ML18025B079

Monthly Operating Repts for Aug 1980

ML18025B079
Person / Time
Site:	Browns Ferry
Issue date:	09/01/1980
From:	Abercrombie H, Green D, Thom T TENNESSEE VALLEY AUTHORITY
To:
Shared Package
ML18025B078	List: ML18025B077 ML18025B079
References
NUDOCS 8009170277
Download: ML18025B079 (36)

Text

TENNESSEE VALLEY AUTHORITY DIVISION OF POWER PRODUCTION BROWNS FERRY NUCLEAR PLANT MONTHLY OPERAT3$ G REPORT August 1, 1980 August 31, 1980 DOCKET NI2iBERS 50 259 j 50 260> AND 50 296 LICENSE ~iBERS DPR-33, DPR-52, AND DPR-68

/

Submitted By.

Plant Manager

'277

It TABLE OF CONTENTS Operations Summary Refueling Information ~ ~ ~ ~

Significant Operational Events Average Daily Unit Power Level . ~ ~

Operating Data Reports 14 Unit Shutdowns and Power Reductions. 17 Plant Maintenance 20 Outage Summary . 28

0 erations Summer August 1980 The following summary describes the significant operational activities during the reporting period. In support of this summary, a chronological log of significant events is included in this report.

There were eleven reportable occurrences reported to the NRC during the month of August.,

Unit 1 There were no scrams on the unit during the month.

Unit 2 There was one scram on the unit during the month. On August 16, the reactor scrammed from closure of the HSIV's caused by the PCIS not being reset prior to testing the second switch during a surveillance instruction (resulting in a full isolation signal).

Unit 3 There were no scrams on the unit during the month.

2 0 erations Summar (Continued)

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

Location Usa e Factor Unit 1 lJnit 2 Unit 3 Shell at water line 0.00485 0.00368 0.00308 Fe'edwater nozzle 0.22994 0.15706 0.11326 Closure studs 0.19498 0.12571 0.09060 Note: This accumulated monthly information satisfies technical specification section 6.6.A.17.B(3) reporting requirements.

Common S stem Approximately 1.38E+05 gallons of waste liquid were discharged containing approximately 7.96E-02 curies of activity.

Refuelin Information July 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-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, and one 8 x 8 R fuel assembly. 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 5, 1980, with a scheduled restart date of October 16, 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 LPCI 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 240 new p 8 x 8 R assemblies in the spent fuel storage pool. The present storage capacity of the spent fuel pool is 820 asse'blies. <i'ith present capacity, the 1979 refueling was the last

Refuelin Information (Continued)

July 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.

However, new high density storage racks are being installed prior to the upcoming third refueling of Unit 2.

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 EOC-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, 208 discharged cycle 1 fuel assemblies, and 164 new P 8 x 8 R 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.

0 Si nificant 0 erational Events Unit 1 Date Time Bvent 8/01/80 0001 Reactor thermal power at 98%, maximum flow control rod sequence "A".

8/04/80 0300 Reduced thermal power from 98% to 85% for turbine C. V.

tests and SI's.

0345 Increased thermal power to 90/, holding for control rod exercise SI.

0405 Turbine C. V. tests, SI's, and control rod exercise. SI completed, commmenced power ascension.

0700 Reactor thermal power at 98%, maximum flow.

1400 Reduced thermal power from 98%-to 85% due to condenser high back pressure.

1440 Commenced power ascension.

1500 Reactor thermal power at 98%, maximum flow.

8/09/80 2205 Reduced thermal power from 98% to 52% for removal of "B" recirculation pump MG set from service for brush replacement.

s/ao/so olio "B" recirculation pump MG set brush replacement completed and pump placed in service, holding at 52% thermal power for removal of "A" recirculation pump MG set from service for brush replacement.

0125 "A" recirculation MG set removed from service for brush replacement.

0235 "A" recirculation pump MG set brush replacement completed and pump placed in service, commenced power ascension.

0500 Commenced PCIOMR from 65% thermal power control rod sequence "A".

8/11/80 1500 Reactor thermal power at >99%, steady state.

8/12/80 0400 Thermal power reduced from >99% to 95% as a result of loss of preferred power.-

0930 Commenced PCIOMR from 95% thermal power control rod sequence "A".

1243 Reactor thermal power at >99%, steady state.

8/16/80 0040 Reduced thermal power from >99% to 80% for turbine C. V.

tests and SI's.

0320 Turbine C. V. tests and SI's completed, commenced power ascension.

0400 Commenced PCIOMR from 90% thermal power control rod sequence "A".

1500 Reactor thermal power at >99%, steady state.

s/as/so 2 oz Reduced thermal power fro~i >99% to 75% for control rod 18-39 solenoid maintenance and control rod pattern adjustment.

Si"nificant 0 erational Events Unit 1 Date Time Event 8/19/80 0210 Control rod 18-39 maintenance and control rod pattern adjustment completed, commenced power ascension.

0530 Reactor thermal power at >99%, steady state.

8/22/80 2300 Reduced thermal power from >99% to 53% for control rod pattern adjustment, turbine C. V. tests and SI's.

8/23/80 0200 Control rod pattern adjustment, turbine C. V. tests and SI'ompleted, commenced power ascension.

0230 Commenced PCIOMR from 70% thermal power - control rod sequence "A".

8/24/80 2300 Reactor thermal power 99%, maximum flow.

8/30/80 0015 Reduced thermal power from 99% to 80% for turbine C. V.

tests and SI's.

0240 Turbine C. V. tests and SI's completed, commenced power ascension.

0700 Reactor thermal power at >99%, steady state.

8/31/80 2400 Reactor thermal power at >99%, steady state.

Si nificant 0 erational Events

-Unit 2 Data Time Event 8/01/80 0001 Reactor thermal power at 45% with power ascension in progress.

0130 Reduced thermal power from 60% to 50% for control rod pattern adjustment.

0300 Control rod pattern adjustment completed, commenced power ascension.

1330 Commenced PCIOMR from 68% thermal power control rod sequence "B".

8/03/80 0700 Reactor thermal power at 96%, maximum flow.

8/04/80 1358 Reduced thermal power from 96% to 75% due to loss of plant preferred power and recirculation pumps run back.

1540 Commenced power ascension.

1545 Reactor thermal power at 95%, maximum flow.

8/05/80 2222 Reduced thermal power from 95% to 55% for control rod pattern adjustment.

8/06/80 0105 Control rod pattern adjustment completed, commenced power ascension, control rod sequence "B".

0330 Commenced PCIOMR from 70% thermal power.

0720 Reactor thermal power at 75%, holding for removal of "A" reactor feed pump from service for maintenance (replaced vibration pickup).

1055 "A" reactor feed pump maintenance completed and pump placed in service, holding for removal of "B" reactor feed pump from service for maintenance (replaced vibration pickup).

1320 "B" reactor feed pump maintenance completed and pump placed in service, commenced power ascension.

1630 Commenced'CIOM from 78% thermal power.

8/07/80 1800 Reactor thermal power at 98%, maximum flow.

8/10/80 0205 Reduced thermal power from 98% to 85% for turbine C.V.

tests and SI's.

0320 Turbine C. V. tests and SI's completed, commenced power ascension.

0700 Reactor thermal power at 98%, maximum flow.

8/ll/SO 2217 "B" recirculation pump ran back, due to 'electrical switching, reducing thermal power from 98% to 93%.

'7')

35 "B" recirculation pump run back reset, commenced PCIO~E from 93% thermal power.

Si nificant 0 erational Events Unit 2 Date Time Event 8/12/80 2320 Reactor thermal power at 97%, maximum flow.

8/15/80 2340 Reduced thermal po~er from 97% to 80% for turbine C.V.

tests and SI's.

8/16/80 0155- Turbine C. V; tests and SI's completed, commenced power ascension.

0539 Reactor Scram No. 108 from 95% thermal power while performing SI 4.2.A-S (MSL Tunnel High Temperature).

1322 Commenced rod withdrawal.

1625 Reactor Critical No. 118, sequence "B".

1933 Rolled T/G.

1955 Synchronized generator, commenced power ascension.

8/17/80 0704 Commenced PCIOMR from 80% thermal power control rod sequence "B".

8/18/80 0600 Reactor thermal power at 97%, maximum flow.

8/19/80 0040 Reduced thermal power from 97% to 80% for control rod pattern adjustment.

0115 Control rod pattern adjustment completed, commenced PCIOMR from 80% thermal power, moving toward all rod out condition.

1500 Reactor thermal power at 94%, maximum flow, EOC 3 coast down.

8/22/80 1500 Reactor thermal power at 95%, maximum flow.

8/26/80 2310 Reduced thermal power from 92% to 75% for removal of "C" RFP from service for Special Test No. 185 (vibration checks).

8/27/80 0907 ST 185 (vibration checks) completed and "C" RFP placed in service, commenced power ascension.

1000 Commenced PCIOMR from 81% thermal power, moving toward an all rods out condition.

8/28/80 1050 Reactor thermal power at 94%, maximum flow.

8/29/80 2300 Reactor thermal power at 92%, EOC-3 coast down.

2342 Reduced thermal power from 92% to 80% for turbine C. V.

tests and SI's.

8/30/SO 0230 Turbine C. V. tests and SI's completed, commenced power ascension.

0700 Commenced PCIOMR from S5% thermal power.

2300 Reactor thermal power at 92%.

8/31/SO 2400 Reactor thermal power at 92%, EOC-3 coast down continues.

Si nificant Operational Events Unit 3 Date Time Event 8/01/80 0001 Reactor thermal power at 94%, maximum core flow rod limited (sequence "B")".

2215 Reduced thermal power from 94% to 51% for removal of "B" recirculation pump MG set from service for brush

'eplacement.

8/02/80 0310 "B" recirculation pump MG set brush replacement completed and pump placed in service, holding for control rod pattern adjustment.

0700 Control rod pattern adjustment completed, commenced power ascension.

0730 Commenced PCIOMR from 66% thermal power control rod sequence "B".

8/03/80 1830 Reactor thermal power at 94%, maximum flow rod limited.

8/04/80 0900 Corznenced power ascension by withdrawing control rods.

1500 Reactor thermal power at 99%, maximum flow.

8/09/80 0105 Reduced thermal power from 99% to 47% for control rod sequence exchange from "B" to "A".

0310 Control rod sequence exchange completed, commenced power ascension.

0555 Reactor thermal power at 60%, holding for TIP run.

1245 TIP run completed, commenced power ascension.

1430 Commenced PCIOMR from 77% thermal power - control rod sequence "A".

8/11/80 0310 Reactor thermal power at >99%, steady state.

0505 Reduced thermal power from >99% to 85% due to "A" reactor feed pump trip on low oil pressure.

0535 "A" reactor feed pump placed in service, commenced power ascension.

1207 Commenced PCIOMR from 95% thermal power, control rod sequence "A".

1905 Reactor thermal power at >99%, steady state.

E 8/13/80 1500 Reactor thermal power at 99%, maximum flow.

8/16/SO 2210 Reduced thermal power from 98% to 63% for control rod pattern adjustment.

8/17/SO 0125 Control rod pattern adjustment completed, commenced power ascension.

0230 Commenced PCIOMR from 78% thermal power control rod sequence "A".

10 0

Si nificant 0 erational Events Unit 3 Date Time Event 8/18/80 0700 Reactor thermal power at 99%, maximum flow.

8/22/80 2207 Reduced thermal power from 99% to 65% for removal of "B" condensate booster pump from service for maintenance.

8/23/80 0145 "B" condensate booster pump maintenance completed, commenced power ascension.

0315 Commenced PCIOHR from 85% thermal power, control rod sequence "A".

1900 Reactor thermal power at 99%, maximum flow.

8/30/80 0030 Reduced thermal power from 99% to 80% for turbine C. V.

tests and SI's.

0200 Turbine C. V. tests and SI's completed, commmenced power ascension.

0800 Reactor thermal power at >99%, steady state.

8/31/80 2400 Reactor thermal power at >99%, steady state.

(1) Personnel error.

P l

I AVERAGE DAILYUNIT POWER LEVEL DOCKET NO. 50-259 UNIT Browns Ferry 1 DATE 9-1-8 COi1PLETED BY Ted Thorn TELEPHONE 205 729 6846 MONTH Au ust 1980

. DAY AVERAGE DAILYPOWER LEVEL DAY AVERAGE DAILYPOWER LEVEL I IIWe-Net ) (SIWe Net) 991 17 1023 1013 18 1009 1011 19 988 1013 'lP 1027 1032 21 1030 1016 '1018 1019 23 03 1010 1008 977 '75 1014 716 1023 10 26 971 27 1028 1021 28 1032 13 1017 99 1029 1026 30 1025 1030 1035 15 31 16 971 INSTRUCTIONS On this tortnat.!1st the as'efa;e daily, unit poa'<.'r Iesel in F15'e.Net I'or each dJy in the fepnflin8 ll'lnnlh. Cnnlpule ln lhe fleafest <<lnlle nlee<ai'Patt.

l~ll771

12 AVERAGE DAILYUNIT POWER LEVEL DOCKET NO 50-260 Browns Perry 2 DATE COMPLETED BY Ted Thotrt TEf PPHONE 205 729 68 MONTH DAY AVERAGE DAILYPOWER LEVEL DAY AVERAGE DAILYPOWER LEVEL (MWe-Net I IMWe.Net) 631 788 886 IS 986 1005 19 955 990 20 974 971 2l 969 755 964 23 965 1026 959 1016 'l5 950 lp 1019 26 944 27 815 1 0 28 972 l3 'l9 997 30 926 IS 994 3I 957 272 INSTRUCTIONS On t!tis iornnt.!!st thc average Gaily unit pnrccr IclcI ln 11'tVC Nct iof chch dly tn thc rcpnrtin tnnnth. Compute tn tile nccrcrl tcllulc tnc3JN'nit.

('tr77)

13 AVERAGE DAlLYUi"IITPOlVER LEVEL COMPLETED GY TELEPHOgE 205 729 6846

'ugust 1980 (MlVe.Net)

DAY AVERAGE DAILYPOb'ER LEVEL DAY AVERAGE DAILYPOlVER LEVEL

{ MIVe.<1 et )

870'7 731 1063 999 19 1057 1056 80 1062 1065 1Q38 1061 13 974 1040 1054 75 1Q57 10 26 1063 101 1066 1054 28 1060 1023 o9 1057 13 0 30 1045 15 1034 31 1066 16 1003 INSTRUCTIONS On t'!til fortnat. hst the underage dulls'nit poaer Ieiel in balll'e Yet for i@eh day in the reporting tnonth. Contpute to tlje tte3 f erat N lto!e ta eeghvut t ~

(it/77 1

14 OPERATl>VG DATA REPORT DOCKET NO.

DATE 9-1-80 COl>IPLETED BY ' e n TELEPHOVE 6846 OPERATING STATUS U>i>f N >nie Browns Ferrv - Unit 1 iVotes t>n P'rh>d: Au ttsr 1980

3. Licensed Thermal Power'MlVt):

4. Na>neplate Rating (Gross!>ItVe):

1152

5. Deiign Electrical Rating (Net lilVe):

6. ~lamin>u<n Depen<lable Capacity (Gross MWe):

1098.4 1065

.(

7. ~laxi>nu>n De p endable Ca p acitv Iiiet ~flVe: )

8. If Chan"es Occur in Capacity Ratings (Items >Vumber 3 Through 7) Since Last Report. Give Reasons:

9. Pn<ver L<<vcl T<> VVhich Restricted, If Any (<Vet!>INe):

10. Reaioni F<>r Restricti<>ns. If Any:

This Month Yr.-to-Date Cumulative

11. Hours ln Reporting Period 744 5 855 53 353

12. >Number Of Hours Reactor IVas Critical 744 3,653.13 31,930.41

13. R<<actor Reserve Shutdown Hours 4

14. Hours Generator On. Line 744 3 524.43 31 137.16

15. Unit Reserve Shutdnivn llours 0 0 0

16. Grosi Thermal Energy Generated (MPH) 2,362,150 10,254,956 84,391,449

17. Gross Electrical Energy Generated (~IIIVH) 766,580 3,297,780 27,816,240

18. Net Electrical Fnergy Generated (ihOVH) 741;958 3,194,295 26,996,263

19. Unit Service Factor 100 60.2 58.4

20. Unit Availability Factor 100 60.2 58.4

l. Unit Capacity Factor (Using l>IDC Vet) 93.6 51.2 47.5

22. Unit Capacity Factor (Using DER <Vet) 93.6 51.2 47.5

23. L'nit Forced Outage Rate 0 11.2 31.1

24. Sill>ld<>wns Scheduled 0'v<'.f lilext 6 i>Ionths IType. Date. and Duration uf Each I:

i5. If Shut 1)oivn At End Of Re pnrt Period, Estimated Date of Startup:

'o. Uniti In Teit Status tpri<>r to Con>mercial Operation): Forecast Achieved INITlAL CRITlCA LITY INITIAL ELECTRICITY CO.'>OI ERCIA L OPERATION (9/77)

15 OPERATIi cG DATA REPORT DOCKET NO.

DATE COMPLETED SY Don Green TELEPHONE ~~'~846 OPERATING STATUS

l. Unit Name v- nit 2 Notes Reportjnz Period. Au ust 1980

3. Licensed Thermal Power (IIIVt):

4. Nameplate Rating (Gross IIWe): 1152

5. Design Electrical Rating (Net IIIVe):

7. XIaxhnunt Dependable Capacity (Net illWe): 1065

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

N/A

9. Povver Level To Which Restricted, If Any (Net IIWe);

N/A

10. Reasons For Restrictions. If Any:

This Month Yr..to.Date Cumulative I I. Hours In Reporting Period 744 5 855 48,264

12. Number Of Hours Reactor Was Critical 7 33 ~ 23 5,185.33 29,669.81

13. Reactor Reserve Shutdown Hours 10.77 648.94 12 423.88 I4. Hours Generator On. Line '29.73 5 052.32 28 716.63

15. Unit Reserve Shutdown Hours 0 0 0

16. Gross Thermal Energy Generated (IIWH) 169 170 1 ~ 585 80 740 799

'7. Gross Electrical Energy Generated (MWH) 4,838,890 26 788,958

18. Net Electrical Fnergy Generated (NIWH) 6 6 119 4 26.030 899

19. Unit Service Factor 98.1 86.3 59.5

'0. Unit Availability Factor 98.1 86.3 59.5 I. Unit Capacity Factor (Using ~IDC Net) 75.4 50.6 2 . Unit Capacity Factor (Using DER Net) 50,6

'3. Unit Forced Outage Rate 1.9 12.~I 33.6

'4. Shutdowns Scheduled Over Next 6 ~Ionths(Type. Date.and Dur'ation of Each):

Reruel outage September 5, 1980, 42 days.

'5. If Shut l)oivn At End Of Report Period. Estimated Date of Startup:

'6. Units ln Test Status (Prior to Cotnmercial Opemtiun): Forecast Achieved INITIAL CRITICALITY INITIALELECTRICITY COiDIERCIAL OPERATION (o/77)

16 OPERATING DATA REPORT DOCKET NO.

DATE 9-1-80 CO~IPLETED BY Don Gree>

TELEPHONE ~~EM846 OPERATING STATUS Browns Ferr Unit 3 Notes I. Unit Name

2. Reportinu period: Au ust 1980

3. Licensed Thermal Power (>IWt):

4. Nameplate Rating (Gross IIWe):

1065

5. Design Electrical Rating INet IIWe):

6 >Iaxhnu>n Depentlable Capacity (Gross a>IWe):

~

1098.4

.(

7. Ilaxin>u>n De >endahle Ca p acitv Net hIIVe: 1065

)

II. If Chan es Occur in Capacity Ratings (Items Number 3 Through 7) Since Last Report, Gimme Reasons:

N/A

9. Pd>>ver Level Td> Which Restricted, If Any (iVet II'lVe):

10. Reasons Fd>r Restrictions. If Any:

This 4>Ionth Yr. to-Date

~ Cunt ula I t'vc

11. Hours ln Reporting Period 5,855 30,719 I . Number Of Hours Reactor Was Critical 5,100.22 24,007.77

13. Reactor Reserve Shutdown Hours 0 101.63 1 759.94

14. Hours Gvnterator On Line 744 5,003.13 23,440.94 IS. Unit Reserve Shutdo>vn llours 0 0

"""t Gree: El'errieat Ener y Generated >tlttH) ~~~> 4>G 5 217 450 22 620 030 IS. Net Electrical Energy Generated (IIWH) 5 073 556 21,961,329

19. Unit Service Factor 100 85. 5 76.3

'0. Unit Availability Factor 76.

l. Unit Capacity Factor (Using MDC Net) 95.2 ' 81.4 67.1

. L'>>it Capacity Factor(Using DER Net) 95. 2 81.4 67.1

'3. Unit Forced Outa e Rate 0 14.5 10.3

24. Shutdovvns Scheduled Over Next 6>>Ionths(Type. Date. and Duration of Each):

Refuel outage October 1980.

25. If Shut I)>>wn At End Of Report Period. Estimated Date of Startup:

o. L'nits In Test Status (Prior to Conlltlercial Operation): Forecast Achieved IN IT IA L CRITICALITY INITIAL ELECTRICITY CO.'>I!>IERCIA L OPERATION (o/77)

~ ~

~ e e ~

UNIT SI IU fl)OWNS ANI) PONtER REI)UGTIONS I)0(.hET NO. 50-259 UNIT NAME Browns Ferr 1 I)ATE COhI PI.ETEI) It Y Don Green IICPORThlONTll~<<> <L<C 205 729 6846 TELI I'IIOIVI!

Ir, II

~ rh n I Iee)lsee ~ l)~ ( ause i%. ( >>I feel>ve Vlh. I).It>>

CI CI o Evenl Act>on lo CI II) Rcporl -" w'G o I reveal lb.l.uffI,nu.

140 800809 B Deratcd for recirculation pump HG set brush replacement 141 800818 B Derated for maintenance to control rod 18-39 142 800822 H Derated for control rod pattern adjustment I': Forced Rcasorl: hlcthod: Exhibit G - Instr<<>>lions S: Scheduled A.l'.Iluipmenl Failure (Explain) I.hlanual for Pf>>paration ot l)ata B.hlaintcnance or Test 2.hIa nual Sera ln. I'.ntry She>>ls I'or l.ice>)s>>c C.Refueling 3 Anion):Ilic Scram. I:v>>ni Report (I.I!RI I'il>> (NURIYI Ih' I) Retlulalory Restriction ~ I.Other (I)xplain)

~

016) I I I I'. Operator Training &. License Exantination J'

E-Administrative 5 I

(;.Operational Iilr(>r (Iixplain) lixhibit I ~

Sa)n>> Soul>>>>

l )/77) I I. 0 I h c I ( Iix pl a hl )

~~

UNIT SIIUTI)OWNS ANI) POWER REI)UCTIONS l)OCKET NO. 50-260 UNIT NAhlE Browns Ferr 2 l)ATE ust COhll'I.ETEI) BY Don Green REPORT hlON'Ill Au TELEI'IIONE 205 729 6846 fervent c.

CI Cr

~ ll I.lccosce t cr cr o Cause &< ('orrcclivc N>>. I)Jle Acl>oo I>>

Rcporl + '

I feveol Recurrence 152 800804 H crated due to loss of plant preferred power 153 800805 H Derated for control rod pattern adjustment 154 800816 F 14 27 G Personnel error while performing SI 4.2.A-8 I

I.: I'orced Reason: hlethod: Iixhibit G - instructions S: Schedule<I A.l)<luipmcnt Failure (Explain) .hl an u J I I I'or Pr>>par:Itioo ol')ata B hlaintcnancc or Test 2 hlanual Scra<n. Entry Sl>>>cts tor L<c>>os>>e C.Rct'uelh>g 3-Auto>oalic Scrao>. I veo> Report ( LI!R) I'il>> (NURI!G-I) RegulJlory Rcslr<>>lion 4 Other (I)xplalo) 0I 6) I )

I!.Operat<>r Training &: Liccnsc Examination I -Adouo<sl<JI<vc (r'.Operational Error (I!xplain) Exhibil I -Sa<ne S>>uree

()/77) I I.Other (L'xplaio)

VNITSIIV1 l)OWNS ANI) POWER HEI)VCTIOiVS l)OCyET No. 50-296 Browns Ferr 3 I)AgE 9-1-80 t ('Ohfp(.ETEI) lty Don Green REPORT MON fit ~Au us ss O

J I.iccoscc CS CP ( ols> 8. ( I>flc.>.tl'LE.

N>>. l).>fc IY Event Acti>>n lc>

I/) Rcport > Cj>'

I fCVCOI Recur lf.'nc>s 139 800801 Derated for oB" recirculation pump brush replacement and control rod pattern adjustment 140 800809 H Derated for control rod sequence exchange from oB" to oAo 141 800816 Derated for control rod pattern adjustment 142 800822 B Derated for oBo condensate booster pump maintenance s i 3

I': Forced Reason: Method: Exhibit G ~ Instructions S: Schcdolcd A-Equipmcnt Failure (ExplJin) I -hlaoual fc)r Preparation ot f)ata Bhiai<<tcnancc oi Test 2 hlanual Scram. I:fIffy Sheets tof l.iccnscc

('efueling 3.Autofn:Itic Scram. Event Rcpoft (I.ER) I'ilc (N(IREG.

~ ~

1).Regulatory Rest I iclion 4.Other (lixplaio) OI 6> I )

I'..OpcfJlof TIJ)ning &. IJccnsc ExJnllnJIII)n I -Adfnioistrativc (s.Opcratf>n)JI Lrror (I:xpla)n) (exhibit I - S;>>nc Source

(')/77) II Other (I:xplaio)

, 'L

~

~ C E

llllo'.IIIS 'l!IIIH 'IUCtl il, tta;IT UIIXT t t:.",.",(: I;rPII I II!:.III. I r.!XTI<XCAI. IIAXIITE;IAIICCSu! IIIAIn I'or tlie TIonth o f Aiigiist: 19 80 D,". te t Component lla tu re o f R act anna Operation of a

Cause of Result" of Action Taken To Preclude Sy c<.".

Maintenance Tha Ra.".eton Haltunctton ~nial func t ion R"currence 8/10/6') I'nmary Contain-L'Cv-64-5 Refueling zone air supply None I,imit swit:ch out Incorrect.po'sition of adjustment indicaLion Adji)sted I tlits and limir swi t:

1 tmt Ls ille ll outboard iso- operating l>roperly lation damper- cliecl<ed ol'ay.

getting open- TI( II178101 closed indica-tion (red-gree light) ~

8/19/80 CIID CIA Module 18-39 One of the scram solenoid None Bad Coil Solenoid valve Replaced coil-dropping out. c!iecked ol'ay.

valves on CRD Tlt I/178146 module 18-39 is intermitt-ently dropping out.

l8/19/80 CRD 1B'RD pump None Breaker linkage Breaker was trip- Adjusted trip free linkage - works I

breaker needs out of adjustment froe adjusting. properly now.

'I'R //170696 t 8/ 14 /80 RIIR 1A RIIR pump 1A RIIR pump None verload trip ~

lA RIIR area cooler. Adjust.ed over I area cooler area cooler fai rating was set inoperable causing t:o correct set ing was found trip t:oo low lA RIIR pump to be clieck okay.

ped on thermal considered Nnoperabl .I'R l/129327, 1706i99, overload. per the Teclinical and 181,723 Specifications. I.I':R No, BI:RO-50-25',t 8061

BVOTBV PJ!itVT 'lVCLE/,ll PL~VT VHIT EII'-CTR'ICAI lfAIllTE1fAflCE SUHffARY fP ect on ha e Action Taken D;. te System Component ffat:ure of Of>eration of Cause of Ifesults of To I'r ec iud e Haintenance 'i'he Reactor Halfunction ifalfunction Recurrence I 8/24/RD Primary 16A-K20 relay 1<eplaced relay Hone Coil open Stopped drywell flon Replaced cui.l.-

Contain- 36A-K20 panel (lrain sump pump cllecl(e(l ol(ay ~

ment 9-43 drywell 'f'l 81S0427 FD sump pump breaker inter-lock with valv

EEO!'HS",l;El;Y UUCCEA!: l'LAST Ul!XT

( Sll( I:OIJI Pl II IIT EL!'-CTRICAI. HAIII'1'BIAIICE SUIIIIARY Jtt Effect on Sn n Action Taken I);. tc System Component Nature of Operation of Cause of Results of To Preclude Haintenance The Reactor Halfunction ~>!alfunction R"currence 8/30 jf)0 I',IIR 3A IGIR Room 3A RIIR Room None Bad overload 3A RIIR area Cooler Installed nm~ relay Cooler fan relay inoperable causing checl'ed okay.

4xO ACB therma. 3A RIIR pump to be 'I'l /I l,78898 overloads trip considered inoperabl I.ER No. IIFI(0-50-296'034 ping per the Technical ecifications.

8/25/80 RCIC Hagnetic Pi,ck Repair connec- None Plug pulled off

~S No speed signal to Replaced connect>>r.

~ '

up for speed tor for mag- EGH @hie)i made RCIC Operations to test-signal to netic pickup inoperable. checI<ed oltay EGI! 'I'l 8148297 LER No. IIFR0-50-29(>,

8832

C!'~!'C 8 llfr:Ir8:T HECIIAIIICAL HAIN1'E NANCE SU?" fARY For the Noeth of cutout 19 80 EFFECT C:I SAFE A:;Ti.o."t i"t!:r.tI OPERATION OF CAUSE OF PESULTS GF 'IQ I'RECLUSE DATE SYSTEII CGHPOa~EI IT NATURE OF HAINTE'll4? ICE TIIE REACTOR K'tLFIJNCTION HALFU:ICTIO'I R (.(fI?RE.h.~E 8/6/80 RB( CIJ Pump lB Excessive None Bad seal Leakage Replaced seal leakage TR 181030 8 8/80 Diesel Diesel No. 2 air comp. None Blown head gasket Blown head gasket Changed head gasltt!

Generator Generator D suction relief TR 177910 lifts contin-uously 8/21/8( IIPCI FCV-1-73-6B Leaking valve None Packing leak Leaking valve Tightened packing TR 103499 8/19/8( CRD CRD Hodule Scram pilot None Pinhole in diaphr gm Replaced both 18-39 valve is ex- on pressure side I.caking valve diaphragm solenoid hausting inter- of valve base, subassembly :

mittently all o-rings

-TR 153460

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2 CSSC FX~UI "lEUT IIECIL'NlCAL KKIHTEI ENCE SUYIARY For the Iionth of August 19 80 EFFFCT ON SAI:F.

L"~ IE SYSTEIf CGHPONEIIT NATURE OF OI'ERATIGti CAUSE OF HESUL1'S OP 'IQ I':"J:.,LLZ'.

OI'I" PAINTElIANCE t!F. Rl'.ACTOR H:I.FUNCTION HALFUIICTION PECURRF'iCE 8/1/80 CRI) CRD Nodule Leaking valve None Scram outlet valv Leaking valve Lengthened valve 30-51 Ieaking through stem TR 1534I>8 8/12/80 lll'CI Inboard ruptur Rupture disk is None Rupture disk seal IIPCI isolated Replaced disk disk leaking is leaking TR 103659

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3 CS."0 FXlIJ II'alii.'T FIECIb',IJICAL HA IN'ANCE SURLY.RY For rbo Hoorh of ~Au uur 1980 EFFECT 0 I SAFE AC I. IO.I D.'~ TE SYSTE11 CrJadPO~rer.IIT NATURE OF OPERATIG:x OF CAUSE OF RESULTS GF IQ I:RECLUD;-:

HAIIITHIIANCE TIIE REACTOR V~ LF U:iCTTON IQ LFUNCTIGN r'.FCURKi!ir.":

8/21/80 lligh Drain valve Leaking valve None Leaking valve Leaking valve Tightened valve Pressure 3-26-87 TR 170192 I'Ire Pro-tectioll

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Common CSSC EQUIP:IEI!T I'IECIIANICAL I'fAIIi'-ENHANCE SUI'IiARY For tl>e Hontl> of August 19 80 EFFECT Oi'i SAFE 0 ~

Q SYSTElf CGI1POIiEHT NATURE OF OPERATION OF SE OF RESULTS GF 'IO i'l!=.0: I.r3.":

E'.IhTENANCE TIIE REACTOR K'MALFUNCTION I ALFU:!CTXON RECURRENCE 8/13/8( RIIRSW Fump Cl Bad leak on bal None Gasket tom Tom gasket trap vent up on Replaced ball tral baal trap gasket TR 170372

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BROGANS FERRY NUCLEAR PIaQlT UNIT INSTRUlKNT MAINTENANCE SUlQfARY CSSC E, UIPMENT FOQ THE MONTH OF August 19 8O NATURE EFFECT ON SAFE CAUSE ACTION TAKEN DATE SYSTEM COMPONENT OF OPERATION OF OF RESULTS OF TO PRECLUDE MAINTENANCE THE REACTOR MALFUNCTION MALFUNCTION RECURRENCE Unit 1 8-4 Containment FT-76-16 Calibrate None Zero Drift Indicated Flow with None 1>>r rting System Off Unit 2 8-13 Primary PdT-64-138 Calibrate None Zero Drift Indication Did None Containment Not Agree with Re-dundant Indicator Unit 3 8-5 P rimary Pdic-64-2 Repair None Pneumatic Motor Reactor Zone Damper None Cont ainmen t Leak Not Functioning Properly

28 OUTAGE Sl&&fARY August 1980 During the past month preparation for the Unit 2 cycle 3 outage have progressed on schedule. Numerous pre-outage work items have'been completed.

Work continued on the modification program including the Hypochlorite facility, the LLRW Facility, Outage Fabrication Facility, and the moving of the East Portal. Work was started on the generator breaker modification and prefab-rication of piping for use during the upcoming outage.

The work schedule for the Unit 2 EOC 3 outage was finalized during this reporting period. Plant sections have provided their anticipated work schedule which has been included in the 'total outage schedule.