ML18283A409
| ML18283A409 | |
| Person / Time | |
|---|---|
| Site: | Browns Ferry  |
| Issue date: | 04/07/1978 |
| From: | Dewease J Tennessee Valley Authority |
| To: | Office of Nuclear Reactor Regulation |
| References | |
| Download: ML18283A409 (45) | |
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TENNESSEE VALLEY AUTHORtTY Brogans Ferry Nuclear Plant P.
O.
Box 2000
- Decatur, Alabama 356 pp~ p~~>>; ~~.,;<-,,
Nuc'ar Regulatory.Commi sion Office of Hanagement Information and Program Control Washington, D,
C.
20555 Gentlemen:
La -'
r.-,
C I' i
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Enclosed"is"the.lfarch.19?B.itnnthly.Operating Rejig-t Browns Ferry Nuclear Plant Units 1, 2, and 3.
Very truly yours, TENNESSEE VALLEY AUTHORITY J.
G.
De@ease Plant Superintendent Enclosure cc:
Director, Region II Nuclear Regulatory Commission Office of Inspection and Enforcement 230 Peachtree St eet, "Nh'uite 818
- Atlanta, GA 30303 Director, Office of Inspection and Enforcement Nuclear Regulatory Commission Washington, D.
C.
20555 78)0 0001
TERKSSEE VALLEY AUTHORITY DIVISION OF POWER PRODUCTION BROWNS FERRY NUCLEAR PLANT MONTHLY OPERATING REPORT March 1, 1978 - March 31, 1978 DOCKET NUMBERS 50-259, 50-260, and 50-296 LICENSE NUMBERS DPR-33, DPR-52, and DPR-68 Submitted by ant Superintendent
TABLE OF CONTENTS Operations Summary Operational Data 2
Maintenance.
2 Refueling Information Significant Operational Events Average Daily Unit Power Level Operating Data Reports Unit Shutdowns and Power Reductions.
Plant Maintenance Summary.
Unit 2 Refueling Outage Summary.
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~
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3 5
13 16 19 22
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31
erations,Summa The fullowing summary describes the significant operational activities during the reporting period.
Xn support of this
- summary,
- a. chronologically ordered log of significant events is included in this report and begins on page 5.
There
.were 7'eportable Occurrences reported to the NRC during the month of March.
Unit 1 Significant operational events for unit 1 are tabulated by date and time beginning on page 5.
The unit did not, scram during the month of March.
A summary of maintenance work is shown on pages 22 through 30.
Unit 2 Significant operational events for unit
- 2. are tabulated by date and time beginning on page 8.
'he unit scrammed once during the month of March.
On March 18 the. reactor was manually'crammed due to high unidentified leakage in the drywell.
The leakage was due to a valve packing leak.
While the unit was, down it was decided to commence the refueling outage, one week ahead of schedule.
A summary of maintenance work is shown on pages 22 through 30.
0 erations Summa (Continued)
-Unit 3 Significant operational events for unit 3 are tabulated by date and time beginning on page 10.
There was one scram on the unit in March.
On March 16 the reactor was manually scrammed to accomodate maintenance to those types of drywell electrical penetrations which had failed laboratory testing of lOCA conditions.
A summary of maintenance work is shown on pages 22 through 30.
The radwaste system performed as designed without significant problems.
Approximately 6.93E+5 gallons of waste containing 1.02 curies of activity were discharged during the month.
erational Data The average daily unit. power level for units 1,
2, and 3 is shown on pages 13 through 15.
The operating data reports for all three units are shown on pages 16 through 18..
Unit shutdowns and power reductions for all three units are shown on pages 19 through 21.
Maintenance Maj or electrical, mechanical, and instrument maintenance activities during the month are described on pages 22 through 30.
Refueling outage activities for unit 2 are described on page 31.
Refuelin Information Unit 1 Unit 1 is scheduled for its second refueling beginning on November 3, 1978, with a restart date of December 15, 1978.
Resumption of operation on that date will require a
change in technical specifications pertaining to the core thermal limits.
Present scheduling is to submit licensing information in support of these changes by August 31, 1978.
This refueling will load additional 8
X 8 fuel assemblies into the
- core, replacing presently loaded 7
X 7 fuel.
There are 764 fuel assemblies in the core.
The spent fuel
'\\
storage pool presently contains 168 assemblies..
The present storage capacity of the spent fuel pool is 1080 assemblies.
Present planning is to increase that capacity to 3471 assemblies.
With present
- capacity, the refueling later in 1978 would be the last, refueling that could be discharged to the spent fuel storage pool without exceeding that capacity and maintaining full core discharge capability in the pool.
Unit 2 Unit 2 began its first refueling on March 18,
-1978, with a scheduled restart date of June 12, 1978.
Resumption of operation on that date will require a
change in technical specifications pertaining to the core thermal limits and increased setpoints for the main steam relief valves.
Iicensing information in support of these changes was submitted on March 10, 1978.
This refueling involves replacing some of the present 7 X 7 fuel assemblies with 8 X 8 assemblies, modifying the main steam relief valves to increase simmer margin, and installing a new recirculation pump trip (RPT) System.
Refuelin Information (Continued)
Unit 2 (Continued)
At the end of March there were 164 Cycle 1 fuel assemblies the core.
There are presently 168 new 8 X 8 fuel assemblies in the spent fuel storage pool, 132 of which are awaiting transfer to the core during refueling, and 600 Cycle 1 fuel assemblies also in the spent fuel storage pool.
The present storage capacity of the spent fuel pool is 1080 assemblies.
Present planning is to increase that capacity to 3471 assemblies.
With present
- capacity, 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 first refueling beginning on August 13,
- 1978, with a restart date of October 22,. 1978.
Resumption of operation.
on that date will require a
change in technical specifi-cations pertaining to the core thermal limits.
Present.scheduling is to submit licensing information in support of these changes in May 1978.
,This refueling will involve replacing some of the present 8 X 8 fuel assemblies with 8
X 8 retrofit assemblies, modifying the main steam relief valves to increase simmer margin, and installing a
new recircu-lation pump trip (RPT) system.
There are 764 fuel assemblies in the core.
There are no fuel assemblies present in the spent fuel storage pool.
The present storage capacity of the spent fuel pool is 1080 assemblies.
Present planning is to increase that capacity to 3471 assemblies.
With present
- capacity, 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.
Si nificant 0 erational Events Date Time Event Unit 1 3/1 3/3 3/4 0000 2302 0210 Reactor thermal power at 97/,
sequence A, steady state.
Reduced thermal power from 97/
to 70'/ for turbine C.V. tests and SI's.
Turbine C.V.
tests and SI's completed, commenced
- '0950 power ascension.
Cotnmenced "control "rod.insertion for critical power 3/5 1515 2000 1500 ratio (CPR) from 75$ thermal power.
Reactor thermal power at 65$, holding for establish-ing target rod pattern.
Target rod: pattern established, commenced PCIOMR
. from 65$ thermal power.
Reactor thermal power at 78$,
PCIOMR.
3/7 1005 Reduced, thermal power from 90$ to 85'/ due to recircu-
,latio'n.,pump,run,.back
,.when transferring shut down board power supply.
1140 Commenced PCIOMR from 85/ thermal power.
3/8 3/12 1630
'eactor thermal power at 98/, steady state.
0001 Reduced power from 98$ to 70$ for turbine C.V. tests 0235 1:100 1815 1926 and SI's.
Turbine C.V.
tests and SI's completed, commenced power ascension.
Commenced PCIOMR from 90$ thermal power.
Reactor thermal power at 98$, steady state.
Scrammed control rod No.
22-27 from Auxiliary Instrument Room when rod could not be withdrawn.
Si nificant erational Events (Continued)
Date Time Event Unit 1 (Continned) 3/13 3/14 1000 1027
-,1105 0001 Reduced thermal power from 98% to 78/ for testing control rod no.
22-27 as required after being inoperable.
Control rod no.
22-27 tests completed, commenced power ascension.
Commenced.PCIOMR -from 90$.thermal.power,.
Reactor thermal power at 98/, steady state.
3/16 3/17 3/18 0700 2320 0040 0130 0700 Reactor thermal power at 97$, steady state.
Reduced thermal power from 97/, to 70/, for turbine C. V.. tests and SI's.
Turbine C.
V; tests and SI's completed, commenced power ascension.
Commenced PCIOMR from 90/ thermal power.
Reactor thermal power at 97/, steady state.
3/24 2235 Reduced thermal power from 97/ to 60$ for removal of "A" recirculation pump from service for brush 3/25 2350 0150
'replacement.
Commenced turbine C. V. tests and SI's.
Turbine C. V. tests and SI's completed.
0152 Brush replacement on "A" recirculation pump completed, reduced thermal power from 60/ to 50$ for returning 0202
, "A" recirculation pump to service.
Commenced power ascension
Si nificant 0 erational Events (Continued)
Date Time Event Unit 1 (Continued) 3/25 0600 Commenced PCIOMR from 90/ thermal power.
3/27 3/28 1830 1500 1610 Reactor thermal power at 98'/, steady state.
Reactor thermal power at 97/, steady state.
Thermal power was reduced from 97'/ to 80'/, when "A" recirculation pump run back occurred (loose relay wire).
1615 1630 Commenced power ascension from 80$ thermal power.
Commenced PCIOMR from. 95/ thermal power.
3/31 2110 2200 2400 Reactor thermal power at 97$, steady state.
Reduced.
thermal power from 97/ to 50/ for control rod sequence exchange from, "A" to "B".
Reactor thermal power at 50$ with control rod sequence exchange in progress.
Si nificant 0 erational Events (Continued)
Date Time Event Unit 2 3/1 3/4 3/5 0000 2247 0001 Reactor thermal power at 89%,
sequence A, steady state.
Reduced thermal power from 86% to 70% for turbine C.V. tests and SI's.
Turbine C.V.
tests and SI's completed, commenced power ascension.
0015
'""'Reactor "thermal 'power at 77/,
holding due to "A" 0340 recirculation pump scoop tube lock occurrence.
"A" recirculation pump scoop tube reset commenced 3/7 3/8 1500 0700 0700 power. ascension.
Reactor thermal power at 86%,. steady state-.
Reactor thermal power at, 85%, steady state.
Reactor thermal power at 84%, steady state.
3/10 2310 Reduced thermal power from 84/ to 70'/ for turbine C.V. tests and SI's.
3/ll 0045 Turbine C.V.
tests and SI's completed, reduced 3/12 0655 1300 1500 thermal power from 70% to '60% for control rod target
'attern improvement.
New rod target pattern established, commenced power ascension.
Commenced PCIOMR from 70% thermal power.
Reactor thermal power at 80'/,
PCIOMR.
Si nificant 0 erational Events (Continued)
Date Time Event Unit 2 (Continued) s/is 2300 Reactor thermal power at 89/, steady state.
3/15 S/i7 S/18 s/si 2300 0700 0220 0655 1100 2200 2400 Reactor thermal power at 88/, steady state.
Reactor thermal power at 87'/, steady state.
Reduced thermal power from 87/ to 80$ for control rod exercise SI.
Commenced re'ducin'g thermal power from 80/ for shutdown due to excessive unidentified drywell leakage.
Reactor scram no.
61 (manual) to accommodate maintenance.
Commenced bringing reactor to cold shutdown for initial refueling outage.
Unit. at cold shutdown with the initial refueling outage in progress.
(600 fuel assemblies removed from the reactor.)
End of Month
10 Si nicicant 0 erational Events (Continued)
Date Time Event Unit 3 3/1 3/3 0000 0050 Reactor thermal power at 96'/,
sequence B, steady state.
Reduced thermal power from 96/ to 90% for isolation 3/4 3/5 3/6 1030 0001 0205 1500 1220 of "A" string low pressure heaters for maintenance.
"A" string low pressure heaters placed in service, commenced PCIOMR.
Reduced thermal power from 96/ to 70% for turbine
""C V. 'tes'ts and'SP,s.
Turbine C.V.
tests and SI's completed, commenced power ascension.
Reactor thermal power at 96/, steady state.
Reduced thermal power from 96/ to 73'/ for removal
. of "C" reactor feed pump from service for maintenance (oil leak).
1530 1608 Maintenance to "C"
reactor feed pump completed.
"C" reactor feed pump placed in service, commenced 3/7 3/12 power ascension from 73'/ thermal power.
2104 Commenced PCIOMR from 92'/ thermal power.
0700
'eactor thermal power at 96%, steady state.
0240 Reduced thermal power from 96/ to 70% for turbine 0452 0700 2030 2045 C.V. tests and SI's.
Turbine C.V; tests and SI's completed, commenced power ascension.
Commenced PCIOMR from 90% thermal power.
Reactor thermal power at 98%, steady state.
Reduced thermal power from 98'/ to 95/
due to EHC high vibration.
V
11 Si nificant 0 erational Events (Continued)
Date Time Event Unit 3 (Continued) 3/15 1940 Commenced reducing thermal power from 95), for shutdown 3/16 3/20 000j 2230 (scheduled maintenance).
Reactor scram no.
52 from 36/ thermal power (manual) to accommodate maintenance to electrical penetrations.
Maintenance to electrical penetrations completed
'commenced-rod -.withdrawal.
3/21 2336 0500 Reactor critical no.
60 and holding at 3g thermal power for venting 02 and to establish stable operations.
Reduced thermal power from 3$ to 0 to bring the reactor subcritical.
0830 Resumed. rod withdrawal for startup.
3/22'/23 3/24 0855 1430 2135 0105 0212 2230 0030 Reactor critical no.
61.
Reactor thermal power at 3g and holding for maintenance to "D" TIP indexer.
Maintenance to "D" TIP indexer completed, resumed
'tartup.
,Rolled T/G.
Synchronized generator, commenced power ascension.
Reduced thermal power from 80$ to 70$ for turbine C. V.
tests and SI's.
Turbine C.
V. Tests and SI's completed, holding for removal of "C" condensate booster pump from service for maintenance (oil leak).
12 Si nificant 0 erational Events (Continued)
Date Time Event Unit 3 (continued) 3/24 3/27 0845 1230 0345 "C" condensate booster pump oil leak fixed, commenced power ascension.
Commenced PCIOMR from 75/ thermal power.
Reactor thermal power at 96%%d, holding due to EHC
-3/.29
~0330 high vibration.
- Increased reactor thermal power from 96/ to 97$.
3/3l 2400 steady state.
Reactor thermal power at 97/, steady state.
13 AVERAGE DAlLYUNITPOWER LEVEL DOCKET NO.
Browns Ferry I DATE 4
4 78 COIIPLETED BY Don Green N
205/729-6846 MONTH HGrcIt 1978 DAY AVERAGE DAILYPOWER LEVEL (MWe-Net) 1046 "1'055 DAY AVERAGE DAILYPOWER'LEVEL (MWe-Net) 1035 17 1043 4
10, 12 13 14 15 1057 810 867 964 1051 1050 1064 1061
'995 1033 1061 1053 1062 19 21 22'0 31 1073 1054 1054 1057 1048 1031 998 1056 1053 1052 1051 1066 1047 INSTRUCTIONS On this format, list the average daily unit power level in MWe-Net for each day in the reporting month. Compute to the nearest whole megawatt.
(9/77)
14 AVERAGE DAILYUiVITPOWER LEV I
DOCKET NO.
DATE COMPLETED BY TELEPHONE Browns Ferry TX 4-4-78 Don Green 205/729-8316 March 1978 DAY AVERAGE DAILYPOWER LEVEL (MWe-Net) 915
'922 905 895 886 891 899 DAY 17 18 19 21 AVERAGE DAILYPOWER LEVEL (MWe-Net) 924
~
358
-10
~ 9
]0 12 16 878 884 688 814 911 931 923 926 26 30 31 lNSTRUCTIONS On this format, list the average daily unit power level in MWe.Net for each day in the reporting month. Compute to the nearest whole megawatt.
.r (9/77)
15 AVERAGE DAILYUNITPOWER LEVEL-DOCKET NO.
UN)T DATE
. COMPLETED BY Browns Ferry III 4-5-78 TELEPHONE 205/729-6846 MONTH March 1 78 DAY AVERAGE DAILYPOWER LEVEL (MWe-Net) 1014
'1023 983'002 DAY AVERAGE DAILYPOWER LEVEL (MWe-Net)
-10 19
)0 12 13
)4
)6 989 938 999 1002 982 994 988 1013 958 21 27 30 31
-=13 446 789 742 858 992 1013
~
1023 1021 1029 1028 INSTRUCTIONS On this format, list the average daily unit power level in MWe.Net for each day in the reporting month. Compute to the nearest whole megawat t ~
(9/77)
16 OPERATL (G DATAREPORT DOCKET NO. 59-2'i DATE COMPLETED BY DsrI1 tzr~e TELEPHONE 20.'iLZP~46 OPERATIiVG STATUS Notes
~
I. Unit Name
, 2. Reporting Period:
Ha>ch 1978
- 3. Licensed Thermal Power <hlWt):
- 4. Name late Rating (Gross hIWe):
P 1065
- 5. Design Electrical Rating (Net MWe):
1098
- 6. Maximum Dependable Capacity (Gross MWe):
e endable a acit Net MWe:
- 7. MaxuuumD p C p y(
)
S. IfChanges Occur in Capacity Ratings (Items Number 3 Through 7) Since Last Report, Giv>> Reasons:
- 9. Power Level To Which Restricted. IfAny (Net MWe):
- 10. Reasons For Restrictions, IfAny:
- -"-This Month 11; Hours In Reporting Period 744
- 12. Number Of Hours Reactor Was Critical
~
. 7
- 13. Reactor Reserve Shutdown Hours
~. 14. Hours Generator On-Line 744
~
- 15. Unit Reserve Shutdown Hours
- 16. Gross Thermal Energy. Generated;(MWH)
- 17. Gross Electrical Energy Generated (ibIWH)
- 18. Net Electrical Ener y Generated (MWH)
- 19. Unit Service Factor
- 20. Unit Availability Factor 100
- 21. Unit Capacity Factor (Using MDC Net) 95 ~ 8
~D. Unit Capacity Factor (Using DER Net)
- 95. 8
- 23. Unit Forced Outage Rate
- 24. Shutdowns Scheduled Over Next 6 Months (Type, Date, and Dura
~Yr:to-Date 2,160 18 1.5 0
1723.97 0
4,680,264 1 564 760 1 520 591 79.8 79.8 76.7 76.7 0.9 tion of Each):
Cumulativ 32;138 4046;8
'4370.
1 0
37,053,493 12 382 780 12 008 938
'4.7 44.7 35.1 35.1 47.1
- 25. IfShut Down At End Of Report Period. Estimated Date of Startup:
- 26. Uni'ts In Test Status (Prior to Commercial Operation):
Forecast INITIALCRITICALITY INITIALELECTRICITY COMMERCIALOPERATION
)
I t
'i (9177)
17 OPERATING STATUS OPERATPiG DATAREPORT DOCKET NO.
DATE COMPLETED BY-Don Green
. TELEPHONE ~2~2-846 Umt Name'rown Ferry II 2
R O' '.
- March, 1978
. 2. Reporting Period:
- 3. I.icensed Thermal Power (MIVt):
- 4. Nameplate Rating (Gross hIWe):
- 5. Design Electrical Rating (Net MWe):. 1065
- 6. hIaximum Deoendable Capacity (Gross MWe):
~ '. Maximum Dependable Capacity (Net MWe):
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 MWe):
- 10. Reasons For Restrictions, IfAny:
'This Month
~ ~Yr:to-Date Cumulative 11.
12.
13.
- 14.
15.
16.
17.
18.
19.
20.
21.
'd,.
23.
24, 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 (hIWH)
Gross Electrical Energy Generated (MWH)
Net Electrical Energy Generated (hIWH)
Unit Service Factor Unit AvailabilityFactor Unit Capacity Factor (Using MQC Net)
Unit Capacity Factor (Using DER Net)
Unit Forced Outage Rate Shutdowns Scheduled Over Next 6 Months 744
, 419 54.5 419 0
- 1. 146 71-3 381 600 370 225 56.3 56.3
- 46. 7 46.7 2.6 (Type, Date, and Duration of Each):
2160 1757.87 131.63 1723. 67
- 4. 810 169 1 569 110 1 525 116
- 79. 8
- 79. 8 66.3 66.3 6-. 6 27 049 12326.1Q 11,331.40
'1,757'.03 0
30,983 306 10 166 060 9 867 920 43.5 43.5
- 34. 3 34.3
- 53. 3
- 25. IfShut Down At End Of Report Period. Estimated Date of Startup:
- 26. Units In Test. Status (Prior to Commercial Operation):
Forecast Achieved
,r ~,
(,, ~ ~ I i
~ ~
~ ~
INITIALCRITICALITY INITIAL ELECTRICITY COMMERCIAL OPERATION
~
~
~
~ '
(907)
18
~
~
OPERATING DATAREPORT OPERATING STATUS r
DOCKET NO.
50-296 DATE 4-444 COMPLETED BY TELEPHONE 846 No tes
~
Unit Name Browns Fer IEE
, 2. Reporting Period:
- 3. Licensed Thermal Power (MWt):
- 4. Nameplate Rating (Gross MWe):
- 5. Design Electrical Rating (Net MWe):
~
1065
- 6. Maximum Dependable Capacity (Gross i%1We):
c v etMWe:
- 7. Maximum Dependable Capa it (N
)
- 8. IfChanges Occur in Capacity Ratings (Items i%umber 3 Through 7) Since Last Report, Give Reasons:
/
~
~
i
- 9. Power Level To Which Restricted, IfAny (Net MWe):
- 10. Reasons For Restrictions, IfAny:
This Month
~Yr.-to-Date Cumulative I
- 11. Hours In Reporting Period,
- 12. Number Of Hours Reactor Was Critical
- 13. Reactor Reserve Shutdown Hours
- i. 14. Hours Generator On-Line
- 15. Unit Reserve Shutdown Hours
- 16. Gross Thermal Energy Generated (MWH)
- 17. Gross Electrical Energy Generated (MWH)
- 18. Net Electrical Energy Generated (idWH)
- 19. Unit Service Factor
- 20. Unit AvailabilityFactor
- 21. Unit Capacity Factor (Using KIDCNet)
'~M. Unit Capacity Factor (Using DER Net)
- 23. Unit Forced Outage Rate
- 24. Shutdowns Scheduled Over Next 6 Months REZUEL OUTAGE AUGUST, 1978.
'744 620.6 116.32 597.92 0
1,775,040 2 160 1,998.25 123.95 1,967.63 0
5,.812,310 569 898 884 096
- 91. 1
- 91. 1 81.
- 81. 9 7.3 80.4 80,4 71.9
- 71. 9 19.6 (Type. Date. and Duration of Each):
'9504 8693.9g 71)2. 36
'8466; 94 24,454,004, 7 735 002'9.1
- 89. 1 6.4 76.4 9.3
- 25. IfShut Down At End Of Report Period. Estimated Date of Startup:
- 26. Units ln,Test Status (Prior to Commercial Operation):
Forecast INITIALCRITICALITY INITIALELECTRICITY COMilIERCIALOPERATION
~l I
'"'9177)
f UNlTSllUTDO1VNS AND PO1VER REDUCT10NS REPORT MONTll DOCKET NO,
'OMPLETEDBY No.
Date C
.5K a-f4~
o~g 'J U~ a
~ C/)
a Liccnscc Event Report tnt Ew cn G
~ID 0 0 Cl E~
O CJ Cause Ec Correctlvc Acttun to Prevent Recurrence I
F: Forced S: Scheduled
(~l>>)
Reason:
A.Equipment Failure (Explain)
B.Maintenance or Test C-Refueling D-Regulatory Restriction E.Operator Training Ec License Examination F-Administratire G Operational Error (Explain)
Il-Other (Explain) 3 Method:
1-Manual 2-Manual Scram.
3-Automatic Scram.
4-Other (Explain) 5 Exhibit G - Instructions for Preparation of Data Entry Sheets for Licensee Event Report (LER) File(NUREG-OI 61)
Exhibit I - Sante Source
UNlTSIIUTDOWNS AND POWER REDUCTIONS DOCKET NO.
UNITNAhkE DATE 4-4-78 COMPLETED BY Do G
Date
, El CL I
r~
5 rsIll m ~OC o~
C
~ f/J Licensee Event Rcport 0 gE~
c3 Cause Ec Corrective Action to Prevent Recurrcncc 45 46 780318 780318 A'14 C
L'XCESSIVE LEAKAGE INTO DRYWELL SUMP DUE TO RECIRC.
DISC1IARGE LINE EQUALIZER VALUE PACKING LEAK.
REACTOR WAS ALREADY DOWN FOR EXCESSIVE DRYWELL LEAKAGE PROBLEM.
F: For<<cd S: Scheduled
(~/17)
Reason:
A.Equipment Failure (Explain)
B.Maintenance or Test C-Refueling D.Regulatory Restriction E-Operator Training & License Examination F-Administrative G.Operational Error (Explain) ll Other (Exp)ain) 3 Method:
I-Manual 2.Manual Scram.
3.Automatic Scram.
4.Other (Explain) 4 Exhibit G - instructions
" for Preparation of Data Entry Sheets for Licensee Event Report (LER) File(NUREG-OI 6l )
Exhibit I - San>c Source
UNITSIIUTDOWNS AND POWER REDUCTIONS REPORT MONTII
¹i DOCKET NO.
UNITNAME DATE COMPLETED BY TELEPIIONE 50-296 205 -729-68 No.
C ~
Q f5hK A~
PI Q
El Hg Q
~ CA Lkcnsec
. Event Rcport 4f Ew El Ol IA~G Q O E~
O CJ h
Cause &Corrective Action to Prcvcnt Recurrence 31 32 78()316 780321 F
134.38 A-F ll.70 A
BFRO-50-296/
784 SIMJLATED OFFSITE TESTS ON IDENTICAL ELECTRICAL PENETRATIONS SHOWED THAT TH PENETRATIONS WOULD FAIL.DURING LOCA.
PENETRATIONS WERE REPLACED.-
HAINTENANCE TO "D" TIP INDEXER, g
~
F: Forced S: Scheduled
(')/77)
Reason:
A-Equipment Failure {Explain)
B-Maintenance or Test C-Refueling D-Regulatory Rcstri<<tlon E-Operator Training & License Examination F-Administrative G-Operational Error (Explain)
I I.Otl>er {Explain)
,3 Method:
Ihlanual 2-Manual Scram..
3-Automatic Scram.
4-Other {Explain)
Exhibit G - Instructions for Preparation of Data Entry Sheets for Licensee Event Report (LER) File (NUREG-016I )
Exhibit I - Sante Source
CSSC EOUIPlKNT BROMNS FERf'Y fkiJCl.k9<K r's~iisi vexed MECHANICAL i~fAINTENANCE
SUMMARY
For. the Honth of l'
1978 ATE SYSTBf COlfPONENT EFFECT ON SAPE NATURE OF OPERATION OP NAINTENPXCE THE REACTOR CAUSE OF KYLFUNCTIOVi RESULTS OF mLFUNCTION ACTION TAKEN TO PRECLUDE RECURRENCE Dies 1
Generator 1 and 2 Diesel Generators Dirty Oil None Operation None Changed oil
/6 RHR Servic Hater Pumps Al, 2, 3, Bl, 2, 3, Cl, 2
3, and Dl, 2, 3
Packing leaks None Morn or loose packing None Adjusted and repackei
/9 Diesel Generator 3C, 38, 3D Diesel I
Low oil level None Unknocm None Added oil
/14 Intake Door Dragging at the bottom None Morn Hinges None Shiomed hinges of door
/21 Fuel Pool Cooling 0-7S-720 Steam leaking around packin'one L'oose packing None Tightened packing
CSSC E UIPMENT BROWNE FERRY NUCLEAR PLANE UNLY~
MECHANICAL MAINTENAHCE
SUMMARY
P For the Month of March 19 78 TE SYSTEM COMPONENT EFFECT OH SAFE NATURE OF OPERATION OF MAINTEHYNCE THE REACTOR CAUSE OF MALFUNCTION RESULTS OF MALFUNiCTION ACTION TAKEN TO PRECLUDE RECURRENCE Reactor BYater Recirc r
1A and B MG Set High oil vapo content None Ho filter in the system'one Placid filters in the oil mist eliminator RCIC Turbine Low oil in-boar/
bearing Hone Unknown Hone Added oil 8
EECB 13 CRD Reactor Mater Recirc 1-67-50 Control Rod 22-27 1A MG Set Bill not
~
o crate Stuck in position 46 Oil leak at flange gasket on su pl linc
...None None None Dirty filter Bad directional valves and clo ped filters Loose flange IHone None None Replaced filter Replaced valves and filters Tightened flange 21 CRD 23 Air Cond.
25 CRD 27 CRD 1B Pump lB control bay chiller Module 38-31 Module 42-31 High pp acros discharge filter Tube leaks Leaking pistol
'Leaking 82 isolation valve None Nona None None Dirty filter Unknown Operation "0" rin~ broken Born "0" ring and packing None None None None Changed filter Plugged 20 tubes Installed rebul.lt accumulator Changed packing and "0" ring YFen ti 1 a-tion FCV 64-14 Ventilatio lB Reactor Zone exhaust fan Air leak by dam ers Brolcen dia-phrain None None Bushing on the con trolanil is worn Operation Allow B fan to turn bnckwards None Replaced bushing Change operator
/31 CRD 1B pump disch valve 85-8-B Leaking Seal Hone Packing gland loose None Tightened pacl'ing gland
CSSC E UDtiENT RRURRRS PERRY NUCLEAR PLANT UNIT~>
MECHANICAL MAINTENANCE SUhfffARY For the Month of kfarch 1978
/6
/18
. SYSTEM Reactor Hater Cleanu HPCI COMPONENT 2B Reactor wate cleanup pump Booster pump NATURE OF
?fAIHTENANCE Blown seal Cooling line leakin EFFECT ON SAFE OPERATION OF THE REACTOR None None CAUSE OF MALFUNCTION Bad Bearing Loose union on 2-1/2 line RESULTS OF IfALFUNCTION None None ACTION TA!<EH TO PRECLUDE.
RECURRENCE Replaced bearings and set new seal Tightened union
/18 Ventilatio 2B Refuel Ex-haust fan Excessive noi and vibration None Bad bear ings Mone Installed new b~inj
/18 Core Spray 2B core spray Isolation pump drain valy Cooling 75-527B Packing leak Hone Loose packing None Tightened packing gland
/21 Standby Liquid Coolin Valve 63-518 Packing leak None Loose packing None Tightened packirg gland
/21 3/23 3/25 RCIC Reactor
>later Cleanu RCIC Pump 2B Reactor tfater Cleanup Pum lA Discharge filter Oil level low-inboard bearin Blown Seal
'High gp '..
~
~
Mone None
. Hone Oil leak Bad bearings Operation dirty filter Hone None None Added oil Replaced bearing~
- shaft, sleeve ai~
set. mechanical seal'nstalled new filter
CSSC E UIFiKNT BROHHS FERRY NuCLEAR i'LA'3T UAL'r MECllANICALMAINTENANCE SUlMARY For the Month of March 19 78'
~
SYS~f CONPONENT NATURE OP MAINTEKVICE EFFECT ON SAFE OPERATlON OP THE REACTOR CAUSE OP MALFUNCTION j
RESULTS OP MALFUNCTION ACTION TAKEN TO PRECLUDE RECURRENCE 14 16 16 Air Cond.
TIP 3B Control Bay Chiller Channel 10 A Discharge filter Clogged Coolii Valve Probe stops at indexer output 1ligh ~
None None None Unknown Loose fitting Clogged up Hone None None Replaced with new valve Tightened fitting Replaced filter 18 Standby Liquid Cooling A and B dis-charge relief valves Opening at to None low of pressu e
Unknown Hono Diaao:.crribLCd va an lapped disc and p ug, res~t at 1420 psi 20 RHR Loop I Leak on Charg ing water lin None Held crack on 1/2"'line coming off charging water line None Rewelded crack
/20 Doors Personnel acces to dr cell Unable to hold ressure None Bad "0" ring None Replaced "0" ring
/20 Ventilatioi Supply damper-to diesel Generator 3C Millnot open None
'lipped linkage on damper None Adjusted linkage
/.20 FCV 85-39A Module 30-11, Seal ring disk busted None Unknown None Replaced seal ri disk and body gasket
CSSC E UIRKNT RROe'RE FERRY NUCLEAR FLAUT UHXT X
ELECTRXCAL'AINTENANCESEQIARY For the Month of March 19 78 aete System Component
. Nature of Maintenance
~
ect on a e Opexation of The Reactor Cause of Malfunction Results of Malfunction Action Taken To Preclude Recurrence 3/1 Reactor 'efuel zone Bldg.
SBGT Pressure Ventilati n limit lockou relay Relay won' seal in None Relay contacts bad Relay wouldn'f. seal in Replaced lock out relay.
TR 55639 3/2 Fire
'ontrol card Protectior assembly Replace contro card. assembly None Control card assembly bad Heat detector zone Replaced control cara inoperable assembly in pa TR 86345 3/16 Fire Pro-tection Smoke Detecto Replace smoke detector None Smoke detector bad Alarm wouldn' clear Replaced smoke detect TR 86378.
BFRO 259/789 3/22 Control Rod Drive 1B CRD Pump disch.
MOV green light Replace trans-fer switch 85-8A None Contacts not making up on XS 85-8A No green light on 1B Replaced CS 85-8A CRD pump disch. valve TR 86440 and 86339
et" EROENS PEERY NUCLEAR PLANT UEXT XX ELECTRICAL kiAINTENA;ICE SU&fA'RY For the l.fonth of March 19 78 ate System
. Component Nature of maintenance lect on a e Operation of The Reactor Cause of Malfunction Results of Malfunction Act'on Taken To Preclude Recurrence 3/3 RHR Ser-vice Wate HS-23-8A Hand swi.tch won't start pump None Contacts on HS-23-8A woulgn't switch burned,.
start RHRSW pumps and not making up Replaced switch.
TR's 85867 and 85871
.'3/3 RBCCW Surge tank level swi.tch Adj. qwitch mechanism
- -
- None Float hanging in chamber.
Surge tank low level alarm wasn't coming in Adjusted float switc mechaoipm.
'L5i 358irG
.3/13 Air part.
RE 90-256 radiation monitoring Check power source
'. None Motor was dirty and pump was locking up Motor was tripping on Cleaned motor up and overload and blowing machinists changed fuses out pump.
TR 85819
.3/15 Control Bay HVAC 2A and 2B bat-Replace bear-tery room ex-ings in both haust fans fan motors None Bad bearing in Excessive noise when both exhaust fan fans were running motors Pulled motors and rc placed bearings.
TR 858S5 3/19 250V D.C.
250U D.C. sta-Clear ground tion battery on 250V sta-tion battery None Carbon post in tach-generator causing ground 120V positive ground on 250U station bat-teries Dismantled and clean tach-generator to clear ground'.
TR 8'/2?
RHR Testable Check No disc posi>>
Ulv 74-54 tion li,ght.
I 'one Limit switch out Jalve 74-S4 had no of adjustment on isc position 3.ight disc, position Adjusted limit switr for disc position.'R 82006
CSSC E UIBKNT EEO!iiVS FENNY'NUCLEAR PLANT UNIT III ELECTRICAL HATNTFiifANCE SUP'O'JARS For the Honth of Harch l978 ate 3/7 System Control Rod Drive
=
Component CRD accumula-tor level switches Nature of Haintenance Clean switches and verify operability ect on are Operation of The-Reactor None Cause of Halfunction Dirt on switch front Results of Halfunction Accumulator level switches wouldn'.
alarm Action Ta'::en To Preclude Recurrence Cleaned switches and verified operability BFRO 296/785 3/8 Diesel Generator D/G D
Replace isola-tion diodes in annunciator rela s
..None isolation diodes on annunciator relays short circuited D/0 D started when local annunciator test button pushes Replaced isolat=on diodes in anrun~
relays.
TR 665~
3/18 Reactor Building Closed Cooling Hater FCO 70-82 FCO 70-87 Xndicatipg lights 1
~
~
Adjust indicat ing light limi switches None Limit switches out of adjustmen FCO 70-82 and FCO 70-87 had no.in-dicating lights Adjusted indicating light limit switches.
TR's 52887, 86l36 and 86043
SSC EQUIPMENT URONNS PL'RRY NUCLPAR PLANT UNTT 0, 1
& g INSTRUMENT MAINTENANCE SMEARY I
POR TlcE MONTH OP March
> 197$
1 l
I ate System Component.'ffect on Safe Nature of Operation of
.Maintenance
- the reactor.'.'.
Cause of
.,':.Malfunction.:.
I ~
Results 'of
...Malfunction..
Action Tak to preclud recurrence it mmon 29 Fire Pxotec tion PI-26-46 Maintenance
. None
\\
Gage Damage t.
~
~
I Xndica 10 psi ed pres ure.
lov None 27'ad.
Monito 27 Rad. Monito it 2
-8 eactor ater Clean p
-14 od Positio nformation it 1 17 Reactor Mater Clean Up TS-69-30P 1Q&90-272B'73B RM-90<<139D dI-69-58 d<<38-43 Calibration
-. None Cal'ibration None Calibration'one Maintenance'ne',
'aintenance.
None'
~
I
~
~ I
~r Faulty Contacts Instrument Drift
~
~
~
~
Vo3.tage,Draff t
T Ipitrument'rift'-
~
~
~
~
Probe Shorted
~
~
~
~
~
~
~
~
~
~
~
~
~
~
~
~
~
~
~
L Svitch Interm Down S
(Readf.
Low In and Re to Flo rift mpose Contact operated ttently ale Alarm '
is in "R")
ication on Meter order Indication larm And Super".
Numbers None None None one one
~
~
~
~
~
~
~
~
~
\\
~
~
~
3
~
SSC EQUIPMENT BRONNE FERRY NUCLEAR PLANT UNIT 3
XNSTRUHI:NT MAINTENANCE
SUMMARY
I FOR TNE MONTN OF March
, 1978 I
ate System Component.".'ffect on Safe.
Nature of Operation of
.Maintenance'he reactor Cause of
- Halfunctioii'
.".".".'esults 'of
.Malfunction'..
Action Tak to precluc recurrenc(
19/7 21/78 27/78 28/78 PIC-85-66 PIC-85-67 Calibration Primary Containmen PR-64-50 Maintenance Rad. Monit r RM-90-256 Calibration Primary Contain-ment.
~ TM-64-52
.'alibration
~
~
None' None.
, ~
~ Setpoint drift
~ II I
f.oose slidewire contact I
0
. Setpoint drift "
~ '
- Instrument drift
~
~
~
~
~
~
~
~
~
~
~
~
I
~
~
I False ow pres ala ure None False ow pressure indi ation Nor Did no "agree with TI-64 52A None False igh indication None I
~
h I
~
~
I
~
l r
~
~
~
~
I
~
~
~
~ r
~
~
~
~
~
~
1,',:,...
~
~
~
~
~
~
~
~
~
~
~
~
~
~
~
~
~
~
~
~
~
~
~
~
~
~
~
\\
I
~
~
~
UNIT 2 31.
March 1978 Outage work accomplished or in progress includes:
Reactor disas-semb'ly, "fuel-un'load'ing, inspection of.hydraulic shock arrestors, inspection of suppression chamber by underwater divers, inspection and repair of instrument
- snubbers, electrical test and cleaning of motors, ground fault protection modification to CRD platform, feedwater and condenser leak checks, and probolog inspection and cleaning of electrical boards, TIP indexer main-tenance and modifications, EHC modifications, recorder maintenance, feedwater system instrument calibrations, and raw cooling water system cooler cleaning.
Primary containment isolation valve local leak rate testing has been in progress and approximately 3Q percent of the valves D (in board) and D (out board) have failed have been removed and sent to Hyle and the T
repair and set point calibration..
Work is tested failed.
NSEV '
A, B, and to meet leakage criteria.
MSRV's Power Service Shop for modification, under way to open, inspect and repair as necessary the A low pressure
- turbine, A reactor feedpump turbine, control valve and Al,, A2 combined intercept valves.