ML18025B192

Monthly Operating Rept for Oct 1980

ML18025B192
Person / Time
Site:	Browns Ferry
Issue date:	11/02/1980
From:	Green D, Thom T TENNESSEE VALLEY AUTHORITY
To:
Shared Package
ML18025B191	List: ML18025B190 ML18025B192
References
NUDOCS 8011180594
Download: ML18025B192 (40)

Text

TENNESSEE VALLEY AUTHORITY DIVISION OF POWER PRODUCTION BROWNS FERRY NUCLEAR PLANT MONTHLY OPERATING REPORT October 1, 1980 October 31, 1980 DOCKET NUMBERS 50-259, 50-260, AND 50-296 LICENSE NUMBERS DPR-33, DPR-52, AND DPR-68

/

Submitted By:,

. g

.C+(

Plant Manager 8011 180gfg

TABLE OF CONTENTS Operations Summary Refueling Information Significant Operational Events Average Daily Unit Power Operating Data Reports Level.

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10 13 Unit Shutdowns and Power Reductions.

16 Plant Maintenance

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19 Outage Summary

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0 erations Summa October 1980 V

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 nineteen reportable occurrences and one rev'ision reported to the NRC during the month of October.

Unit 1 There was one scram on the unit during the month.

On October 3, the reactor scrammed when the main turbine tripped due to a false indication of low turbine bearing oil tank level.

Unit 2 The unit was in its EOC-3 refueling outage the entire month.

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

0 erations Summa (Continued)

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

Location Unit 2 Unit 2 Unit 3 Shell at water line Feedwater nozzle Closure studs 0.00491 0.23383 0.-19632 0.00369 0.00314 0.15822 0.11571 0.13193 0.09194 Note:

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

Common S stem Approximately 6.69E+05 gallons of waste liquid were discharged containing approximately 9.26E-Ol curies of activity.

Refuelin Information October 1980 Unit 2 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 assembPies in the reactor vessel.

The spent fuel storage pool presently contains 550 spent 7 x 7 fuel assemblies, five 8 x 8 fuel assemblies,'nd one 8 x 8 R fuel'assembly.

Because of modification

'ork to increase spent fuel pool capacity to 3471 assemblies, present available capacity is limited to 1193 locations.

Unit 2 Unit 2 is presently in its EOC-3 refueling outage.

Unit 2 is scheduled for its fourth refueling beginning on or about March 1, 1982, with a scheduled restart date of June 14, 1982.

This refueling outage will involve completing relief valve modifications, torus modifications if all approvals are received, "A" low pressure turbine inspection, and loading additional 8 x 8 R fuel assemblies into the core.

There are 764 fuel assemblies in the reactor vessel.

At the end of the month, there were 132 discharged cycle 1 fuel assemblies, 156 discharged cycle 2 fuel assemblies, and 352 discharged cycle 3 fuel assemblies in the spent fuel storage pool.

The present available capacity of the spent fuel pool is 160 locations.

Mith present

capacity, the 1979 refueling was the

Refuelin Information (Continued)

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

However, 949 new high density storage racks have been in-

stalled, but cannot be used until Special Test 161 is completed.

Unit 3 Unit, 3 is scheduled for 'its third refueling beginning on or about November 14, 1980, with a scheduled restart date of December 23, 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 8 x 8 R assemblies in the spent fuel storage pool.

The present available storage capacity of the spent fuel pool is 1012 locations.

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 I

core discharge capability in the pool.

Date Time

~fi nifitant 0 eratienal Events Unit 1 Event 10/01/80 0001 0400 0700 1805 10/03/80 1326 1755 2020 2258 Reactor thermal power at 85%, holding for condensate demineralizer problems Condensate demineralizer problems resolved, commenced power ascension (Sequence "B")

Commenced PCIOMR from 95% thermal power Reactor thermal power at >99%, steady state Reactor Scram No.

137 from >99% thermal power on (1) turbine stop valve closure.

Turbine trip on low oil level in main turbine oil tank when level switch was inadvertantly actuated by Instrument Maintenance personnel Commenced rod withdrawal Reactor Critical No.

158 Synchronized generator, commenced power ascension 10/04/80 0530 0930 1130 2135 Reactor thermal power at 80%, holding for "C" string H.P. heaters isolation and maintenance (leaks)

Commenced PCIOMR from 80% thermal power Reactor thermal power at 85%, holding due to "C" string H.P. heaters being out-'f-service "C" string H.P. heaters maintenance complete and heaters placed in service, commenced power ascension.

10/05/80 0700 0930 1630 Reactor thermal power at 90%, holding for condensate de-mineralizers backwash and precoat Condensate demineralizers backwash and precoat complete,'ommenced PCIOMR from 90% thermal power Reactor thermal power at 99%,

maximum flow.

10/09/80 0827 1415 1500 2237 Reduced thermal power from 99% to 80% for removal of "A" reactor feedwater pump from service to fix leaks on minimum flow line Repairs to minimum flow line on "A" reactor feedwater pump completed and pump placed inservice, commenced power ascen-sion Commenced PCIOMR from 90% thermal power Reactor thermal power at 99%,

maximum flow 10/10/80 2230 Reduced thermal power from 99% to 80% for removal of "A" reactor feedwater pump from service for maintenance (leaks) and turbine C.V. tests and SI's 10/11/80 0030 1650 1830 Turbine C. V. tests and SI's completed, holding for "A" reactor feedwater pump maintenance "A" reactor feedwater pump maintenance completed and pump placed in service, commenced power ascension Commenced PCIOMR from 90% thermal power

Si nificant 0 erational Events Unit 1 Date Time Event 10/12/80 0700 10/13/80 1030 1100 1300 1410 1500 Reactor thermal power at 99%,

maximum flow Reduced thermal power from 99% to 70% for control rod pattern adjustment "A" recirculation pump bailey limiter locked out due to a bad amplifier while attempting to increase core flow Commenced power ascension, maintenance on amplifier con-tinues Maintenance to "A" reciruclation pump amplifier complete Reactor thermal at >99%, steady state 10/17/80 2330 10/18/80 0435 0700 Reduced thermal power from >99% to 80% for turbine C.V.

tests and SE's.

Turbine C.V. tests and SI's completed, commenced power ascension Reactor thermal power at 99%,

maximum flow 10/25/80 0330 0452 0700 Reduced thermal power from 99% to 80% for turbine C. V.

tests and SI's Turbine C.V. tests and SE's completed, commenced power ascension Reactor thermal power at 99%,

maximum flow 10/31/80 2400 Reactor thermal power at 99%,

maximum flow

Si nificant 0 erational Events Unit 2 Date Time Event 10/01/80 0001 1242 10/06/80 0530 10/31/80 2400 Reactor at cold shutdown, (EOC 3) refueling outage Fuel shuffle operation completed Core and SFSP verification completed Reactor at cold shutdown, (EOC 3) refueling outage

Si nificant 0 erational Events Unit 3 Date Time Event 10/01/80 0001 1500 10/02/80 1500 Reactor thermal power at >99%, steady state Reactor thermal power at 99%,

maximum flow Reactor thermal power at 98%,

maximum flow 10/04/80 0115 0925 1420 1500 Reduced thermal power from 98% to 70%, for "C" reactor feedwater pump maintenance (leak)

All control rods at notch 48 (fully withdrawn)

"C" reactor feedpump maintenance

complete, commenced power ascension Commenced PCIOMR from 77%.thermal power 10/05/80 2130 10/08/80 0700 10/10/80 2200 Reactor thermal power at 99%, flow limited Reactor thermal power at 98%, coast down Reduced thermal power from 98% to 45% for both recirculation pumps MG set brush replacement 10/11/80 0345 0700 1500 Recirculation pumps MG set brush replacement completed, commenced power ascension Commenced PCIOMR from 95% thermal power Reactor thermal power at 98%, coast down 10/12/80 2300 10/14/80 1500 10/17/80 2120 Reactor thermal power at 97%, coast down Reactor thermal power at 96%, coast down Reduced thermal power from 96% to 50% to replace a

broken brush on 3B recirculatiom MG set 10/18/80 0112 0345 1217 1227

. 1305 3B recirculation pump brush replacement completed, commenced power ascension Commenced PCIOMR from 90% thermal power Reduced thermal power from 98% to 85% due to loss of plant preferred power ("A" recirculation run back)

Plant preferred power restored, commenced power ascension Reactor thermal power at 98%, coast down, achieved 98%

power as a result of Xenon burn-out 10/19/80 0620 0845 1500 Commenced reducing thermal power from 98% for shutdown due to both "A" and "B" flow bias channels inoperable Both "A" and "B" flow bias channels

operable, commenced power ascension from 60% thermal power Reactor thermal power at 95%, coast down 10/21/80 0700 10/22/80 0700 Reactor thermal power at 94%, coast down Reactor thermal power at 93%, coast down

Si nificant 0 erational Events Unit 3 Date Time Event 10/24/80 1500 10/25/80 0120 0315 0700 Reactor thermal power at 92%, coast down Reactor thermal power at 92% to 90% for turbine C.V.

tests and SI's Turbine CD V. tests and SI's completed, commenced power ascension Reactor thermal power at 92%, coast down 10/28/80 2300 10/31/80 2330 2400 Reactor thermal power at 91%, coast down Reduced thermal power from 91% to 80% for turbine C.V.

tests and SI's Reactor thermal power at 80%, holding for turbine C.V.

tests and SI's (1) Personnel error

'I

10 AVERAGE DAILYUNITPOWER LEVEL DOCKET NO.

Browns Ferry - 1 11-2-80 DATE COMPLETED BY dTom TELEPHONE 205-729-6846 October 1980 DAY AVERAGEDAILYPOWER LEVEL (MWe-Net) 1012 DAY AVERAGEDAILYPOWER LEVEL (MWe.iVet) 1048.

17 10 12 13 IS 16 1050 592 763 1002 1044 1061 1057

.,976 1047 886 1045-1046 1055 1053 1055 18 19

.20 21 22 23 24 25 26 27 28 29 30 31 1045 1047 1053 1055 1055 1050 1055 1057 1053 1053.

1058 1059 1054 1053 INSTRUCTIONS On this format, list the average daily unit power level in i~ilVe.>Vet for each day in the repi>rting >n>>nth. Compute to the nearest whole megawatt.

>tCDST to CST on 10/26/80 I<)(77 l

11 AVERAGE DAILYUNITPOWER LEVEL DOCKET NO.

50 260 Br owns Perry 2

DATE 11-2 COMPLETED BY Ted Thorn 205-729-6846 October 1980 DAY AVERAGE DAILYPOWER LEVEL (MWe-Net)

I

<<2 10 12 13 14 IS 16 DAY AVERAGE DAILYPOWER LEVEL (MWe Net)

-5 17 18 19

.20 21 22 23 24 25

'6 27 28 29 30 31 INSTRUCTIONS On this format, list the average daily unit power level in LlltVe Net for each day in the reporting tnonth. Cotnpute to the nearest whole megawatt.

• CDST to CST on 10/26/80 lol77 )

12 AVERAGE DAILYUNITPOWER LEVEL DOCKET NO.

Browns Fer 3

11-2-80 COMPLETED BY Ted Thorn TELEPHONE 205-729-6846 MONTH 'ctober 1980 DAY AVERAGE DAILYPOWER LEVEL (MWe-Net)

DAY AVERAGE DAILYPOWER LEVEL (MWe.Net) 17 10 12 13 14 IS 16 1050 1053 798 996 1062 1065 1063 1057 1018 924 1049

'037 1031 1025 1026 18 19

.20 21 22 23 24 25 26 27 28/

29 30 31 979 940 1019 1011 1001 995 994 999 994 997 986 979 976 978 INSTRUCTIONS On this fortnat.!1st the average daily unit power level in LIIWe.Nct I'or each day in thc reporting tnonth. Crnnpute to the nearest whole megawat t.

• CDST to CST on 10/26/80 P>/771

13 OPERATING STATUS OPERATING DATAREPORT DOCKET NO.

DATE ~2-80 COMPLETED BY TELEPHONE 205-729-6846 I. Unit Name Browns Fer

, 2. Reporting Period:

October 1980

3. Licensed Thermal Power (MWt):

4. Nameplate Rating (Gross MWe):

1152

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:

h This Month Yr:to.Date Cumulative 745 7 320 738.10 5,094.53

~380. 02 4 957.12 6.90 735.47 0

0 14 751 985 2 321 167 778 800 4 775 900 757,925 4,630,063 67.7 98.7 67.7 98.7 59.4

95. 5 59.4 95.5 8.7 1.3 Type, Date. and Duration of Each):

11. Hours ln 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 (MWH)

17. Gross Electrical Energy Generated (MWH)

IS. Net Electrical Energy Generated (M>VH)

19. Unit Service Factor

20. Unit AvailabilityFactor

21. Unit Capacity Factor (Using 4%IDC Net)

22. Unit Capacity Factor (Using DFR Net)

23. Unit Forced Outage Rate

24. Shutdowns Scheduled Over Next 6 Months (

Refue13uta e April, 1981 54 818

,33,371.81 5,069.63 32 569;85 88 888 478 29 294 360 28,432,031 59.4 59.4

48. 7 48.7 30.2

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

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

Forecast Achieved INITIALCRITICALITY INITIAL ELECTRICITY COP@I ERCIAL OPER ATION (ol77)

14 OPERATING DATAREPORT DOCKET NO.

DATE COMPLETED BY ZaxLJ~.

TELEPHONE 205-729-6846 OPERATING STATUS Notes

1. Unit Name Browns Ferrv - 2

2. Reportfng Period:

0<tob~r 1980

3. I.icensed Thermal Power (MWt):

4. Nameplate Rating (Gross MWe):

5. Design Electrical Rating (Net MWe):

6. Maximum Dependable Capacity (Gross MWe):

7 Ia i mDe e dable a acit NetM'IVe:

xmu pn Cp y(

)

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

N/A 4

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

10. Reasons For Restrictions, IfAny:

r

~

This Month Yr.-to-Date 7,320 5,304.11 745

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 (MlVH)

17. Gross Electrical Energy Generated (MWH)

18. Net Electrical Energy Generated (iNVH)

19. Unit Service Factor

20. Unit Availability Factor

21. Unit Capacity Factor (Using MDC Net)

22. Unit Capacity Factor (Using DER Net)

23. Unit Forced Outage Rate

24. Shutdowns Scheduled Over Next 6 Months (Type. D

.0

'48.94 0

5,171.10 0

0 14 929 875 4,952,010 4,807,248 0

0 0

70. 6 0

70. 6 0

61. 7 0

61.7 0

12. 2 0

ate. and Duration of Each):

Cumulative 49,729 29,788.59 12,423.88 28,835.41 0

81 084 875 26,902,078 26,138 717

58. 0

58. 0 49.4 49.4 33.5

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

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

11-7-80 Forecast Achieved INITIALCRITICALITY INITIALELECTRICITY COAIAIERCIALOPERATION

15 OPERATING DATAREPORT OPERATING STATUS I. Unit Name:

Brown's Fer 3

, 2. Reporting period:

October 1980

3. Licensed Thermal Power (MWt): 3293

4. Nameplate Rating (Gross MWe):

1152

5. Design Electrical Rating (Net MWe):

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

7. Maximum Dependable Capacity (Net MWe):

N'otes DOCKET NO. '0-296 DaTE

>>-E-BO COMPLETED BY ~~i eee TELEPHONE ~2-~2-6846

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 MWe):

N/A 10; Reasons For Restrictions, IfAny This Month Yr.-to.Date 7,320 Cumulative 745 32,184 25 421.8 6 514.27 745 1,810.89 24 840:27 152-58 6 402.46 0

745 0

0 0

2,289,631 19,700,810 72 808 676 769,400 6,612,550 748,423 6,429,002 24,015,130 23,316,775 100 87.

77 100 77.2 87.5 94.3 82.5'8.0 94.3 82.5 68.0 0

12.5

10. 0 (Type. Date. and Duration of Each):

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 Ilours

16. Gross Thermal Energy Generated (MWH)

17. Gross Electrical Energy Generated (MWH)

18. Net Electrical Energy Generated (MWH)

19. Unit Service Factor

20. Unit AvailabilityFactor

21. Unit Capacity Factor (Using'MDC Net)

22. Unit Capacity Factor (Using DER Net)

23. Unit Forced Outage Rate

24. Shutdowns Scheduled Over Next 6 Months Refuel Outa e November 1980

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

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

Forecast Acldc'vcd INITlALCRITICALITY-INITIALELECTRIClTY

, COMAIERCIALOPERATION (9/77)

UNITSIIUTDOWNS AND POWER REDUCTIONS REPORT hIONTII DOCKET NO.

UNITNAhIE Browns Ferr 1

COhIPLETED BY No.

Date

~A r>

~An I

Q wJ

~ C/l Licenscc Event Rcport >

O~

c D

O cO 0O Cause 8c Corrective Action to Prevent Recurrence 148 801003 9.53 Turbine trip on low oil-level due to personnel inadvertently checking level switch 149 801009 Derated for maintenance to "A" reacto feedwater pump 150 801010 A

Derated for.maintenance to "A" reacto feedwater pump and turbine C.V. tests and SI's 151 801013 Derated for control rod pa'ttern adjustment 152 801017 Derated for turbine C.V. tests and SX's 153 801025 B

Derated for turbine C. V. tests and I

I F: Forced S: Scheduled (I/>v)

Reason:

A-Equipment Failure (Explain)

B hiaintenance or Test C-Refueling D-Regulatory Restriction E.Operator Training k Liccnsc Examination F.Administ ra t ivc G Operational Error (Explain)

I I.Other (Explain)

Method:

I -hlanual 2.hIanual Scram.

3.Automatic Scram.

4 Other (Explain)

Exhibit G - Instructions for Preparation of Data Entry Sheets for Licensee Event Report (LER) File (NUREG-OI6I)

Exhibit I ~ Sante Source

UNITSIIUTD01'YNS ANDPOWER I(EDUCTIONS REPORT h)ONTII 0 to r

DOCKET NO 50-260 UNITNAhfE Browne Ferr

-2 DATE 11-2-80 TELEPIIONE N<l.

Date ll Cl Ng I

m -cc

~ CA Gl Licenscc Event Report >

E~

Cl Cl lO cn Cr C

Cl 0c Q

U

'O Cause &. Corrective Action to Prevent Rer.urrcnce 155 Cont.

801001 745 C

2 Refueling (EOC-3)

I F

Forced S: Scheduled

('I/77)

Reason:

A Equipment Failure (Explain)

II hlaintenance or Test C.Refueling D Regulatory Restriction E.Operator Training &. Liccnsc Examination F-Administ rat ivc G.Operational Error (Explain)

II Other (Explam) 3 hlethod:

I Manual 2 hianual Scram.

3-Automatic Scram.

4.Other (Explain)

Exhibit G ~ Instructions for Preparation of Data Entry Sheets for Licensee Event Report (LER) File (NUREG.

OI6I)

Exhibit I - Satnc Source

UNITSIIVTDOWNS AND POWER REDUCTIONS REPORT hIONTII October DOCKET NO.

50-296 JL" DATE COMPLETED By Ted Thorn No.

Dale Licensee Event Report C~an OQ D (Q

Cause &, Corrective Action lo Prevent Recurrence 149 801004 A

"C" reactor feedwater pump maintenance (leak) 150 801010 B

Brush replacement for both recirculation pumps MG set 151 801017 B

Replace broken brush on 3B recirculation pump MG set 152 801019 A

"A" and "B" flow bias channels inoperable F: Forced S: Scheduled

<<>/v7)

Reason:

A.Equipment Failure (Explain)

B hlaintenance or Test C'-Refueling D.Ret,ulatory Restriction E.Operator Tfainint; &. Liccnsc Examination F-Administ ra Iivc G Operational Error (Explain)

I I Otltcr (Explain) 3 h(ethod:

I.hlanual 2.hlanual Scram.

3-Automatic Scram.

4-Other (Explain)

Exhibit G - Instrucllons for Preparation of Data Entry Sheels for Licensee Event Rcport (LER) File (NUREG-OI6I )

Exhibit I ~ Same Source

BHQiWS PERltY MUCLEAll PLPilT UNIT~'

ELKCTRXCAL MAXNTENANCE SlMGNY Fo" the Honth of October l9 80 D;.te Syster.

Component Nature of Haintenance E

ect on

'a e Operation of The Reactor Cause of Halfunction Results of

~ifalfunction Actior Taken To Preclude Recurrence 10/'IB1h) c0 st(rage and fire protection Pilot Repair pilot master val.ve master valve Hone Coil burned up Pilot master valve inoperat>ve.

I Replaced coil on pilot master valve,

~

IQ'2 ~

Mhen roil Has..::;

nergized,.valve

.=-

losed and:remained

'osed.

Left val'.ve. in ervice.

TRJ:15~063 0/25/80 High Pressure Coolant Injection System HPCI gland seal hotwell pump motor HPCI gland seal hotwell, ump motor.

(PCI rem'oved from ervice for re-air to motor-for ersonnel

.safety onsiderations.

'ump and'motor flooded HPCI gland 'seal hotwell pump inoperable-Changed pump motor checked rota/ion; performed Ei~lI-33. ~

TR8 189002 I0/26/80 High

'ressure Coolant Injection System EG-R electro-mechanical-hydraulic actuator and EG-H control box o determine vhy EG-H ontrol. box has o output fPCI. inop'erabl e Mire broken arid grounded.on backside'f.

cannon connec-tor in EG-R causing EG-N control to malfunction HPCI inoperable "iechanical Maintenance replaced EG-R, after-ward Electrical 1aintenance replaced EG-t1 control box nd performed cali-bration per ENI 36.

1PCI was tested, found operational and placed in service.

TRIJ 169073 LER Ho. BFRO-50-259/

8079

BROGANS I'EitlVJ Ml/CLEAD PLANT UHZT

~'LECTRICAL MAINTENANCE SRMRY por the Ifonth of October l9 80 Date Syster Component Nature of tlaintenance E

ecton

'a e Operation of The Reactor Cause of lfalfunction Resul ts,'of

~falfunc tion Action Taken To Preclude Recurrence 10/27/89 High Pres-sure In-Jection System HPCI tlagnetic Pickup Connector on IIPCI IIagnetic Pickup broken PCI Inoperable Connector on IIagnetic Pickup was broken during performance of maintenance of EG-R HPCI was not in service due to maintenance on EG-R Replaced connector llagnetic Pickup.

TRP 197602 10/28/8 Iligh Pressure Coolant Injection System IIPCI Gland Seal Pump flotor round receiy-IOIIE d when IIPCI iotwell level larm came in flPCI Gla'Ad Seal Pump motor grounded.

HPCI Gla'nd Seal pump inoperable Replaced HPCI gland seal pump motor.

Checked for proper rbtation and'operation.

perates

properly, erformed EI1I 33.

R8 179797

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~;pO'gS PERI;Y ilUCLHAll PLDNT U1iIT 2

ErrCTRrCAr. mTNTEWuCE Sv~aeRY I'or the lfonth of~~~

19~

Date 10/8/S Syster Control Rod Drive System Component FCV-85-37C Nature of Haintenance Limit switch not working properly 8

ecton 'ae Operation of The Reactor HONE Cause of Halfunction

'imit switch out of adjust-ment Results of

~afalfunction Inabilitg to deter-mine valise position by indicator. liqhts I

Action Taken To Preclude-Recurrence Adjusted limit switch, valve indicator lights are now workin(

properly; TRII 179634 10/9/80 Control Rod Drive System FCV's85-37A and 85-37B C

L'imit switches NONE not operating pjoperly-Limit switches out 6f adjust-

ment, Inability to deter-mine valve position by indicator lights Adjusted limit switch-es, valve indicator lights are now work ing properly.

TRII 181147 1'0/10/80 Primary Contain-ment System Unit 2 R3A Relay SI 4.2.A-16 flOtlE R3A Relay would not meet accep-table criteria as prescribed in SI 4:2.A-16 Time 'delay relay was found out of tolerance and nonrepetitive Replaced R3A. relay and performed SI 4.2.A-16 per instruc-tions on units 1, 2, and 3.

All perform-ing satisfactorily.

TRg 163864 LER No: BFRO-50-26~

80M 10/ll/80 Residual'eat Removal System RHR Pump

~

g RHR pump breaker will not rack full ln lONE Racking screw not properly aligned.

Ground bus gaulded Lined up collar for.

racking screw,-clean-ed and greased ground bus bar.

Breaker racked in.

and functioned properly.

TR8-180470 0/ll/80 Control Rod Drive System FCV-85-llB.

Open and closed HONE indicator lights Limit switch out of adjustment Inability to deter-Adjusted limit switch, mine valve position on FCV-Q5-118, now by indi/ator lights operating properly

TR8 181156

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CSSC E UIPMENT BRO'WHS FERRY NUCLEAR PLANT UNIT INSTRUIIENT MAINTENANCE SUI&IARY FOR 1lIE MONTH OF October 19 80 nit 2 SYSTEM COIIPONENT NATURE OF MAINTENANCE EFFECT ON SAFE OPERATION OF THE REACTOR CAUSE OF MALFUNCTION RESULTS OF MALFUNCTION ACTION TAKEN TO PRECLUDE RECURRENCE 0-23 nit 3 0-20 0-24 High Press ure Coolant Injection Recircula-tion Reactor Core Isol-ation Cool ing Pdis-73-lA FT-68-5A FT-68-5B.

Pdis-71-1B Repair Repair Repair None None None Water in Switch Mater in Trans-mitters Mater in Switch Erroneous High Flow Alarm APRM Flow Bias Alarm False Indication of Steamflow None ECN-1880 To Install Catch Pan ECN-1880 To Install Catch Pan

CSSC EAUIPe~lENT HEClfANICAL MAINTENANCE SUKfARY For tbe i[orth oft October 19 80 SYS TIE<

CCeePONENT NATURE OF M"INTENANCE EFFECT ON SAFE OPERATION OF TffE REACTOR CAUSE OF kfALFUNCTION RESULTS OF MALFUNCTION ACTiON TAKEN TO PRECLUDE RECURRENCE 9/22/8 Diesel "D" D/G enerator Blown head asket None High pressure

- Blown"gasket asket blown Replaced blown head TR 17&482

>KCHANICAL IfAINTENANCE SURGERY 2

Por the Honth of October 19 80 10/15 SYSTEM NPCI CGiiPONENT FCV-73-18 NATURE OF KCINTENANCE Bad valve EFFECT ON SAFE OPERATION OP TltE REACTOR None CAUSE OP YALF UNCTION RESULTS OF

>fALFUNCTION Leaking gasket Leaking gasket ACTIO'i T,'KEN TO PRECLUDE RECURRENCE Replaced gasket an<

refitted pipe to valve TR 176833 lol23 HPCI Valv Valve 73-574 Valve is leak-ing None Bad spring Leaking valve Replaced spring TR 102826 and 179697

3

~CSSC E

UZP.'lrH<T 1KCHANICALMINTENANCE SUMS.RY DATE SYSTEM COiMPOÃENT EFFECT ON SAFE NATURE OF OPERATION OF MAINTENANCE THE REACTOR CAUSE OF MALFUNCTION RESULTS OF MALFUNCTION ACTION TAKEN TO PRECLUDE RECURRENCE

)O/17 CRD LO/10.

Diesel Generator lo/4 HPCI LCV-73-8 FCV-85-37B 3ED D/G Valve will no open Air solenoid leaking air Circulating oil pump lock up None None None Bad o-rings Heat from solenoid caused o-ring to.-becom brittle Pump locked up Render valve inopera Leaking valve Pump would be inoperable le Lubricated stem ani replaced o-ring TR 165496 Replaced o-ri TR 103699 Replaced pump

Common ffEClfANICALMAINTENANCE SUMIfARY For the Month of October 19 80 DATE SYSTEM COMPONENT EFFECT ON SAFE NATURE OF OPERATION OF MAINTENANCE THE REACTOR CAUSE OF MALFUNCTION RESULTS OF kfALFUNCTION ACTION TAKEN TO PRECLUDE RECURRENCE f.o/23 Standby Diesel Generators Lube oil circulating um Bad seal and bearings None Bad seal and bearings Possibly prevent startup of engine Replaced seal and bearings TR 137677

l

30 OUTAGE

SUMMARY

October 1980 I

During this month, the scope of Unit 2, Cycle 3 outage work increased considerably due to many previously unidentified work items requiring major repairs due to non-outage-related repairs.

The ciritcal path to startup was determined to be the LPGA modification work approximately midway through the month, due to extensive maintenance remaining.

Approximately 600 repairs were completed during the month.

Other major work in progress included 2 CLP turbine inspection and assembly, generator breaker installation and testing, H 02 analyzer replacement, primary containment isolation system logic changes, and in-condenser maintenance.