ML18024B176

Monthly Operating Repts for Nov 1979

ML18024B176
Person / Time
Site:	Browns Ferry
Issue date:	12/02/1979
From:	Green D TENNESSEE VALLEY AUTHORITY
To:
Shared Package
ML18024B175	List: ML18024B174 ML18024B176
References
NUDOCS 7912140393
Download: ML18024B176 (35)

Text

TENNESSEE VALLEY AUTHORITY DIVISION OF POWER PRODUCTION BROWNS FERRY NUCLEAR PLANT MONTHLY OPERATING REPORT November 1, 1979 November 30, 1979 DOCKET NUMBERS 50-259, 50-260, AND 50-296 LICENSE NUMBERS DPR-33, DPR-52, AND DPR-68 ji Submitted By:

Plant Superintendent

TABLE OF CONTENTS Operations Summary

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Refueling Information Significant Operational Events Average Daily Unit Power Level Operating Data Reports

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Unit Shutdowns and Power Reductions.

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Plane Maintenance Outage Summary

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0 erations Summa 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 five reportable occurrences reported to the NRC during the month of November.

Unit 1 There were two scrams on the unit during the month.'n November 8 the reactor scrammed due to turbine stop valve closure.

Stop valve closure occurred when a loss of power to the feedwater level controller caused a

false low water level signal in the feedwater controls, which in turn ramped h

up the feedwater pumps, tripping the turbine on reactor high water level.

The reactor was manually scrammed on November 24 to accomodate maintenance to drywell control air leakage.

Unit 2 The unit scrammed twice during the month.

On November 21, the reactor scrammed due to MSIV cl'osure during surveillance testing.

The reactor scrammed on November 29 due to high neutron flux, apparently from EHC pressure transients.

Unit 3 The unit was down for EOC-2 refueling the entire month.

2 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..

Closure studs 0.00421 0.00307 0.00263 0.20264 0.13241 0.10293 0.17644 0.11372 0.08159 Note:

This accumulated monthly information'atisfies technical specification section 6.6.A.17.b(3) reporting requirements.

Common S stems Approximately 7.43E+5 gallons of waste liquid were discharged containing 8.94E-l curies of activity.

Refuelin Information Uni.t 1 Unit 1 is scheduled for its third refueling beginning on or about January 2, 1980, with a restart date of. February 18, 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 322 spent 7 x 7 fuel assemblies, two 8 x 8 R fuel assemblies, and 252 new fuel assemblies.

Because of modification work to increase spent fuel pool capacity to 3471 assemblies, present capacity is limited to 720 assemblies.

With present capacity, Unit 1 does not have full core discharge capability in the pool.

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, the 1979 refueling would be the last refueling that could be discharged to l

the spent fuel pool without exceeding that capacity and maintaining full core discharge capability in. the pool.

Unit 3 Unit 3 began its second refuel outage on August 24, 1979, with a scheduled restart date of December 7, 1979.

This refueling involves loading additional 8 x 8 R (retrofit) assemblies into the core, MSRV tailpipe routing, core spray piping modifications, feedwater sparger modifications, LPCI modifications, installing acoustical monitors on MSRV's, and con-tainment isolation modifications.

Resumption of operation following re-

~ fueling will require changes in technical specifications pertaining to the core thermal limits.

Licensing information in support of these changes has been previously submitted.

There are 764 fuel assemblies presently in the reactor vessel.

There are 144 discharged cycle 2 fuel assemblies and 208 discharged cycle 1 fuel assemblies 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.

5 Si nificant 0 erational Events Unit 1 Date Time Event ll/Ol/79 0001 Reactor thermal power at 97%, rod limited (max flow) control rod sequence "B"

11/03/79 2200 Reduced thermal power from 97% to 55% for removal of "A" recirculation pump from service for M.G. set oil cooler maintenance and turbine C.V. tests and SI's.

11/04/79 0100 Turbine C.V. tests and SI's completed, holding for "A" recirculation pump MG set oil cooler maintenance.

1005 1125 11/05/79 0335 "A" recirculation pump MG set cooler maintenance com-pleted and pump placed in service commenced power ascension e

Commenced PCIOMR from 85% thermal power Reactor thermal power at 97%, rod limited (max flow) 1500 11/06/79 0700 Reactor thermal power at 96%, rod limited (max flow)

Reactor thermal power at 95%, rod limited (max flow) 2155 Reduced thermal power from 95% to 73% for control rod pattern adjustment 11/07/79 0008 All control rods fully out (notch 48) 0025 11/08/79 0757 Commenced PCIOMR from 73% thermal power Reactor scram No.

115 l:rom 94% thermal power on stop valve (X) closure due to loss of power to feedwater level controller inverter 1017 Commenced rod withdrawal 1354 1635 1654 Reactor critical No. 132 Rolled T/G Synchronized generator, commenced power ascension 11/09/79 2300 Reactor thermal power at 50% and holding to extend unit operation and remain below 16350 KK/ton core exposure before scheduled shutdown

Si nificant 0 erational Events Unit 1 Date Time Event 11/10/79 0810 11/11/79 0100 11/12/79 2242 Commenced power ascension from 50%

Commenced PCIOMR from 60% thermal power Reduced thermal power from 96% to 75% to extend and remain below 16350 >1ND/ton core exposure before scheduled shutdown ll/13/79

0430, 0600 Commenced power ascension Commenced PCIOMR from 85% thermal power 2150 Reduced thermal power from 95% to 75% to, extend and remain below 16350 NOD/ton core exposure before scheduled shutdown 11/14/79 0340 Commenced power ascension 0500 Commenced PCIOMR from 90% thermal power 2006 Reduced thermal power from 95% to 80% to extend and remain below 16350 K&/ton core exposure before scheduled shutdown 11/15/79 0320 0430 Commenced power ascension Commenced PCIOMR from 90% thermal power 0700 Reactor thermal power at 95%, rod limited (max flow) 1957 Reduced thermal power from 95% to 75% to extend and remain below 16350 %AD/ton core exposure before scheduled

'hutdown 11/16/79 1028 Reduced thermal power from 75% to 65% to extend and remain below 16350 NWD/ton before scheduled shutdown 11/21/79 1240 Commenced power ascension 1500 Commenced PCIOMR from 83% thermal power 11/22/79 1500 Reactor thermal power at 95%, rod limited (max flow) 1605 Reduced thermal power from 95% to 90% due to excessive vibration on EHC piping 1700 Reactor thermal power increased to 95%, rod limited (max flow)

Si nificant 0 erational Events Unit 1 Date Event 11/23/79 2315 Reduced thermal power from 95% to 80% for turbine C.V.

tests and SI's, 11/24/79 0245 Turbine C.V. tests and SI's completed, commenced power ascension 1000 Commenced thermal power reduction from 92% for shutdown to repair drywell control air leakage 1136 Reactor scram No. 116 (Manual) from 40% thermal power to accomodate maintenance to drywell control air leakage 11/25/79 1030 1315 1616 Commenced rod withdrawal Reactor critical No.

133 Rolled T/G 1637 Synchronized generator, commenced power ascension 2230 Commenced PCIOMR from 70% thermal po~er ll/26/79 2047 Reduced thermal power from 85% to 45% due to both recir-culation pumps tripping during surveillance testing 2125 Both recirculation pumps placed in service, commenced power ascension (Sequence "A")

11/27/79 0700 2035 Commenced PCIOMR from 85% thermal power Reactor thermal power at 95%, rod limited (max flow) 11/29/79 1410 Reduced thermal power from 95% to 75% due to both recir-culation pumps run back when Unit 2 scrammed 1445 1500 ll/30/79 2400 Commenced power ascension Reactor thermal power at 92%, rod limited (max flow)

Reactor thermal power at 92%, rod limited EOC (max flow)

Si nificant 0 erational Events Unit 7,

Date Time Event 11/Ol/79 0001 Reactor thermal power at 82%,

PCIOMR in progress, control rod seauence "B"

1500 Reactor thermal power at 86%

, rod limited (max flow) 11/02/79 2243 Reduced thermal power from 86% to 50% for control rod pattern adjustment and turbine C.V. tests and SI's 11/03/79 0030 Turbine C.V. tests and SI's completed, holding for control rod pattern adjustment 0105 Control rod pattern adjustment completed commenced power ascension

.from 50% thermal power 0340 Reduced thermal power from 65% to 50% due to recirculation pumps run back when "C" RFP tripped (inadvertantly closed pump suction valve) 0355 "C" RFP placed in service 0425 Commenced p'ower ascension 0830 Commenced PCIOlR from 70% thermal power 1500 Reactor thermal power at 75%; holding for removal of "A" RFP from service for maintenance 1645 "A" RFP maintenance completed and pump placed in service, commenced power ascension 1705 11/04/79 1900 11/05/79 1222 2100 Commenced PCIOHR from 80% thermal power Reactor thermal power at 98% rod limited {max flow)

Reduced thermal power from 98% to 95% for TIP set retest TIP set retest completed 2135 Commenced PCIOMR from 95% thermal power 2330 Reactor thermal power at 98%, rod limited (max flow)

Si nificant 0 erational Events Unit 2

Date Time Event 11/10/79 0015 Reduced thermal power from 98X to 85% for turbine C.V.

tests and, SI's 0205 Turbine C.V. tests. and SI's completed, commenced power ascension 0250 Commenced PCIOMR from 95% thermal power

, 0730 Reactor thermal power at 98%, rod limited (max flow) 11/16/79 2345 Reduced thermal power from 98% to 85% for turbine C.V.

tests and SI's 11/17/79 0100 Turbine C.V. tests and SI's completed, commenced power ascension 0200 0700 Commenced PCIOHR from 95X thermal power Reactor thermal power at 98X, rod limited (max flow) 11/20/79 1500 11/21/79 1044 Reactor thermal power at 98%, rod limited (max flow)

Reactor scram No.

87 from 98% thermal power due to (2)

MSIV closure while performing SI 1349 Commenced rod withdrawal for startup 1650 Reactor critical No.

98 (Sequence B) 2014 2044 11/22/79 0500 11/23/79 0700 Rolled T/G Synchronized generator, commenced power ascension Commenced PCIOIR from 70% thermal power Reactor thermal power at 93% rod limited (max flow) 2205 Reduced thermal power from 93% to 85% for turbine C.V.

tests and SI's 2250 Turbine C.V. tests and SI's completed, further reduced thermal power to 55% for control rod pattern adjustment

10 Si nificant 0 erational Events Unit 2

Date Time Event 11/24/79 0045'ontrol rod pattern adjustment completed, commenced power ascension 0640 Commenced PCIOMR from 85% thermal power 1525 11/29/79 1410 Reactor therma'1 power at 98%, rod limited (max flow)

Reactor scram

, No.'8 from 98% thermal power on APRM (1) hi flux due to EHC pressure regulator malfunction 1712 1855 11/30/79 1104 Commenced rod withdrawal Reactor cirtical No.

99 (Sequence B)

Synchronized generator, commenced power ascension 2400 Reactor thermal power at 65% with power ascension in progress

Si nificant 0 eratlonal Events Unit 3 Date Time Event 11/01/79 0001 ll/04/79 1445 11/16/79 1718 Unit shutdown for refueling outage EOC 2

Commenced loading BOC 3 fuel in the vessel Completed loading BOC 3 fuel in the vessel Refueling outage continues 11/30/79 2400 Unit refuel outage continues Equipment malfunction (1)

(2)Personnel error

12 AVERAGE DAILYUNITPOWER LEVEL DOCKET NO.

12-.2-79 COMPLETED BY MONTH November 1979 DAY AVERAGE DAILYPOWER LEVEL.

(MWe-Net)

DAY AVERAGE DAILYPOWER LEVEL (MWe-iNet) 646 17 7

8 10 12 13 14 15 16 772 1036 983 882 448 489 540 952 934 948 736 18 19 20 21 22 23 24 25 26 27 28

'l9 30 31 684 666 667 786 976 449 137 6

978 INSTRUCTIONS On this format.!ist the average daily unit power level in MWe.Net for each day in the reporting month. Compute to the nearest whole rnegawart.

('>/77 )

13 AVERAGE DAILYUNITPOWER LEVEL DOCKET NQ.

50: 260 UNIT Brd s Ferry 2

MONTH November 1979 DAY AVERAGE DAILYPOWER LEVEL (MWe-iVet)

I 10 DAY AVERAGE DAILYPOWER LEVEL (MWe-Net) 1064 17 7.

8 10 12 13 14 15 16 762 1068 1067 1067 1069 1055 1065 1068 1068 1072 1067 1064 18 19 20 21 22 23 24 25 26 27 28 29 30 31 1074 1064 1068 5516 824 977 1020 1069 1070 1068 628 282 INSTRUCTIONS Qn this:ormat.!ist the ave.a e daily unit power level'n Mme.Net for each day in the reporting inonth. Compute to the nearest whole me;~uvatt.

(')l77 )

AVERAGE DAILYUNITPOWER LEVEL MONTH

November, 1979 DAY AVERAGE DAILYPOWER LEVEL (MWe-Net)

I

-6 DAY AVERAGE DAILYPOWER LEVEL (MWe-Net)

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17 18 19

')0 21 10 13 14 IS 16 23 24 25 26 27 28 29 30 31

-10 INSTRUCTIONS On this tormat.!ist the average daily unit power IeveI'In MNe.Net for each day in the reponing month. Compute to the nearest whole megawatt.

(9I77 )

15 OPERATING DATAREPORT DOCKET iVO.

DATE COi~IPLETED IIY Dorl Green TELEPHONE 2QQZ2~o-846 OPERATING STATUS Notes I. Unit Name:

2. Reporting period:

November 1979

3. Licensed Thermal Power (MWt):

4. Nameplate Rating (Gross MWe):

5. Design Electrical Rating (Net MWe): 1

6. Maximum Dependable Capacity (Gross MWe): 1098 4

u De endableCa acit Netii(We:

7. iIaxtm m p

p y(

)

8. IfChanges Occur in Capacity Ratings (Items Number 3 Through 7) Since Last Report. Give Reasons:

N A

9. Power Level To Which Restricted, IfAny (Net il(We):

10. Reasons For Restrictions. IfAny:

This i~(onth

,Yr..to.Date Cumulative II. Hours In Reporting Period

12. iVumber Of Hours Reactor Was Critical

13. Reactor Reserve Shutdown Hours

31. 60

14. Hours Generator On-Line 682.

03-'5.

Unit Reserve Shutdown Hours

16. Gross Thermal Energy Generated (MWH) 1 796 417

17. Gross Electrical Energy Generated (MWH)

18. Net Electrical Energy Generated (MWH)

19. Unit Service Factor

94. 7

. 94.7

20. bnit Availabihty Factor

21. Unit Capacity Factor (Using MDC Net)

23. Unit Forced Outage Rate 5.3

24. Shutdowns Scheduled Over Next 6 months (Type, Date, and Duration of 016 7,301.69 2 0.48 7 177.39 0

21 236 682 6 998 100 6,812,645 89.5 89.5 79.8 79.8 4.8 Each l:

46.754 27,533.28 26 868.73 72 009 354 23 816 100 23,118,865 57.5 57.5 46.4 46.4 33.6

25. IfShut Down At End Of Report Period. Estimated Date of Startup:

26. Units ln Test Status (Prior to Commercial Operation):

Forecast Achieved INITIALCRITICALITY INITIALELECTRICITY COMAIERCIALOPERATION (o(77)

16 OPERATING DATAREPORT r

DOCKET NO.

DATE ~~~

COMPLETED BY ~Green TELEPHONE ~cij22~ 846 OPERATING STATUS I. Unit Name'

2. Reporting Period:

ovem er

3. Licensed Thermal Power (MWt):

4. Nameplate Rating (Gross MWe):

5. Design Electrical Rating (Net MWe):

6. Maximum Dependable Capacity (Gross MWe):

7. 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.

11 12 13 14 15 16 17 18 19 20 21 23 24 This Month

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Yr.-to-Date 8,016 720 0 2.47 0

2 109 331 2

244 716 980 699 755 88.0 88.0 81.8

81. 8 2.0 Duration of Each):

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 (M1VH)

Unit Service Factor 95 ~ 7 Unit Availability Factor 0

Unit Capacity Factor (Using DER Net) 91.3 Unit Forced Outage Rate 4.3 Shutdowns Scheduled Over Next 6 Months (Type. Date. and Cumulative 41 '665 23 913.45

'23.120.33 0

20'69 517 55.5 55.5 47 47.0 37.2

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 INITIALELECTRICITY COiNIMERCIALOPERATION (o/77)

17 OPERATING DATAREPORT OPERATING STATUS I. Unit Name

2. Reporting Period:

November i 79

3. Licensed Thermal Power (i~IWt):

4. Nameplate Rating (Gross MWe):

5. Design Electrical Rating (Net M)Ve):

P' l: JJSB Notes DOCKET NO.

DATE

~ COMPLETED BY Doh Green.

TELEPHONE 2Q.'iLZ2~o-846

7. Maximum Depend b e C p y (

)

8. IfChanges Occur in Capacity Ratings (Items Number 3 Through 7) Since Last Report. Give Reasons:

N/A

9. Power Level To Which Restricted, IfAny (Net ilIWe):

10. Reasons For Restrictions, IfAny:

This illonth Yr:to.Date Cumulative 8 016 720 5 224.60 421.40 5,174.05 15 724 989 5 231 290 501:

72 0

59. 6

11. Hours In Reporting Period

12. Number Of Hours Reactor Was Critical 0

13. Reactor Reserve Shutdown Hours 0

14. Hours Generator On-Line

15. Unit Reserve Shutdown Hours 0

16. Gross Thermal Energy Generated (hktVH)

17. Gross Electrical Energy Generated (MWH)

19. Unit Service Factor

20. Unit'AvailabilityFactor 0

21. Unit Capacity Factor (Using ilIDCNet)

22. Unit Capacity Factor (Using DER Net)

23. Unit Forced Outage Rate 8.4

24. Shutdowns Scheduled Over iVext 6 h1onths (Type. Date, and Duration of Each):

24 '120 18 315.80 1 526.81 17 0

16 870 16 497 160

25. IfShut Down At End Of Report Period. Estimated Date ot Startup:

26. Units In Test Status (Prior to Commercial Operation):

r7 179 Forecast Achieved INITIALCRITICALITY

'NITIALELECTR.!CITY COiltMERCIALOPERATION (9/ I7')

P UNITSIIUTDO'lUNS AND PO)UER REDUCTIONS REPORT h(ONTH DOCKET NO.

UNITNAhlE Browns Ferry 1 COMPLETED BY No.

Date C ~

Vl

~

I C3 I

N C

c pe Llcellscc Event Rcport 8

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o~

0C CI C ~

Cause 8r, Corrective Action Io Prevent Recurrence 102 791103

'I Derated for recirc pump MG set oil cooler maintenance 103 791106 Derated for control. rod pattern adjustment 104 791108 8.95 A

Turbine stop valve closure due to loss of power in"A"level controller 105 791124 29.02 Maintenance to drywell control air leak 106 107 791126 791129 Derated when both recirc pumps trippe Derated when both recirc pumps ran-back due to unit 2 scram I". Forced S: Schcd>>1erl

('I/77)

Reason:

A-Iuluipment Failure (Explain)

B.Mairltenancc or Test C-Ref<<e lint, D Regulatory Restriction E-Ot)erator Tlainint, k. Uccnsc Examination F.Administrative G.Operational Error (Fxplain)

I I Other (Iixpiain) 3-Method:

I.hlanual 2-hlanual Scram.

3-Autoluatic Scram.

4-Other (Explain)

Exhibit G - Instructions I'or Preparation ol'ata Lnlry Sheets lor Liccttsec Event Report (LER) FIIL'.NOREG-016I )

Exhibit I - Sante Source

UNITSHUTDO)VNS A4D PO)VER REDUCTIONS REPORT MONTH DOCKET NO.

UNITNAhIE DATE COMPLETED DY TEI.EPI IONE o

t:reen Ni),

Date CJp-I rr, o

4l x gee',

tl C

~ M Licensee Event Report 4

~

E~

Cl 4J'n N

ril G c~

p CJ 2 ~

O Cause Er. Correitrvc Action to Prevent Rccurrcnce 105-791102 Derated for turbine C.V. tests and SI's and control rod pattern adjustmen 106 791121 10.0 Personnel error during performance of main steam line low pressure SI 107 791123 Derated for control rod pattern adjustment 108 791129 P

20.9 A

Ilain steam pressure regulator malfunction F: Fore ll S: Scheduled Reason:

A-Frloipment Failure (Explain) lt.hlaiutcnancc or Test C-R fueling D.Regulatory Restriction C.Operator Training Ec Liccnsc Exanlination F-Adnlinislrative G-Opcratirutal L'rror (Explain)

I I Other (L'xplain) hlethod:

I Manual 2.Manual Scram.

3.Autonlat ic Scranl.

4.Other (Explain)

Exhibit G - Instructions I'or Prcpafalh)n of Data Entry Sheets for l.iccosee Event Report (I.LlR)Fills(NUREG.

OI 6l )

Exhibit I - Salnc Source

P UNITSIIUTDOQNS AND POWER REDUCTIONS REPORT MONTII DOCKET NO 50-296 12-2-79 COhIPLETED BY TELEPIIONE 205 729-6846 No.

l)atc P1 C

fj Cp

<Pi M

g oa Q~ CA Licenscc Event Report I

o ~

Q o C ~

o CJ Cause Sc Corrective Action lo Prevent Recurrence 109 791101 S

720 Refueling F: Forced S: Scltcdulerl

('>/77)

Reason:

A-Equipment Failure (Explain)

B.hiaintenance or Test C-Refuelinit D (tet,ulatory Restriction I'.-Operator Trainint,8c Liccnsc Examination F-Administrative G.Operational Lrnlr(Explain)

I I Other (lixplain) hlethod:

I -hlanual 2.Manual Scram.

3.Automatic Scram.

4-Other (Explain) 4 Exhibit G - Instructions I'or Preparation of Data Entry Shccts ior l.iccnsee Event Rcport ( I.E R> Filo(NURE-GOI6

)

5 Exlttbtt I Shanti Sour<<

CSSC E UIPMENT BROHNS PERRY NUCLEAR PLANT UNIT 2

MECIIANICAL? fAINTENANCE SU>MARY For the Month of November 19~9 ll/6 SYSTEM Off-Gas COMPONENT Off-Gas Chiller EFFECT ON SAPE NATURE OP OPERATION OF MAINTENANCE THE REACTOR Drier in liqu d None line to off-gas chiller CAUSE OP MALFUNCTION Dirty filters and valves RESULTS OF MALFUNCTION Dirty filters ACTION TAKEN TO PRECLUDE RECURRENCE Installed new filters and valves ll/14 HPCI Limitorque Broken on valve 73-35 None Unknown Broken limitorque housing and shaft Replaced new li torque housing a

shaft ll/ 8 CRD "2A" pump discharge filter Filter stoppe Up None Dirty filters Filters dirty Cleaned dirty filters 11/26

• 10/15 Equipment

Access, Locks, Doo Dampers Diesel Generator Door 479 (Battery Board Room)

-Gen.

"A" Door not shutting properly MMI 6 None None Closure 'out of adjustment To perform MMI 6 Door not shutting properly None Adjusted door closure to shut quicker W

MMI 6 Recorded hour readings.

• 10/15 Diesel Generator Gen.

"B" MMI 6 None To perform MMI 6.

None MMI 6 Recorde hour readings

~NOT REVIOUSLY 1 EPORTED

CSSC E UIPHENT BROMNS FERRY NUCLEAR PLANT UNIT 1

HEGiAHICAL MAINTENANCE SUlQfARY l

For the Month of No'vember 19 79 11/5 11/13 ll/ 3 SYSTEM CRD EECW Diesel Gen Fire Pump COMPONENT Rod 14-07 IIAII g IICII Core spray coolers Anti-Freeze coolant NATURE OF MAINTENANCE Rod drifting Valve stopped up Check. degrees of coolant EFFECT ON SAFE OPERATION OF THE REACTOR None None None CAUSE OF MALFUNCTION Leak at scram pilot valve Stopped up.valv en coolers I

Check for 0 below zero RESULTS OF MALFUNCTION Drifting rod Stopped up valve on "A" & "C" coolers Found coolant to go below 10 below zero 0

ACTION TAKEN TO PRECLUDE RECURRENCE Changed out 0-ring gaskets in pilot valve subassembly Blew out valve and unstopped block Added anti-freeze coolant ll 19 Drywell Air Comp.

Suction Strainer Needs to be replaced None Dirty filters Filters were dirty.

Removed filters and cleaned 11/22 Drywell Air Comp.

Solenoid Valve Valve is leak ing None Bad solenoid valve Leaking solenoid valve Replaced old solenoid valve 11/29 RCIC RCIC pedal sliding foot MMI 22 None None Checked as per TR Performed MMI 22

CSSC E UIPMENT BROWNS FERRY NUCLEAR PIANT UNIT 3

MEC11ANXCAL MAINTENANCE

SUMMARY

h'ot the 'Hooth of

. Noveehet 19~

DATE SYSTE11 Equip.

Access, Locks, Doo Fans

- COMPONENT Door 800 Diesel Gen.

NATURE OF MAINTENANCE Door does not function properly EFFECT ON SAFE OPERATION OF THE REACTOR None CAUSE OF MALFUNCTION Latch out of adjustment RESULTS OF MALFUNCTXON Door not functioning properly ACTION TAKEN TO PRECLUDE RECURRENCE Adjusted latch Oiled internal parts ll/P.

HPCI 11/t BPCI HPCI Booster pump HPCI Low oil level E

Drain oil and change filter None None

,'Low oil level t

Dirty o'il and filters Low oil level Dirty oil Oil to be change during.,unit outage Changed oil and filters ll/15 HPCI Booster pump Filtered oil thru center-fuge None None QA inspection of oil Filtered oil in HPCI ll/16 CRD 10-51 N2 leak None Bad "0" ring Leaking Replaced 0-ring ll/18 Fire Pro-Valve 26-761 tection Hard to open None Valve needs lubricating Valve hard to open 11/19 HPCI 11/2 HPCI ll/2 HPCI Booster pump HPCI Oil tank Low oil level Overspeed test Oil level low None None None None None Unknown Low oil level Tested HPCX for overs eed Low oil Added oil to proper level Overspeed HPCI Added oil to proper level

CSSC E UIEtKNT BUNCE FERRY 'NUCLEAR PLANT URYT 1

'ELECTRICAL *MAINTENANCE SRMRY por the Month of November 19 79 Date System Component Nature of Maintenance ect on a e Operation of The Reactor.

'ause of Malfunction Results of Malfunction Action Taken To Precluae Recurrence 11/3/79 I

Penetra-tions Penetration seal S eal. brok'en'.

None broken seal Seal integrity weakened Replaced seal.

TR 134779

CSSC E IJIAKNT BRONNR PERRY NUCLEAR PLA2lY UN11 2

ELECTRICAL MAINTENANCE SENARY For the Month of November 19 79 1

'System Component Nature of Maintenance ect on a e Operation of The Reactor Cause of Malfunction Results of Malfunction Action.Taken To Preclude Recurrence ll/6/79 I

RCIC RCIC trip solenoid Solenoid grounded None Failed solenoid mechanism Solenoid grounded Replaced solenoid, mechanism checked OK.

TR 161304 11/l,i/2 11PCI FCV-73-35 (HPCI test V-motor limit switches)

Runs past ful None ly closed and thermals out Valve housing broken and motor failed Motor thermals.out on closing Mechanical mainte nance replaced housing.

Electrical installed new limits and torque switch.

Performed EMI 18,.

Checked OK.

TR 149825

URER PERRX NUCLEAR PLANT URLT 3

ELECTRICAL MAINTENANCE StMfARY Por the Month of November 19 79 Date 11/2/79 ll/2)79

'System RCIC Neutron monitor--

ing Component PCV-'71-19 Condensate storage suc-tion V motor SRH and IRM drive relays number 7C-K9C and number 7C-K9J coils Nature of Haintenance 250V-negative grbund on cable Coils are'pen ect on a e Operation of The Reactor.

Not -applicable Not applicable Cause of Malfunction Wire'umber S-1 inside cable Pailed coils Results of Malfunction Ground on cable Coils open Action Taken To Preclude Recurrence Repaired using VQ 58 Checked OK.

TR-150761 i

Replaced coil.

Checked OK.

TR.

117103 11/9/79 Neutron monitor-ing Panel 25-14 relay 7C-K7H coil Coil 'open Not applicable Failed coil Open coil Replaced coil, Checked OK.

TR 161504 ll/13/79 Unit pre-ferred 120V AC system Unit preferred MG set, AC motor,:DC

motor, and generator-bearings Replace bear-,

ings and repack with grease Not applicable Noisy bearing and preventative maintenance pro-gram Failure to perform maintenance would have resulted in bearing failure Replaced all bear-ings on AC-DC'motors and generator and repacked with grease Checked OK.

TR 143065 11/16/79 HPCI FCV-73-44 (HPCI pump discharge'alve) motor EMI 63 Not applicable Failed bearings, uneven commutato brushes short an chipped Arcing and pitting Replaced brushes and

bearings, had commu tator turned, cleanejd motor, performed EHI 63 and EHI 18.

Checked OK.

TR 139660

CSSC E UIPMENT ERORRR PERRY EUOLEAR PL@IX UUXY 3

ELECTRICAL MAINTENANCE SRQfARY For the Month of November 19 79 P

Date

'System Component Nature of Maintenance ect on a e Operation of The Reactor Cause of Malfunction Results of Malfunction Action Taken To Preclude Recurrence 11/24/79 HPCI HPCI,inver ter Failed inver-,

ter ailed inverter None refueling F

outage I

HPCI would not have Replaced inverter.

operated Checked OK.

TR 154110 11/2'79 HPCI HPCI magnetic pickup Damaged pick-Up None -'refueling outage fagnetic pickup damaged HPCI would not have Replaced magnetic~

'perated

=

pickup.

TR 146924 ll/2 /79 Primary contain-ment FCV-64-139 (compressor inlet valve) solenoid coil Coil grounded None - refueling outage il grounded

'-.'alve would not operate properly Replaced,coil.

Checked i~K.

work plan 9690.

TR 137708

CSCC E UIPMENT BROGANS FERRY NUCLEAR PLANT UNIT 1

INSTRUMENT MAINTENANCE SU1$ ARY FOR THE MONTH OF November

, 1979 Date System Component Effect on Safe Nature of Operation of Maintenance the reactor Cause of Malfunction Results of Malfunction Action Taken to preclude recurrence 11-5 11-24 Primary Containmen Containmen Air Dilution PI-64-135 TA-84-31 Replace Repair None None aulty Indicator pen Relay Coil Two readings did not agree Alarm would not'lear None None

CSCC E UIPMENT BROWNS PERRY NUCLEAR PLANT UNIT 2

INSTRUMENT MAINTENANCE SENARY POR THE MONTH OP November~

197 9 Date System Component,.

Nature of Maintenance Effect on Safe Operation of the reactor '.

Cause of Results of

.-,...Malfunction

'.. " Malfunction Action Tak n to preclude recurrence 11-8 11-8 Rod Block fonitor adiation fonitoring R.B.M."A" RM-90-133D Repair Repair None None Paulty Relay Faulty high voltage card Pront panel indicator did not agree with computer and APRM "E" indicator Alarm in with normal signal None None 11-20 rimary PI-64-137 ontainment Calibrate None Instrument drift Alarm setpoint low None

CSCC E UIPMENT BROWNE PERRY NUCLEAR PLANT UNIT 3

INSTRUMENT MAINTENANCE

SUMMARY

POR THE MONTH OP November 1979 Date 11-6 System Core spray Rod positfo information

. Component PI-75-21 RPIS-18-19 Calibrate None Repair None Effect on Safe Nature of Operation of Maintenance the reactor Cause of

Malfuiiction" Flow modifier drift Paulty probe buffer card Results of

".Malfunction Indicated flow when there was none Rod drift alarm Action Tak n to preclud

,recurrence None 11-7 FI-74-64 Calibrate None Plow modifier drift Indicated flow when there was none None 11-14 Control rod drive PDA-85-10 Calibrate None Setpoint too low P

Alarm would not clear None 11-16 Neutron Monitoring SRM-C Repair None Damaged during outage woik Drive would not operate None

31 OUTAGE

SUMMARY

November 1979 The unit 3, cycle 2 refueling outage is approximately 15.5 days behind schedule.

Critical path work remaining to be completed before startup con-sisted of a repair to the 'D'nboard MSIV air operator which was leaking and the performance of the SX Diesel Load Acceptance Test.

Other work during the outage proceeded with only minor delays.

All major turbine/generator maintenance was completed. on November 14, while all-major valve work was completed by November 3.

The changeout of the electrical transformers and associated testing were completed on November 2.

The con-tainment integrated leak rate test was completed satisfactorily on November 26; shortly thereafter, vessel reassembly commenced.

The reactor pressure vessel leak check was in progress at the end of the reporting period.