor thermal power at 99 percent for turbine control valve test and SI's.
0230 Turbine control valve tests and SI's complete, commenced power ascension.
0300 Reactor thermal power at >99 percont, maximum flow, rod limited.
1 1132 Reduced thermal power when jet pump flow instrument 6
68-43 pegged, indicated core flow increased to 107 x 10 lb/hr.
(No change was indicated in actual electricxal or thermal power levels.)
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l Sinnificant Ocerat'ional Event Unit 3
' Event Date Time s
Unit ~4 (Continued) [
2/05 1200 Reactor thermal power at 83 percent for repair of ' jet pump flow instrument 68-43
't 1225 Commenced power ascension, repair 'f 68-43 in progress.
o 1400 Jet pump flow instrumentation 68,-43 repaired; Reactor power at 94 percent, power ascension in progress.
1800 Reactor thermai power at >99 percepc, maximum flow, rod limited.
2/11 2340 Commenced redecing thermal power for turbin control valve test and SI's.
2400 Reactor thermal power-at 93 percent for turbine control valve test and SI's.
2/12 0120 Turbine control, valve test and SI5s complete, commenced power ascension.
i 0200 Reactor thermal power at 100 percent, maximum flow.
'lJ 2/18 2240 Commenced reduc.ing thermal power for control rod pattern l
adjustment dnd turbine control valve test and SI's.
2300 Reactor thermal" power at 91'gercent for turbine control
^
valve test and SI's and control rod pattern adjustment.
2325 Turbine control valve test;co'mpleW, reducing thermal power for contro]. rod pattern adjustment.
1 2/19 0300 Reactor thermal power at 71 percent, control rod pattern adjustment in progress.
0330 Control rod pattern adjustment in progress, increaring
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thermal power.
1100 Commenced PCIOMR from 78 percent thermal power.
2/20 1500 Reactor thermal Wer at 100 percent maximum flow.
/
2/21 0330 Commenced redgeing thermal pcyer,for SI 4.3. A-2 (CRp exercise).
0345 Reactor thermal power at 95 peccent for CRD exercise.
040D CRD exercise complete, commenced power ascension.
i 0415 Reactor thermal' power at 100 percent, maximum flow.
l 2/26 0110 Commenced reducing thermal power for ' turbine control valve test and SI's.
0130 Reactor thermal power at 83 percest for turbine control valve test,and SI's.
0200 Turbine control valve test and SI's complete, commenced power ascension.
0300 Reactor thermal power at 100 percent, maximum flow.
3 2/28 2400 Reactor thermal power at 100 percent, maximum flow. -
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gg AVERAGE' DAILY' UNIT POWER LEVEL
. DOCKET NO.
50-259 UNIT Browns Ferry 1
~I-03 DATE-CO\\1PLETED BY TELEPilONE - 205/729-0834 i.
Sf0NTli February.
DAY AVERAGE DAILY POWER LEVEL AY AVERAGE DAILY POWER LEVEL (31We-Neo (SIWE-Net )
I 857 17 1032 965 18 1018
'1016 3
943 1016 4
o 2
1008 S
-14 1005 6
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_i 998 7
23
..-16 995 8
4
'1'3 985 9
_5 53 10 26 991
-748 991 1
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, 7 H '-
'979 963
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12 28 i-g3 1018-29 1054 g.,
30 1048 15 3I 1032 16 INSTRUCTIONS
- On this li>rmat. hst the.n erage,jaily nni, p,u.,,,.g.i g, g.,,,3,d W -
d') '" 'l'# '#P'"'""2 ni.ouh. Cornpute :o the nearest whole inegaw.us.
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- 12 AVERAGE DAILY IfNIT POWER LEVEL DOCKET NO. 50-260 UNIT Browns Ferry 2 83 DATE CO\\fPLEIED fly Ted Thom TELEPflONE 205.729-0834 MONTil February DAY AVER AGE DAILY POWER LEVEL DAY AVER AGE DAILY POWER LEVEL (MWe. Net) iMWe-NerI ~
l
-7
-6 17
-7
-6
~ 2 is
-8 3
19
-8
-7 4
20 5
-9
-6 21
-9
-6 6
22
-9
-6 7
3
-9
-6 S
24
-9
-8 9
25 10
-8 26
-10 11
-8
-8 27
-8
-6 1,-
,3
-7 13 29
-8
,4 30
-8 IS 31 16
-7 INS TRUC TIONS On.Ihis f or snai. !bt Ihe.ncr e, e.1:nh unit,,..ui k.u.l,,, g,.*3el 3"' Cach sl.is in s he 'Vlion tin.* in..nt h. (,inlints t n The Ikearc31 ultole nn pau.,g g,
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F: Forced Reason:
Method:
Exhibit G. Instructions S: Scheduled A Equipment Failure (Explain) 1-Manual for Preparation of Data B-Maintenance of Test 2-Manual Scrain.
Entry Sheets for I.ieensee C Refueling 3 Automatic Scram.
Esent Repint t Ll!R) File tNtlREG-D Regulatory Restriction.
4-Ot her ( Explain )
0161) 1;-Operator Training & License E amination 3
F-Adnunist rati.e 5
G. Operational Eiror (Explai.il l'.shibii 1 Same Source (9/77)
Il-Oiher i Explaini I
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50-296 UNITSilUTDOWNS AND POWER REDUCTIONS DOCKET NO.
UNIT NAM E Browns Ferry 3 DATE 3-1-83 REPORT MONTil February COMPLETED BY Tmi Thnm TELEPilONE 205/729-0834 n.r
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B Derated for turbine control valve test and SI's and control rod pattern adjustment.
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Method:
Exhibit G Instructions S: Schedulet!
A Equiprnent Failure (Explain) l-Manual for Preparation of Data B Maintenance of Test 2-Manual Scram.
Entry Sheets for Licensee C-Refueling 3 Automatic Scram.
Event Report (LE R) File (NUREG.
D Regulatory Restriction 4-Ot her (Explain )
016l1 li-Operator Training & License Examination F Administrative 5
i G. Operational Error (Explain)
Eshibit I Same Source 19/77)
Il Oiher ( Esplain)
MECHANICAL MAINTENANCE SUlttiRY CSSC EQUIPMENT.. s:...
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For the Month of February 19 83
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COMPONENT..
EFFECT ON SAFE
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ACTION TAKEN dI;.u g?.
NATURE OF OPERATION OF CAUSE OF RESULTS OF 70 PRECLUDE i
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MAINTENANCE THE REACTOR MALFUNCTION MALFUNCTION RECURRENCE j 24 Primary.m 'drywell.. door;d replace inter-none faulty interlocks interlocks nonfunc-replaced interlocks
- 4#dI{S Containment ' interlocks.Qp~
locks tional MR# 61784
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pressure MR# 61982 m
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CSSC EQUXPFiENT
}CCHANICAL MAINTENANCE
SUMMARY
-LJ Ihn For'the' Month of February 19 83 7..
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EFFECT ON SAFE ACTION TAKEN DATE
. SYSTEM COMPONENT
~ NATURE OF OPERATION OF CAUSE OF RESULTS OF TO PRECLUDE C MAINTENANCE THE REACTOR MALFUNCTION MALFUNCTION RECURRENCE If"-91 CFD HCUAccumulat6[
'r$bEflNiedun none..._
faulty o' rings O' rings & accumulator replaced o' rings r - -- - 23'
-l7 tilatorQ3@jj ;' 3 ] i nonfunctional MR# 61905
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"r.*m 2-247 CRD. -
HCU--14-35
' replace'I M : none filters worn manifold block fil-changed 6 tit all 3 strainerP.:gg
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ters nonfunctional manifold filters wit screens,-M[f:..~-
MR# 62'543 a
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new ones
-Si
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2-16_
HPCI FCV-73-35 replace: key-in none faulty key in manual engagement replaced key in keyway _.
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keyway
. lever not operable keyway
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. g-u_._t 2-11~
EECW- '
FCV-67-50 change straine c -non e - - - -
faulty strainer valves stay open changed strainer &
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& adjust!M
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& bleedoff adjusted bleedoff bleed-off
valve out of valve valve *-
f, adjustment MR# 59083 4
'i' 2-11 Chem. Feed HCV-70-503 repair valve]
stem needs valve inoperable removed stem from.,
none
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replacing 3/4" vent valve off of chem-feed tank &
placed in HCV-70-503 MR# 28328 e
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G.,CSSC EQUIPMENT % q.;h;i
- MECHANICAL MAINTENANCE
SUMMARY
(Nx.w$f $51d.g;iEO!E.
For the Month of February 19 83
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3 EFFECT ON SAFE ACTION TAKEN
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[ SYSTEM COMPONENT ~
NATURE OF OPERATION OF CAUSE OF RESULTS OF TO PRECLUDE MAINTENANCE THE REAC'IOR MALFUNCTION MALFUNCTION RECURRENCE
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[ 1-30 s Afut'g.. wt.;l_ 5 'FCV-74@12......
faulty set screw valve inoperable replaced set screw
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rd. **-d '" %ggs*5@;3,E replace set"c(
none.
r 5 screw in gear' Q.y1'M ~%$ QQ nsai':d?"
"'T MR# 64451 l
i l 2-l'6 'A I$d'I. * ' t LPCI;MG. set?~
past seal ring MR# 28329 lubricant leak none faulty seal rings LPCI 3EN inoperable changed' seal rings h
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3EN : _y, i+
5 in coupling
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- 1:1 2 ul D/G 'Ir -
DG.3D air..
replace _ head none blown head air compressor replaced head gasket '
ll comp [essor.B_
gasket-gasket inoperable MR# 64335
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2-10 Fire
' fire' pump ~B.
replace shear' none faulty shear pin pump strainer will replaced shear pin Protection J. E J.~ T ' ~ ~ pin.
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not rotate MR# 63797
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-RHR-EECW 4:.M repair;penetra-none unknown air leak sealed air leak wit!
Protection tunnel}3Ai' tion with RTV RTV.
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ll 2-2 RHR FCV-74 stem leaking none stem has scarred water leak tightened packing places lub stem & stroked 7.g. 7 valve
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MR# 63751
,i 1-31 HPCI.
gland seal replace seal on none blown seal bad leak on H O side replaced seal j
2
'i condenser condenser heat MR# 62227 exchanger top gasket t.
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MECHANICAL !!AINTETANCE SUFDIARY
.. CSSC EQUIIHENT
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OSe-For the Month of February 19 83
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EFFECT ON SAFE ACTION TAKEN DA'E
- SYSTEM COMPONENT NATURE OF OPERATION OF CAUSE OF RESULTS OF
'ID PRECLUDE 1.
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MAINTENANCE TILE REACTOR MALFUNCTION MALFUNCTION RECURRENCE 2 -12 ".-
M...aste low. level insert needs.
none defected insert not functioninn installed insert #2 c
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- radwaste cask.
replacing insert properly by welding Mit# 59168 l
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BS-33-180 I~
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MR# 60803
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CSSC EQUIPMENT ELECTRICALMAINTENANCESIEMARY ppendix B 9/29/82 h,
For the Month of. February 19 83
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Effect on Safe Action Taken
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Nature of Operation of Cause of Results of To Preclude Edits System Component Maintenance The Reactor Malfunction Malfunction Recurrence
~2/2/83' Fire Smoke detec-During the None Normal aging.
The listed smoke The smoke detec-
'thrcugh ' Protection tors. -
performance of detectors sensitivity tors were replaced.
2/15/83 XS-39-72 BH SI4.11.C.1&5 was too low.
and SI4.ll.C.1&5 XS-39-72 AG the listed was successfully XS-39-66 XC smoke detectors performed on each XS-39-69 WE sensitivity detector.
was found to MR #A-061453 be too low.
MR #A-061400 MR #A-061460 MR #A-061466 2/5/83 RHR,
Limit switch While unit 1 None, All RHR Water in the To go into shutdown Replaced limit (LS12) on was,in cold pumps were still limitorque con-cooling the RHR trains 1 and 2 l-FCV-74-48 shutdown with operable and trol box on pumps take suction 3 and 4, and the B RHR pump primary contain-FCV-74-48 from the A recircula-torque switch.on lined up to ment isolation corroded limit tion loop through FCV-74-48.and provide shut-valves 74-47 and train contacts.
FCV's 74-47 and performed EMI 18.
down cooling, 74-48 would have 74-48. 'These valvos MR #A-061479 the B RHR pump gone closed on have an interlock ~
failed to PCIS signal.
that trips the pump g
start.
if the valves do not show full open. When these valves were opened a interlock prevented B RHR pump from starting.
I-i i,
. l e
'M
w w
.>.raana n uu.c.ita rt. suit uusi * - - - - - -
BF EMSIL 30 CSSC EQUIPMENT ELECTRICAL MAINTENANCE SUNLRY APP 2ndix B 9/29/82 j'
For the Month of. February 19 83
'i.
Effect on Safe Action Taken a : --
Nature of Operation of Cause of Results of To Prcclude T-ta
._ System Component Maintenance The Reactor Malfunction Malfunction Recurrence 5
s /1 /83 i Neutron IRM "F" 1RM channel None Bad relay (7C-IRM "F" channel rods Replaced the bad
!?.
Monitoring detector "F" would not K9K) coil.
blocked.
relay coil, IRM
~
position travel.
channel returned relay.
to normal.
Im #A-064457 I/16 /8 3 48 volt 48 volt DC Battery None Bad contactor Battery charger Replaced the bad DC Power annunciator charger inop-closing coil.
inoperpble.
.contactor closing i
battery erable.
coil, charger charger A.
operated. properly.
~
MR #A-063551 m.
- d t
0 h
8 9
x
owano e c. sus a out,t.c.,us r e,us a unAA e
BF'EMSIL 30
(
CSSC EQUIPMENT ELECTRICAL MAINTENANCE Sl[0fARY Appandix B 9/29/82 4 ;.'. E u For the Month of - February 19 83 3
,. c.
tss P.,.
Effect on Safe Action Taken p;' ~ Q Nature of Operation of Cause of Results of To Preclude
< D7tn t System Component Maintenance The Reactor Malfunction Malfunction Recurrence
.5 D
~
- 1/31'/83 CRD.
~
Scrantaccumu-Received a None, unit in Bad level switch Received several Replaced the bad
~ ~ ^
lator-level false water refueling outage false water alarms.
level switch.
switch in CRD alarm.
MR #A-061005 hydraulic control unit 26-47,
~
2/7/83' RWC and Relay 16A-Relay coil None, relays Failure of lexan Relay coil retainer The listed relays 4KV Shut-K59A and retainer were operable.
coil retainer spools. cracked.
were replaced
?~~
down relay 52RUlB (lexan) spool spools. Ref.
NOTE: The relays per SEMI 37 and Boards and inspection.
HFA Relay Coils were found to have retruned to.
Busses Service Advice cracked coil spools service.,
e PSM-721-152.2 during inspection.
MR #059078 g
m FSR 366E8138.
relays were still MR #059079 i
'2/9/83.
CRD Hand switch Hand switch None Broken stop Required care to be The broken stop HS-85-48 traveled past
- plate, taken by operator to plate was replac-desired avoid turning hand ed in HS-85-48.
- setting, switch past desired The stop plate setting.
was broken and replaced again on 2/28/83.
I j
l
._~
EKUWis.rtxxY NUCLEAR l'LANT UNIT 4
BF D1SIL 30 CSSC EQUIPMENT ELECTRICAL MAINTENANCE SUdiARY ppandix B 9/29/82
,g For the Month of. February 19 83
- 1'si l[
Effect on Safe Action Taken
~
'*~ - '
D:ts.
. Nature of
. Operation of Cause of Results of To Precludt-System Component Maintenance The Reactor Malfunction Malfunction Recurrenes-
- : 2,9/83 :
RBCCW 2B1 drywell Fan would not None Bad overload.
2B1 drywell blower Replaced bad over-blower motor start.
Ioads per EMI 7.
,i feeder MR #A-064266 breaker.
!2f3/83 Annuncia-Annunciator Panel failed None Bad annunciator 2-XS-55-3B inoperable Replaced the bad tor panel to test
- card, card, the annun-2-XS-55-3B.
properly.
ciator panel
~
I operated properly.-
c MR #A-061122 2/10/83
select CRD contacts were select CRD 22-43.
relay, the new 22-43 during not making relay operated withdraw cycle.
connection.
properly.
4 insulation was MR #061123 u i
found under #7 terminal.
2/11/83 Fuel Pool-2-FCV-78-66 FCV-78-66 would None Bad starter coll. FCV-78-66 inoperable.
Replaced the had Cooling starter coil.
not operate, coil, valve breaker operated properly.
control cir-MR #A-061155 cuit fuse blowing.
.0 I
L e
thUwNS tttuti NUCLEAli PLANT UNIT BFbMSIL30
_CSSC EQUIPMENT ELECTRICALMAINTENANCESINMARY Apptndix B 9/29/82 i(;
For the Month of u r,,,,ry 2: L..
19 s q
- o m,
I'. u 2 1..
Effect on Safe
~
Action Ta'cn C F, r -
"C Nature of Operation of Cause of Results of To Preclude dlat'F
' System Component Maintenance The Reactor Malfunction Malfunction Recurrence
- r
',('p.
I2/13/d3 Radiation Radiation' Monitor None Bad motor.
2-RM-90-250 Replaced the bad Montioring monitor tripping inoperable.
motor, the new 2-RM-90-250.
electrically.
motor operated 1
properly.
\\,:4.
MR #A-062699
- <
- v;,
2/17/83 RWCU 2-FCV-69-2 FCV-69-2 would None Bad valve motor.
2-FCV-69-2 Replaced the bad not operate electrically motor and per-N_
electricelly.
formed EMI 18.
f
' ~
MR #A-063606
- i M
e l
e D
o g
b e
EROWr:5 FERRY NUCLEAR PLANT UNIT 3
BF EMSIL 30 CSSC EQUIPMENT ELECTRICAL MAINTENANCE SU$4ARY App ndix B 9/29/82 For the Month of ' February 19 R1 If '
lfy
- .2,
., y Effect on Safe Action Taken
~
- A-. W.- -
v.
Nature of Operation of Cause of Results of To Preclude 2
l'en -
System Component Maintenance The Reactor Malfunction Malfunction Recurrence 1,./83' Fire Smoke detec-Received inter-None Bad smoke Received false Replaced the U.L,
Protection tor iS mittent alarms
- detector, alarms.
smoke detector 88XA.
from XS and performed 88XA.
SI4.ll.C.165.
1m #A-064330
'2'/5/83 '
RBCCW RBCCW surge Surge tank low None Broken low level Surge tank low level Replaced the tank low level annunci-switch.
switch inoperable.
broken switch.
level switch.
ator inoper-MR #A-063959 able.
4 g
a 4
1 e
t
BROWNS FERRY NUCLEAR PLANT UNIT 1 and Common NON-CSSC EQUIPMENT ELECTRICAL MAINTENANCE
SUMMARY
I For the Month of February 19 83 Nature of Cause of Malfunction or Dite
System Component Maintenance Maintenance Action Corrective Action f
5/31/8Mr Generator.
"A" air com-4th stage air pres-Bad check valve.
Cleaned moisture separators and
~7 Breaker pressor check sure gauge shows replaced the bad check valve.
~
valve.
pressure with com-1R #A-061352 pressor off.
2/2/83 500KV PCB 5278 C phase losing air.
Air leak on #2 head. Rag Repaired air leak.
Breaker air Switchyard air system.
stuck in discharge piston system returned to normal.
port.
FR #A-061476 2/4/83 Station,_ _
Condensate Excessive mot'or Bad mot'pr bearing and end Replaced the pump motor.
Drainage,
sludge pump noise.
bell housing.
MR #A-064304
.h, A.
2/6/83 Off-Gas SJAE "A" No indicating Bad limit switch due to Replaced the limit switch l valve inlet valve.
lights for valve.
water.
indicating lights operated proper-ly.
MR #A-064414 2/6/83 480 volt Normal feeder 1B 480V Turbine Bad overcurrent trip Replaced the normal feeder breaker.
Turbine Bldg. breaker fer Bldg. vent board device.
}R #A-064360 Vent Boards.
1B 480V normal feeder Turbine Bldg.
breaker located vent board, in IB 460V unit Bd.
compt. 6B tripping.
l i
O e
I
^
BR0h'NS FERRY NUCLEAR PLANT UNIT 1 and Common NON-CSSC EQUIPMENT ELECTRICAL MAINTENANCE
SUMMARY
For the Month of February 19 83 i
l
[
, ;mme,,
Nature of Cause of Malfunction or
.g 7'Date,~
~
System Component Maintenance Maintenance Action Corrective Action I/h/83
.500KV.
PCB 5204 air Air escaping from Bad solenoid valve.
Replaced the bad valve, air Switchyard system control cabinet.
system returned to normal.
'{
solenoid FR #A-061488 valve.
2/8/83
. Generator PCB 214 "A" Unloader valve Unloader valve stopped up.
Cleaned unloader valve and
't Breaker compressor inoperable, replaced piston in unloader unloader cylinder.
valve.
MR #A-059126 i.
f 2/9/83 Building Secondary Heat pump 1B Burned coil on heat pump Replaced starter coil, returned Heating heat pump 1B
motor starter, heat pump to service.
i' motor starte:
MR #A-061493
,co il,
i 2/10/83 Door Inter-Door inter-During refueling Both events were apparently A door watch was posted until the locks lock system, outage on unit 2 a result of the reactor limit' switches were adjusted and turbine to and startup of unit building access doors the doors returned to service.
units 1 and 1, the turbine to closing enough to actuate Upon re-occurrence the door watch 2 reactor units 1 and 2 re-the door position limit was posted and the door interlock building actor building switches, but not closing limit switches were adjusted to doors (221, doors (221, 235, enough to engage the operate properly.
235, and and 236) were open-electric strike.
MR #A-064424 236).
ed simultaneously LER#BFRO-50-259/83008 breaching secon-dary containment.
Approximately 22 hours2.546296e-4 days <br />0.00611 hours <br />3.637566e-5 weeks <br />8.371e-6 months <br /> later the personnel access doors (235 and 221) between the turbine b1dg. and the unit 1 reactor b1dg.
i
. l were again opened at the same time.
BROWNS FERRY NUCLEAR PLANT UNIT 2 ff-NON-CSSC EQUIPMENT ELECTRICAL MAINTENANCE
SUMMARY
For the Month of Fei>ruary 19 83 ll-x.. -.
Nature of Cause of Malfunction or
==-
);
._Date
- System -
Component Maintenance Maintenance Action Corrective Action f
.y '2/1/83
. Main Steami;,
2-FCV-1-155 Valve torque switch Bad torque switch.
Replaced the torque switch, valve not operating operated properly.
properly.
MR #A-061553
/4/83.
Heater 2-FCV-6-133 2-FCV-6-133 Burned valve motor Replaced the valve motor, FCV
. Drains and inoperabic, windings.
operated properly.
Vents MR #A-061107 2/6/83.
Off-Gas y.
Rec 6mbiner Fan inoperable.
Bad control transformer in Replaced the bad control trans-rm cooling 480 volt Turbine MOV Bd.
former, the cooling fan operated
' ~'
fan 2B.
2B, Compt. 10A, properly.
MR #A-061095 g
2/14/83 RWCU
'2A Rx Water Pump motor making Bad motor bearing.
Replaced pump motor bearings, pump cleanup excessive noise operated properly.
holding pump, and vibration.
MR #A-061041 D
f h
I e
i t
e e
BROWNS FERRY NUCLEAR PLANT UNIT 3
- p.
- j r:
NON-CSSC EQUIPMENT ELECTRICAL MAINTENANCE SUPJ1ARY
. t ;;i. a 5 5 ~,[.
For the Month of February 19 83
.z-
! [~di$kf-
',c gjg Nature of Cause of Malfunction or 2;Date'
- ' System Component Maintenance Maintenance Actfon Corrective Action t %t
- .'2/4 /83 ;
. Condensate 3D conden-Pump motor making Bad pump motor bearings.
Replaced motor bearings, pump W i.- -'
and Domin shte demin excessive noise and operated properly.
', ' ~
~
Water
- holding pump vibrating.
MR #A-063765 motor.
I s,.
g w
[
W
..se e
9 0
<f e
i
34 FIELD SERVICES
SUMMARY
February 1983 Maior Work Areas A.
Refuel area - the fuel reload continued through the first week of February and was completed on February 8 at 0405 hours0.00469 days <br />0.113 hours <br />6.696429e-4 weeks <br />1.541025e-4 months <br />.
An average of 48 bundles per day was loaded out of 764.
Verification was completed on February 9, 1983 B.
Turbine - the generator air test was successfully performed during February.
This concluded all turbine floor work except for the j
modification to the turbine floor crane rails and the control intercept valve handrail work.
Both of these jobs are currently being worked and will be complete prior to unit 2 cycle 4 startup.
j Preliminary planning for the unit 1 cycle 5 was started during February.
C.
Drywell - with fuel reload complete, major efforts were made to prepare the drywell for ILRT. The failure of an MSRV on unit 1 was
' solved by swapping MSRV and vacuum breakers from unit 2 to unit 1, and the failed valve sent to Wyle Labs for repair.
A red 6 sign for the vacuum breakers was submitted by FSG valve engineer and with approval by EN DES, a prototype was started by mid-February. The following work items were essential for ILRT:
1.
Install blanks at missing MSRV
~2.
Replace fittings for RBCCW pumps 3
Tip tubing installation and handcranking 4.
Set up for ILRT 5.
LLRT's of 64-17, 18, 19 and 76-24, 74-57, 58, 59 and H2/02 4
6.
Complete MSRV air supply system.
J
35 FIELD SERVICES
SUMMARY
(Continued)
February 1983 Maior Work Areas (Continued)
C.
Drywell (Continued)
All of the above was accomplished by February 14 when tensioning of drywell head was complete.
Pressurization of drywell started at 0100 hours0.00116 days <br />0.0278 hours <br />1.653439e-4 weeks <br />3.805e-5 months <br /> on February 15, but had to be aborted due to hose problems at 0600 hours0.00694 days <br />0.167 hours <br />9.920635e-4 weeks <br />2.283e-4 months <br />. On February 17 stabilization phase was in progress and on February 20 at 2300 hours0.0266 days <br />0.639 hours <br />0.0038 weeks <br />8.7515e-4 months <br /> drywell ILRT was completed.
With comple-tion of ILRT the critical path became the refuel floor and drywell preparations for RPV hydro.
On February 21 the refurbished MSRV was received from Wyle and installation began immediately while the RPV preparations for hydro were worked in parallel.
On February 25 the RPV was ready for pressurization and hydro was completed on February 28 at 0700 hours0.0081 days <br />0.194 hours <br />0.00116 weeks <br />2.6635e-4 months <br />.
D.
Electrical - during February the primary work performed by the elec-
'trical group was sa follows:
1.
Completed STEAR 8301 on the recirculation riser instrumentation installation.
2.
Completed L2115E modification, cable pulls and thermocouple installation and hookup.
3 Completed installing all emergency lighting on unit 2 (PO479).
Final walk-thru inspection is still outstanding.
4.
Completed all work on the torus vacuum breaker modification and completed surveillance instruction (SI).
I l.
9
' 36 FIELD SERVICES
SUMMARY
(Continued)
February 1983 Maior Work Areas (Continued)
D.
Electrical (Continued) 5.
Resumed TIP work and installed all indexers and successfully com-pleted all handcranking.
Wattage test will be performed next month.
6.
Performed maintenance on the 20 condensate pump motor which requires disassembly from pump and shipment to the power service shop.
7 Completed P0600 recirculation brush holder modification on recir-culation MG sets 2A and 2B.
8.
Completed all electrical work and SI's related to the H2/02 modi-fication (P0361E).
t 9
Support other outage work with various maintenance requests that were added to the outage scope of work.
l E.
' Mechanical -
1.
Complete retest of high-pressure feedwater heater A1 and A2 and B1 and B2.
Repaired A2 heater and released to plant.
i 2.
Reworked drywell blower dampers A and B side.
l 3
Installed one SDIV platform and started prefabrication of second.
l 4
Completed CRD "0" ring change-out.
5.
Completed main steam snubber installation in drywell.
6.
Started fabrication of parts for modification of vacuum breaker and ordered material for installation.
37
~
FIELD SERVICES
SUMMARY
(Continued)
February 1983 Maior Work Areas (Continued)
E.
Mechanical (Continued) 7 Completed all ISI work in drywell.
8.
Completed all MSIV and MSRV mechanical work.
9.
Recived approved pipe hanger changes from EN DES for MSS-13 and H-5 on February 28 and started prefabrication.
10.
Completed paint touch-up in drywell.
F.
Torus 1.
Unit 2 During the first two weeks of February the following remaining work was completed, a.
Installation of torus seismic lug shims b.
ECCS gussets c.
N, J and L lapplates d.
Installation of MKII for tie-downs and shimming r
e.
Installation of torus snubbers, except bolting at one bracket f.
Started cleanup work and decon at El. 51'9 2.
Unit 1 During February setup to work at unit 1 started with setting of protective barrier, moving of compressor from unit 2 and unit 1, power supplies, tool cage and lubrication of shims at seismic lugs.
By the end of the month N, J, and L lapplates were pre-m
' ~
_f 38 FIFLn SERVICES
SUMMARY
(Continued)
February 1983 Maior Work Areas (Continued),
[
F.
Torus (Continued) fabricated and preparations made for installation, nine positions had drilling complete for torus snubber wall bracket, lifting lugs were 80 percent cocplete and 80 percent of ECCS gussets were -
f1 tacked into place, baseplates drilling and installation of ECCS l-ring header snubbers 50 percent complete and prefabricated approximately 52 pipe hangers in shop.
[
G.
Administrative - the overtime percentage for the conth of January was 15 percent, with 148,077 straight time hours and 26,479 5 overtime hours.
As of January 31, 1983 year-to-date overtime percentage was 21 percent, 581,322.5 hours5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br /> of straight time hours and 153,568 overtime
~
hours.
The overall goal of the overtime percentage'is 17 percent.
The O&M budget for January was $4,557,896 and the exponditures were
$2,654,076 with year-to-date budget being $12,783,'i35 and actual
/
year-to-date expenditures being $10,233,344. - The capital budget was I
l
$4,979,009 and the expenditures were $1,39S,357 with year-toddate budget being $16,096,805 and actual year-to-date expenditure's being
$6,781,703 Overall budget was $9,556,905 and the overall expendi-tures were $4,043,433 with year-to-date budget being $28,885,740 and actual year-to-date expenditures being $17,015,047. The February ',
/
overall budget is $3,859,909.
f 9
)
a a
q -
r 39 7
ERRATA
~,
Make. corrections to pages 16, 17, and 18 of the January Monthly 2
Operating Peport, as per the attached pages.
w w
I 4
16 OPERATING DATA REPORT DOCKET NO. 50-259 DATE 2-1-83
^~
CO$1PLETED BY Ted Thom TELEPilONE 205/
-0834 OPERATING STATUS
- 1. Unit Narne: Browns Ferry - 1 N"l*5 '
- 2. deporting Period: January 1983 3293
- 3. Licensed Thermal Power (31Wt):
1
- 4. Nameplate Rating (Gross 31We):
1065
- 5. Design Electrical Rating (Net alWe):
1098.4
- 6. Staximum Dependable Capacity (Gross 31We):
1065
- 7. Alasimum IJependable Capacity (Net 31We):
- 8. If Changes Occur in Capacity Ratings (items Number 3 Through 7) Since Last Report. Give Reasons:
N/A
- 9. Power Lesel To Which Restricted,if Any (Net 31Wel: N/A
- 10. Reasons For Restrictions. If Any:
N/A This alonth Yr..to.Date Cumulative
- 11. Ilours in Reporting Period 744 744 74,546
- 12. Number OfIlours Reactor Was Critical 698.55 698.55 48,088.09
- 13. Reactor Reserve Shutdown llours 45.45 45.45 5,782.76
- 14. Ilours Generator On-Line 679.45 679.4) 47,079.57
- 15. Unit Resene Shutdown linurs 0
0 0
- 16. Grow Thermal Energy Generated (alWill 2,066,830 2.066.830 133,839,834
- 17. Gross Electrical Energy Generated (alWill 683.790 683,7.90 44,084,510
- 18. Net Electrical Energy Generated (5thill 665,447
_665.,447 42,815,226
- 19. Unit Senice Factor 91.3 91.3 63.3
- 20. Unit Asailability Factor 91.3 91.3 63.3
- 21. Unit Capacity Factor (Using.\\lDC Net) 84.0 84.0 53.9 84.0 84.0 53.9 2.'
Unit Capacity Factor (Using DER Net)
O'7
- 23. Unit Forced Outage Rate
.]
- 24. Shutdowns Scheduled User Nest 6 Stunths (T.s pc. Date.and Duration of rachl:
- 25. If Shnt Down At End of Report Period. Estimated Date of Startup:
- 26. Units in Test Status (Prior to Commercial Operationi:
Iorecast Achiesed INIII A L CRITICALITY INill \\L El.LCIRICIT Y CO\\l\\lERCI A L OPER ATlON P3/771
1/
OPERATING DATA REPORT DOCKET NO. 50-260 DATE 2-1-83
~
CON 1PLETED itY h1 Thn-3 TELEPilONE 205/729-083/.
OPERATING STATUS
- 1. Unit Name: Buns Fmy - 2 Nom
""
- Y 190
- 2. Reporting Period:
- 3. Licensed Thermal Power (5tht1: 3293
- 4. Nameplate Rating (Gross 31We): 1152
- 5. Design Electrical Rating (Net.\\lWe):
1065
- 6. Stasimum Dependable Capacity (Gross SlWel: 1098.4
- 7. Stasimum Dependable Capacity (Net.\\twe):
1065 8 If Changes Occur in Capacity Ratings Iliems Number 3 Through 7: Since I.ast Report.Giie Reasons:
N/A
- 9. Power Lesel To WI.ieh Restricted,1f Any(Net Alde):
N/A
- 10. Reasons For Restrictions,If Any:
N/A This 5fonth Yr..t o.Dat e Cumulative
- 11. Ilours In Reporting Period 744 744 69,487
- 12. Number Of Ilours Reactor has Critical 0
0 43,293.47
- 13. Reactor iteserve Shutdown llours 0
0 13,684.82
- 14. If ours Generator On.Line '
O O
41' M 4)
- 15. Urtit Resene Shutdown llours 0
0 0
- 16. Gross Thermal Er,.y Generated (31Wil) 0 0
120,480,340
- 17. Gross Electrical Energy Generated (.\\lWil) 0 0
40,024,908
- 18. Net Electrical Energy Generated ( AlWil) 0 0
_38,873,075
- 19. Unit Senice Factor 0
0 60.4
- 20. Unit Availability Factor 0
0 60.4 0
- 21. Unit Capacity Factor (Using. lDC Net) 0 N3
\\
- 22. Unit Capacity Factor (Using DER Net) 0 0._..
52.5
- 23. Unit Forced Outage Rate 0
0 27.1
- 24. Shutdowns Scheduled Oser Next 6 slonths (Iype.Date.and Duration of Eacht:
- 25. If Shnt Down At I:nd Of Report Period. !>timated Date of Startup:
3/7/83
- 26. Units in Test Status (Prior to Connnercial Operationi:
Forcea3 t "
Achiesed INIIl \\ L CRI TICA LITY INI Il \\ 1. EI.! CTRICITY CO\\l\\lERCI \\ 1. OPFR.\\ l ION (9/77)
-.m
- _ ~ -
,--s.-,.-
E_._
l 18 e s OPERATING DATA REPORT DOCKET NO. 50-296 DATE 2-1-83 CO.\\lPLETED Ity Ted Thom TELErilONE '>ns/799-0834 OPERATING STATUS Y~
- 1. Unit Name:
January 1983
- 2. Reporting Period:
9
- 3. Licensed Thermal Power 15tht):
1152
- 4. Nameplate Rating (Gross 31We):
1065
- 5. Design Electrical Hating INet alWe):
1098.4
- 6. Stasimum Dependable Capacity (Gross $1We):
1065
- 7. Stasimum Dependable Capacity INet SIWE):
S. If Changes Occur in Capacity Ratings titems Number 3 Through 7) Since Last Report. Gi e Reasonc N/A
- 9. Power Lesel To Which Restricted if Any (Net MWe):
N/A
- 10. Reasons For Restrictions. If Any:
N/A This alonth Yr to Date Cumulative
- 11. Ilours in Reporting Period 744 744 51,912
- 12. Number Of Ilours Reactor Was Critical 300.30
'_300.30 37,912.58
- 13. Reactor Reserse Shutdown llours 443.7 443.7 3.815.85
- 14. Ilours Generator On-Line 274.43 274.43 37,048.49
- 15. Unit Reserve Shutdown llours 0
0
- o
- 16. Gross Thermal Energy Generated ($1will 798,838
~796,636
- 17. Gross Electrical Energy Generated (SIWil)
_279,800 279,069
_ 110,134,942 36,319,590
- 18. Net Electrical Energy Generated (ilWil) 267,069 267.069 35,247.973
- 19. Unit Service Factor 36.9 36.9 71.4
- 20. Unit Asailability Factor 36.9 36.9 71.4
- 21. Unit Capacity Factor (Using SIDC Net) 33.7 33.7
_63.8
- 22. Unit Capacity Factor IUning DER Net) 33.7 33.7 63.8
- 23. Unit forced Ourage Rate 63.1 63.I 18.1
- 24. Shutdowns Scheduled ther Nest 6 Months tType. Date.and Duration of Each):
i
- 25. If Shnt Down At End Of Report Period. Estimated Date of Startup:
- 26. Units in lest Status tPrior io Commercial Operation):
Forecast Achies ed INITIA L CltlilCA LIIY INI II.\\ L 1:1.1 CTRICITY CO\\l\\l0RCIT L Ol'l:R ATION P3/77)