ML18025A962

Monthly Operating Repts for June 1980

ML18025A962
Person / Time
Site:	Browns Ferry
Issue date:	07/02/1980
From:	Green D, Thom T TENNESSEE VALLEY AUTHORITY
To:
Shared Package
ML18025A961	List: ML18025A960 ML18025A962
References
NUDOCS 8007160556
Download: ML18025A962 (34)

Text

TENNESSEE VALLEY AUTHORITY DIVISION OF POWER PRODUCTION BROWNS FERRY iiUCLEAR PLANT MONTHLY OPERATING REPORT June 1,

1980 June 30, 1980 DOCKET NUMBERS 50-259, 50-260, AND 50-296 LICENSE NUMBERS DPR-33, DPR-52, AND DPR-68 Submitted By:

Plant Superintendent

0

TABLE OF CONTENTS Operations Summary Refueling Information Significant Operational Events 4

6 Average Daily Unit Power Level 13 Operating Data Reports

~

~

~

16 Unit Shutdowns and Power Reductions.

Plant Maintenance Outage Summary

~

~

~

19 22 29

0 erations Summar June 1980 The following summary describes the significant operational activities during the reporting period.

In support of this summary, a chronological log of significant events is included in this reports There were fifteen reportable occurrences reported to the NRC during the l

month of June.

Unit 1 There were five scrams on the unit during the month.

On June 17, when moisture separator high water level, due to level control failure, caused a

trubine trip.

The reactor was manually scrammed later in the day to inves-tigate oil level alarms on the "B" recirculation pump motor.

The reactor was manually scrammed on June 23, to investigate level alarms on the EHC tank, leaks on the Nc.

2 control valve and PS47-144.

On June 24, the reactor shutdown twice because the control valve fast closure switch had been wired into the RPS incorrectly causing rod insertion during SI 4.1.A-12.

Unit 2 There were three scrams on the unit during the month.

On June 19, the reactor was manually scrammed for maintenance to decrease steam tunnel temperature.

The reactor scrammed on June 24, due to a turbine trip on loss of condenser

vacuum, caused by maintenance on LCV 6-84A, moisture separator pump level control valve on C2 heater.

Again on June 28, the reactor scrammed due to a loss of condenser vacuum caused by a diaphragm failure on (2FCV-66-11) the suction valve to the 2A SJAE.

0 erations Summar (Continued)

June 1980 Unit 3 There were two scrams on the unit during the month.

On June 7, the reactor scrammed due to a generator load re)ection from the ground detection relay.

On June 28, the reactor was manually scrammed in order that repairs to a leak in the feedwater line could be initiated.

During this scram approximately one-third of the rods did not go to the full insert position, additional operator action was required and all rods were fully inserted after approximately 14 minutes.

This problem is currently under investigation.

0 erations Summar (Continued)

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

Location Shell at water line Feedwater nozzle Closure studs Unit 1 0.00475 0.22762 Usa e Factor Unit 2 0.00355 0.15182 Unit 3 0.00301 0.11232 0.19298 0.12304 0.08893 Note:

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

Common S stem Approximately 2.94E+05 gallons of waste liquid were discharged containing approximately

2. 14E-01 curies of activity.

Refuelin Information June 1980 Unit 1 Unit 1 is scheduled for its fourth refueling beginning on or about April 15, 1981, with a scheduled restart date of July 25, 1981.

This re-l fueling will involve loading additional 8 x 8 R (retrofit) fuel assemblies into the core, the final fix on the sparger modification, power supply on LPCI modification, and torus modifications if all approvals are received.

There are 764 fuel assemblies in the reactor vessel.

The spent fuel storage pool presently contains 550 spent 7 x 7 fuel assemblies, five 8 x 8 fuel assemblies, one 8 x 8 R fuel assemblies, and 20 new P

8 x 8 R assemblies.

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

Unit 2

Unit 2 is scheduled for its third refueling beginning on or about September 1, 1980, with a scheduled restart date of October ll, 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, and power supply on LPGA modification.

There are 764 fuel assemblies in the reactor vessel.

At the end of the month, there were 132 discharged cycle 1 fuel assemblies, 268 discharged cycle 2 fuel assemblies, and 64 new 8 x 8 R 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

Refuelin Information (Continued)

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

Unit 3 Unit 3 is scheduled for its third refueling beginning on or about October 17, 1980, with a scheduled restart date of November 25, 1980.

This EQC-3 refueling, involves loading additional 8 x 8 R (retrofit) assemblies into the core, and power supply on LPCI modification.

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.

Si nificant 0 erational Events=-

Unit 1 Date Time Event 6/01/80 0001 0100 0515 2135 Reactor thermal power at 97%,

EHC vibration limited, Sequence "B"

Commenced reducing thermal power for removal of "B" recirculation pump MG set from service for brush replacement Reactor thermal power at 50%, holding for removal of "B" recirculation pump from service "B" recirculation pump MG set brush replacement com-pleted and pump placed in service, commenced power ascension 6/02/80 0430 1432 Commenced PCIOMR from 73% thermal power Reactor thermal power at 82%, holding due to HPCI being inoperable 6/05/80 0200 0300 1700 HPCI declared

operable, commenced power ascension Commenced PCIOMR from 88% thermal power Reactor thermal power at

>99% steady state 6/07/80 0300 0605 0730 1500 Reduced thermal power from 99% to 70% for turbine C. V. test and SI's Turbine C. V. tests and SI's completed, commenced power ascension.

Commenced PCIOMR from 90% thermal power Reactor thermal power at

>99%, steady state 6/13/80 1350 Reduced thermal power from >99% to 95% due to high river differential temperature 6/14/80 0207 0340 0700 Reduced thermal power from 95% to 85% for turbine C.V. tests and SI's Turbine C. V. tests and SI's completed, commenced power ascension Reactor thermal power at 96%, holding due to high river differential temperature 6/15/80

-1915 2215 6/17/80 0654 1000 1417 1652 Commenced PCIOMR from 96% thermal power Reactor thermal power at

>99%, steady state Reactor Scram No.

127 from >99% thermal power on moisture separator B-2 level high and turbine trip Commenced rod withdrawal Reactor critical No.

147 sequence "A"

Reactor Scram No. 128, from 5% thermal power manual due to receipt of "B" recirculation pump'ow oil level alarm

Si nificant Operational Events Unit 1 Date Time Event 6/18/80 2025 2346 2355 Commenced rod withdrawal (to stay subcritical)

Resume rod withdrawal Reactor critical No.

148 6/19/80 0535 0540 2030 Rolled T/G Synchronized generator, commenced power ascension Commenced PCIOMR from 70% thermal power-6/20/80 1930 2005 Reactor thermal power at 99%,

maximum flow Reduced thermal power from 99% to 92

% for removal of "B" string high pressure heaters from service due to leaks 6/21/80 0127 0220 0250 0355 0700 Reduced thermal power from 92% to 89% for CRD exercise "B" string high pressure heater maintenance completed, heaters placed in service CRD exercise completed, commenced power ascension Commenced reducing thermal power from 92% to 70% for control rod adjustment Control rod adjustment completed, commenced PCIOMR from 70% thermal power 6/22/80 1730 6/23/80 1843 1853 2155 Reactor thermal power at

>99%,

KZZ limited Commenced reducing thermal power for shutdown due to High EHC leaks (No.

2 Control Valve)

Reactor Scram No.

129 manual from 35% thermal power to accommodate maintenance to EHC leaks Maintenance to EHC completed, commenced rod withdrawal 6/24/80 0051 0240 0258 0454 0858

.1116 1405 1610 1628 2123 2348 Reactor critical No.

149 Rolled T/G Synchronized generator commenced power ascension Reactor Scram No.

130 from 30% thermal power-while performing SI. 4.1.A.12 (C. V. closure)

Commenced rod withdrawal Reactor critical No.

150 Reactor made sub-critical due to No.

3 Servo valve malfunction Reactor critical No.

151 Reactor Scram No. 131, manual from 10% thermal power whi.le performing SI 4.1.A.12 (C. V. closure)

Commenced rod withdrawal Reactor critical No.

152

Si nificant 0 erational Events Unit 1 Date Time Event 6/25/80 0200 0227 0830 Rolled T/G Synchronized generator, commenced power ascension Commenced PCIOMR from 55% thermal power 6/26/80 0700 Reactor thermal power at 76%, holding due to "A" reactor feed pump maintenance (turning gear mechanism) 6/27/80 0333 2015 Commenced power ascension from 76% thermal power "A" reactor feed pump maintenance completed and pump placed in service, commenced power ascension 6/28/80 0130 1530 1640 1808 1900 2300 Commenced PCIOHR from 86% thermal power Reactor thermal power at 99%,

maximum flow Reduced thermal power from 99% to 76%,

due to high main steam tunnel temperature Commenced power ascension Commenced PCIOIK from 93% thermal power Reactor thermal power at 99%,

maximum flow 6/30/80 2400 Reactor thermal power at 99%,

maximum flow

Si nificant 0 erational Events Unit 2

Date Time Event 6/01/80 0001 Reactor thermal power at 98%,

maximum flow sequence IIAII 6/02/80 0700 6/03/80 0700 6/07/80 0523 1518 2130 2250 Reactor thermal power at 97%,

maximum flow Reactor thermal power at 96%,

maximum flow Reduced thermal power from 96% to 52% due to "A" recirculation pump trip "A" recirculation pump tagged out for maintenance "A" recirculation pump maintenance completed and pump placed in service, commenced power ascension Commenced PCIOMR from 90% thermal power 6/09/80 0700 6/10/80 1500 6/13/80 2200 Reactor thermal power at 97%,

maximum flow Reactor thermal power at 95%,

maximum flow Reduced thermal power from 95% to 50% for control rod sequence exchange from "A" to "B" 6/14/80 0155 1510 Control rod sequence exchange completed, commenced power ascension (sequence "B")

Commenced PCIOi&E. from 66% thermal power 6/16/80 0130 6/19/80 2132 2231 Reactor thermal power at 98%,

maximum flow Commenced reducing thermal power for shutdown Reactor Scram No.

101 manual from 35% thermal power for scheduled outage 6/22/80 1600 1835 Commenced rod withdrawal Reactor critical No. 112, sequence "B"

6/23/80 1255 1343 6/24/80 0149 0651 0940 1225 1246 Rolled T/G Synchronized generator, commenced power ascension Reactor Scram No.

102 from 65% thermal power due to condenser low vacuum during maintenance on (6-84A) condenser drain valve.

Commenced rod withdrawal Reactor critical No.

113, sequence "B"

Rolled T/G Synchronized generator, commenced power ascension

10 Si nificant 0 erational Events Unit 2 Date Time.

Event 6/25/80 0001 6/27/80 0700 0713 Commenced PCIOHR from 67% thermal power Reactor thermal power at 95%,

maximum flow Reduced thermal power from 95% to 92% due to one-half scram when "A" RPS HG set isolated 6/28/80 0849 1155 1420 1855 1915 Reactor Scram No.

103 on condenser low vacuum, diaphram failure on Z FCV-66-11 Commenced rod withdrawal Reactor critical No.

114 Rolled T/G Synchronized generator, commenced power ascension 6/29/80 0730 6/30/80 2030 2400 Commenced PCIOMR from 65% thermal power Reactor thermal power at 97%,

maximum flow Reactor thermal power at 97%,

maximum flow

Si nificant 0 erational Events Unit 3 Date Time Event 6/01/80 0001 0150 1430 Reactor thermal power at 84%,

power ascension in

progress, sequence "B"

Commenced PCIOMR from 90% thermal power Reactor thermal power at 99%, rod limited 6/06/80 2130 2145 Reduced thermal gower from 99% to 50% due to "B" recirculation pump run back Commenced power ascension from 50% thermal power 6/07/80 1436 2214 Reactor Scram No.

84 from 99% thermal power when the ground protection relay tripped relay 186C which tripped the turbine scramming the reactor Commenced rod withdrawal 6/08/80

'115 0320 0341 1330 Reactor critical No.

94 Rolled T/G Synchronized generator commenced power ascension Commenced PCIOMR from 70% thermal power 6/10/80 1500 6/13/80 1405 1640 2030 Reactor thermal power at 98%,

maximum flow Reduced thermal power from 98% to 80% due to high river differential temperature Commenced power ascension Commenced PCIOMR from 88% thermal power 6/14/80 2300 Reduced thermal power from 97% to 60% for turbine C. V.

tests, SI's and control rod pattern adjustment 6/15/80 0046 0130 Turbine C. V. tests and SI's completed, holding for control rod pattern adjustment Control rod pattern adjustment completed, commenced PCIOMR from 60% thermal power 6/16/80 1630 6/20/80 2148 2215 2225 Reactor thermal power at 99% maximum flow Reduced thermal power from 99% to 90% Eor turbine C. V.

tests and SI's Turbine C. V. tests and SI's completed, commenced power ascension Commenced PCIOMR Erom 95% thermal power 6/21/80 0700 6/26/80 2300 Reactor thermal power at 98%,

maximum flow Reactor thermal power at 97%,

maximum flow

12 Si nificant 0 erational Events Unit 3 Date Time Event 6/27/80 2212 6/28/80 0130 0146 1320 Commenced reducing thermal power from 97% to shutdown for feedwater line maintenance Reactor Scram No.

85 manual from 35% thermal power to accommodate maintenance to feedwater line (leak)

The scram was completed, the delay being due to control rod insertion problems.

Reactor at cold shutdown 6/30/80 2400 Unit at cold shutdown for maintenance

13 AVERAGE DAILYUNIT POWER LEVEL DOCKET NO.

- UNIT Browns Ferry 1 DATE 7-2-80 COMPLETED BY TELEPHONE 205 729 6846 i~IONTH JOE 1980 DAY AVERAGE DAILYPOWER LEVEL fMWe.iilet) 602 DAY AVERAGE DAILYPOWER LEVEL (i'llWe.iVet )

298 l7 9

10 l3 IS l6 820 869 876 989 1050 997 1048 1057 1057 1054 1033 996 1015 1045 l8 I9 20 21 23 24

'i5 26 27 28 30 3I

-12 451 934 814 986 817 527 756 798 980 1034 1025 INSTRUCTIONS On tltis format. list the avera8c daily unit power level in lil>Vc iNet for each day in the rcportin ttti>ntlt. Ciiinputc to thc nearest whole m'cgawatt.

('>/77)

14 AVERAGE DAlLYUNITPOWER LEVEL DOCKET NO.

Browns Perry 2

COMPLETED BY Ted Thorn TFLEPHONE 205 729 6846 JUNE 1980 I

DAY AVERAGE DAILYPOWER LEVEL PI We-Net)

I

-1043 DAY AVERAGE DAILYPOWER LEVEL (ilIWe-iVet) 1015 17 3

4 10 13 14 IS 16 1021 1025 1032 1020 1020 667 965 1030 1015 1013 1011 972 620 918 1039 18 I9 20 21 22 23 24 25 26 27 28 19 30 31 1030 931

-10

-10

-10

'07 292 802 973 993 416 691 948 INSTRUCTIONS On this format, list the avcragc daily unit power level in i~lWe.Net for each day in thc reportin<>>nonth. Cinnputc to the nearest whole megawat t.

('>/77)

15 AVERAGE DAILYViVITPOWER LEVEL DOCKET iNO. 50-296 Browns Ferry - 3 COMPLETED IIY Ted Thorn TELEPHOyE 205 729 6846 IIOiNTH JUNE 1980 DAY AVERAGE DAlLYPOWER LEVEL (li(We.iVet) 1039 1075 DAY AVERAGE DAILYPOWER LEVEL (IIIVe.iVet )

1068 17 1072 10 13 14 15 16 1078 1076 1070 1036 612 582 994 1053 1032 1055 1001 1015 805 1028 19 90 23 24 95 26 27 28 19 30 31 1078 1065 1068 1072 1074 1071 1067 1061 1032

-12 INSTRVCTIONS Qn this format, list thc average daily unit power level in!iIVVciVet for each day in the reporting inonth. Ci>mputc tii the nearest whole megawatt.

('>/77)

16 OPERATING DATAREPORT DOCKET NO.

DATE 7-2-80 COMPLETED BY DQXL GXRfJ1 TELFPHONE ~~r~846 OPERATING STATUS Notes BROWNS FERRY UNIT 1 I. Unit Name:

Reporting Period:

3. Licensed Thermal Power (MIVt):

3293

4. Namephte Rating (Gross illWe):

5. Design Electrical Rating (Net ilI'LVe):

6. Maximum Dependable Capacity (Gross ill)Ve):

7. AIaximum De endable Ca acit Net AIWe:

1098.4 1065 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 LII'IVe):

10. Reasons For Restrictions, IfAny:

11. Hours In Reporting Period

12. Number Of Hours Reactor )Vas Critical

13. Reactor Reserve Shutdown Hours

14. Hours Generator On. Line

15. Unit Reserve Shutdown Hours

16. Gross Thermal Energy Generated (MWH)

17. Gross Electrical Energy Generated (AIWH)

18. Net Electrical Energy Generated (M'IVH)

19. Unit Service Factor

20. Unit AvailabilityFactor

21. Unit Capacity Factor (Using LIIDC iVet)

22. Unit Capacity Factor (Using DER Net)

23. Unit Forced Outage Rate

24. Shutdowns Scheduled Over Next 6 Months This Month 720 659.82 60.18 643.60 0

1,974,667 615 870 599,539 89.4 89.4 78.2 78.2 10.6 Yr.-to-Date 4 367 2191

~ 50 344.03 2,072.20 0

5,791,462 1 869,260 1,812,746 47.5

47. 5 39.0 39.0 16.4 (Type, Date.and Duration of Each):

Cumulative 51,865 30,468.78 5,033.64 29,684.93 0

79,927,955 26,387,720 25,614,714

57. 2 57 '

46.4 46.4

32. 0

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

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

INITIALCRITICALITY liVITIAL ELECTRICITY CORDI ERCIAL OPERATION Forecast Achieved

17 OPERATING DATAREPORT DOCKET NO.

DATE 7-2-80 COMPLETED BY Don Green TELEPHONE 2115 '~~846 OPERATliNG STATUS BROGANS FERRY UNIT 2

2. Reporting Period:

3. Licensed Thermal Power ()~fWt):

4. nameplate Rating (Gross illtVe):

5. Design Electrical Rating, (Net LlfWe):

6. ilfaximum Dependable Capacity (Gross hf'lVe):

7. Nfaximum Dependable Capacity (iNet iaaf We):

1098.4 1065 Notes

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

N/A

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

N/A

10. Reasons For Restrictions. IfAny:

11. Hours In Reporting Period

12. Number Of Hours Reactor Was Critical

13. Reactor Reserve Shutdown Hours

14. Hours Generator On-Line

15. Unit Reserve Shutdown Hours

16. Gross Thermal Energy Generated (iaaf WH)

17. Gross Electrical Energy Generated (MWH)

18. Net Electrical Energy Generated (MWH)

19. Unit Service Factor

20. Unit Availability Factor

21. Unit Capacity Factor (Using MDC i%et)

22. Unit Capacity Factor (Using DFR Net)

23. Unit Forced Outage Rate

24. Shutdowns Scheduled Over Next 6 iMonths Refuel Outage September, 1980 This Month 720 641.38

78. 62 611.42 Yr.-to.Dat 4,367 3,787.98 579.02 3,679.09 1,776,475 585,310 568,875 84.9 10,557,875 3,522,000 3,426,932 84.2 7.2 74.2 3.4 73.7 73.7 14.0 (Type. Date. and Duration of Each):

Cumulative 46,776 28,272.46 12,353.9f 27,343.40 0

76,712,875 25 472 068 24,758,401 58.5 58.5 49.7 49.7 34.5

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

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

Forecast Achieved INIT I A L CR IT I CA L IT Y

'INITIALELECTRICITY CORDIERCIAL OPERATION (rt/77)

18 OPERATING DATAREPORT DOCKET NO.

DATE 7-2-80 COilPLETED BY ~De Greetl TELEPHONE 2!15 '~846 OPERATliVG STATUS Notes BROIPilS F ERRY UNIT 3 Rei)oftlno Pefiud:

3. Licensed Thermal Power (ilIWt):

4. Nameplate Rating (Gross i)IWe):

S.

Design Electrical Rating (Net e))I)Ve):

6. Iiaximum Dependable Capacity (Gross )II')Ve):

7. l)Iaxin)um De endable Ca acitv Net l)IWe:

p p

.(

)

S. IfChanges Occur in Capacity Ratings (Items iVumber 3 Through 7) Since Last Report, Give Reasons:

N/A

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

10. Reasons For Restrictions. IfAny This )PIonth Yr.-to.Date 720 638.85 3,853.80 101.63 3822.80 0

11,937,761 672,640 4,029,030 654,737 3 927 577 87.5 87.5 84.4 84.4 12.5 I I. Hours In Reporting Period 4 367

12. iVumbcr Of Hours Reactor )Vas Critical

13. Reactor Reserve Shutdown Hours 81.15

14. Hours Generator On.Line 636.42

15. Unit Reserve Shutdown Hours 0

16. Gross Tliermal Energy Generated (M)VH) 1,990,334 17.

Gross Electrical Energy Generated

(~lDVH)

IS. Net Electrical Energy Generated (ebI)VH)

19. Unit Service Factor 88.4

20. Unit AvaihbilityFactor

~

~

88. 4

21. Unit Capacity Factor (Usillg ilIDCNet)

22. Unit Capacity Factor (Using DER iVet)

85. 4

23. Unit Forced Outage Rate

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

Refuel Outage October, 1980 Cumulative 299 231 22 761.35 1 759.96 22260.61 0

65,045 627 21,431,610 20 815 350 76.2 76.2 66.9 66.9 9.6

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

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

Undertermined Forecast Aclllcved IN ITIAL CRITICALIT Y INITIAL ELECTRICITY COiBDIERCIALOPERATION (ol77)

UNITSIIUTDOWNS AND POWER REDUCTIONS REPORT hlONTII JUNE DOCKET NO.

50 259 Browns Ferr 1

COA1PLETED BY TELEPIIONE 205 729 6846 N(i.

Ih>c r~I I

A 6

~

(Y Cl V)

L>ccnscc Event Rcporl <

CCI o

Cause

&r, C>irrcclivc Action>>>

Prcvcnl Recurrcncc 126 127 128 800601 800607 800617 F

9.97 crated to replace brushes in "B" ecirculation um M.G. set crated for turbine control valve tests and SI's Ioisture seperator high level 129 130 131 800617 800621 800623 F

36.80 8.08

'B" recirculation pump low oil level larm crated for turbine control valve tests and SI's faintenance to EHC oil leak 132 133 800624 800624 F

11.57 9.98 Phile performing control valve losure SI Phile performing control valve losure SI F: Forced Scheduled

('>/77)

Reason:

A E>Iuipmcnt Failure (Explain)

B.hlaintcnance or Test C-Refueling D.Regulatory Restriction E Ope>ator Training &: License Fxamination F-Administrative G.Operational Error (lixplain)

I I Other (Explai>>)

Method:

! -hlar>ual 2.hlanual Scram.

3-Auti>>nalic Sera>n.

4.0>hcf (Explain)

Fxhibil G - Instructions ror Prcparalii>>> of Data Entry Sheets I'or l.iccnsce Even> ltcport (LLR) File (NUREG.

016I)

Exhibit I - San>e S iurc'

UNITSIIUTDOWNS AND POWER REDUCTIONS

~EPOR~ WONnl DOCKET NO.

UN)A NAMF l)rowns Ferr

- 1 (Cont.

DATE 7-2-80 N>>.

l)atc PJ C

rP A

4>~ CI)

Liccnscc Event Rcp>>fr >

C 0

Cause A Corrcctivc Aclii>n l>>

Prevent Rccurrcnce 134 800628 Derated due to main steam line high tern erature F: Forced Scl)cduled (9/77),

Reason:

A-Equipmenl Failure (Explain)

D hlaintcnance or Test C. Refueling D Rcgtdatory Restricli>>n I'..Operator Trainiil k. License Examination F-Adnlinislra tive G.Opcfallonal Error (lixplain)

II-Other (Explain) 3 hlelhod:

I.hlanual 2-hianual Scraln.

3-Aul>>nmtic Sera>>i.

4 Olllcr (Explain)

Exhibit G - Instructions rillPrep'lratli>n ilfData I:nlry Sheets Ior l.iccnsi'c llvcot Rcp>>rl I I.I R) I'ilc(NUREG.

OI6I)

Exl)ibit I - San)<>ulcc

UNITSIIUTDO)VNS AND POPOVER REDUCTIONS r

REPORT MON'I'll DOCKET NO.

UN@ WeME Browoe~Ferr 2

DATE 7-2-80 COMPLETED HY Don fereen N>l.

l)atc rr.

I A

cc Cl~ C/l Llccnscc I:.vent Rcport ~

OJ CJ

~A rn'G o ~

Cr Causck Corrective Action to Prevent Rccurrcnce 140 800607 Derated due to "A" recirculation um tri 141 142 143 800613 800619 800624 S

87.20 B

F 10.95 B

Derated for control rod sequence exchan e from "A" to "B" Scheduled maintenance Condenser low vacuum during maintenance on condenser drain valve.

144 800628 F

10.o3 B

Condenser low vacuum F: Forced Scheduled (9/77)

Reason:

A-Equipment Failure (Explain)

B.Maintenance or Test C Rcfucllng I) Regulatory Restriction F..Operator Training E; License Exalnination I=-Adnllnlstratlvc G.Operational Lrrr>r (Explain)

I I.Other (L'xplain)

Method:

I -hlanual 2.Manual Scram.

3 Autolnatic Scraln.

'I Other (Explau>)

Exhibit G - Instructions for Prcparati>>n of Data Lntry Sh<<cts tor l.icc>>scc Event Report (I.ER) File (NUREG-OI 6l )

Exhibit I

~ Salnc S>>urcc

UNITSIIUTDOlVNS AND POlVER REDUCTIONS REPORT hjONTII JUNE DOCKET NO.

UNITNAhlE DATE COhtl'LETEl) BY TELEPI IONE 50-296 rowns erry 3 Don Green 205 729 6846 iV(i.

Date an a

ri an gr, A

CP L>i:cnscc Event Rcport ~

cCl 0

C +

Cr Cause A Correct we Acl>iin lo Prevent Recurrence 129 800606 Derated due to."B" recirculation pump runback 130 131 800607 800614 F

13.08 Ground protection relay trip a

Derated for turbine control valve

tests, SI's and control rod adjustment 132 800627 F

70.50 Maintenance to feedwater piping F: Forced Schedule>I

~ (')/771

~

Reason:

A-E>Iuipment Failure (Explain) 8-hlaintenance oi Test C-Refueling D.Regulatory Restrictioo I!.Operator Trainin k, Liccosc Exao>ination F.Ado>in ist ra Ii;c G Opera(>onal Lrfor(Explah>)

I I.O>l>cr (Explain).

3 hlcthod:

I -hlanual 2.hlaoual Scram.

3 Anti>n>>'ic Scran>.

4.0>her (L'xplaio)

Exhibit G - Instructions for Preparatiio> of Data i!@try Sl>cuts lor l.iccnscc I:vent Repi>rt (I.ER) File (NURI'.G-OI6I)

Exhibit I - Same Source

CSSC f:. VIPffrNT PROfrNS FERRY:,'UCf.EAR PLANT UNIT tfECffAf~iICAI.t>Tt'TERENCE SUtflfAftY SYS1i.if COi~fPObENT NATURE OF lfAINTENANCE EFFFCT 0Ã SP<E OPERATION OF TflE REACTOR CAUSE OF HALFUNCTION RESULTS OF MALFUNCTION ACTION TAKEN TO PRECL'UDE None

CSSC E

UIP11ENT 8ROt!NS FERRY NUCLEAR PLANT UNIT 1KC1UQiICAL HAINTENANCE SUMfARY

,'or the Honth of

- ~u<<19 80 DATE SYSTE11 COH PONENT EFFECT ON SAFE NATURE OF OPERATION OF 11AINTENANCE THE REACTOR CAUSE OF HALFUNCTION RESULTS OF HAI.FUNCTION ACTION TAKEN TO PRECLUDE RECURPZNCE 6/21/80 Radwaste 6/21/80 Recircula~

tion 6/21/80 Recircula-tion and HPCI 6/21/80 Hain Steam FCV-2-77-4A Valve 2-2-27A Valves 2-1118-L 2-110C-L 2-'110C-H and 3-68 Valve 2-1290-L 2-1198-L 2-119C-L 2-119A-L 2-119A-H 6-51D-L 6-51D-H 2-118D-L 2-118D-H 2-1188-L 2-1188-H 2-118A-L 2-118A-H 6-60C 6-51C-C 6-51C-,H 2-117D-H 2-117C-C 2-117C-H 2-117A-C 2-117A-H 6-608 6-518-C 2-1168-H 2-116A-L 2-116A-H 2-51A-C

')-C1 A u Valve will not open all the wa Valve needs to be repacked Valve needs to be repacked Valve needs to be repacked None None

.None None Bursted diaphrag'm Packing leak Packing leak Packing leak Inoperable valve Leaking valve Leaking valve Leaking valve Replaced diaphragm an<

stem o ring TR 146793 Repacked valve w graffoil packing TR 166605 Repacked valve with graffoil packing TR 166602 Repacked valve with graffoil packing TR 166606

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CSSC I'. UIPtlF.HT BRO>1iiS FERRY NUCLI'.AR PLANT UNIT FIEGIANICAL IIAIN'fENAHCE SUIII!ARY For the Month of June 19 80 DATF.

SYS'i'i.i 1

/17/80 UIR CO~ilPONENT Pump C

NATURE OF MAINTENANCE Drain pipe lea EFFECT ON SAFE OPERATION OF TIIE REACTOR None CAUSE OF MALFUNCTION Drain leak RESULTS OF MALFUNCTION Drain leak ACTIOH TPZN TO PRECLUDE RECUIUKNCE fightened casing rain fittings R 103460

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BFO!'HS EiUH lUC!.Ei'i: PL!)!

UliI'f ELECTRICAL lUIIHTENANCE SIMfARY For the lfonth of) une 19 80 L)atc System Component Nature of Haintenance E

ect on Sia e

Operation of The Rc,.c tor Cause of Halfunction Results of ifalfunction Action Taken To Preclude Recurrence 6-29-80 480 V R HOV Bd.

Rx liOV board 480 2A Rx HOV bd.

480 normal feeder breake at 480 shut-down bd.

2A

'will not close.

Caused loss of power to 2A Rx lOU Bd. until bd.

as energized'romalternate feeder.

Closing mechanism out of adjustment.

Loss of power from normal feeder breaker.

Adjusted closing

)I)echanism.

Checked ok TM l7ll00

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CSSC E UIPI'fENT

~ BROWNS FERRY NUCLEAR PLANT UNIT>>> < 3 INSTRUIIENT MAINTENANCE SlMfARY FOR THE HONTII OF June 19 80 DATE SYSTEIf nit 1 Primary Containment Primary Containment C(h~fPONENT TI-64-55A LI-64-54B NATURE OF MAINTENANCE Calibrate Calibrate EFFECT ON SAFE OPERATION OF THE REACTOR None None CAUSE OF kfALFUNCTION Instrument Drift Instrument Drift RESULTS OF MALFUNCTION False Indication Disagreement Between Redundant Indicators ACTION TAKEN TO PRECLUDE RECURRENCE None None.

~-10 Standby Liquid Con-trol LS-63-1 Calibrate None Setpoint Drift x

Intermittent False Alarm None

-18 Feedwa ter LI-3-53 60 206 Calibrate None Instrument Qrift Disagreement Between Redundant Indicators

'None I 25 Primary Containment LS-64-54A Calibrate None Setpoint Drift Alarm When Level Normal None fnit 2 i-20 Control Rod Drive RPIS Probe 42-31 Replace None Faulty Reed Switches No Indication at Position 2,3,6,7

& 9 None i-20 Neutron Ifonitoring

'IRH-H Replace None Detector Failure Erratic Indication None Jnit

) 5 5

Feedwater Feedwat<<r LI-3-58A LI-'3-58B Repair Replace None None Faulty Bearings in Indicator Indicat d Same Value Did Not Hove Failed Resistor Indicated Upscale None None

~a 29 OUTAGE STORY June 1980 Kgor emph'asis was placed on the security modifications in order to meet commitment dates of early August.

Other, modification work consisted of the anchor and hanger inspection per le Bulletins 79-02 and 79-14 with no major problems encountered, the construction of the new fabrication shop building, the construction of the east portal, the construction of the hypochlorite building, the addition of two condensate storage tanks and the cooling tower modifications.

Unit 2 was shutdown June 19, 1980, in order to install calcium silicate insulation on the main steam lines and modify the ventilation duct in the main steam tunnel to help reduce the extremely high temperatures experienced A

during unit operation.

Also, major emphasis was placed upon investigating the CRD problem I

experienced when Unit 3 which was shutdown June 28, 1980.

The work consisted of cutting the CRD water lines and inspecting for any debris that may have prevented 68 control rods from inserting fully.

The inspections revealed no debris either in the CRD lines or the scram discharge volume tanks.