ML20077H792

Monthly Operating Repts for June 1983

ML20077H792
Person / Time
Site:	Browns Ferry
Issue date:	07/01/1983
From:	Coffey J, Pittman J TENNESSEE VALLEY AUTHORITY
To:	NRC OFFICE OF RESOURCE MANAGEMENT (ORM)
References
NUDOCS 8308110308
Download: ML20077H792 (51)

Text

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r TENNESSEE VALLEY AUTHORITY DIVISION OF NUCLEAR POWER BROWNS FERRY NUCLEAR PLANT MONTHLY OPERATING REPORT TO NRC June 1, 1983 - June 30, 1983 DOCKET NUMBERS 50-259, 50-260, AND 50-296 LICENSE NUMBERS DPR-33, DPR-52, AND DPR-68 Submitted by:

• PlantSuperintendent

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- s TABLE OF CONTENTS Operations Summary......

1 Refueling Information....................

3 Significant Operational Instructions..

5 Average Daily Unit Power Level....

13 Operating Data Reports..........'..........

16 Unit Shutdowns and Power Reductions.

19 Pla nt Mai nt e na nce......................

22 Field Services Summary..

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1 Ooerations Sna==ry June 1983 The following summary describes the significant operation activities during the reporting period.

In support of this summary, a chronological log of significant events is included in this report.

There were 15 reportable occurrences and six revisions to previous report-able occurrences reported to the NRC during the month of June.

Unit 1 The unit was in cold shutdown the entire month for the units' end-of-cycle 5 refueling outage.

Unit 2 There were no scrams on the unit during the month.

Unit 9 There were no scrams on the unit during the month.

Principally prepared by B. L. Porter.

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2 ODerations Summary (Continued)

June 1983 Fatinue Usane Evaluation The cumulative usage factors for the reactor vessel are as follows:

Location Usane Factor Unit 1 Unit 2 Unit 9 Shell at water line 0.00583 0.00465 0.00397 Feedwater nozzle 0.28294 0.19834 0.15111 Closure studs 0.22349 0.16837 0.12839 NOTE:

This accumulated monthly information satisfies Technical Specification Section 6.6. A.17.B(3) reporting requirements.

Common System Approximately 1.00E+06 gallons of waste liquids were discharged containing approximately 2.88E-01 curies of activities.

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Ooerations Su==any (Continued)

June 1983 Refueling Information Unit 1 Unit 1 began its fifth refueling outage oa April 16, 1983 The sched-uled restart date is October 7, 1983 This refueling will involve loading 8X8R (retrofit) fuel assemblies into the core, finishing the torus modifica-

tion, turbine inspection, finishing THI-2 modifications, post-accident sampling facility tie-ins, core spray changeout, and changeout of jet pump

' hold-down beams.

There are O fuel assemblies in the reactor vessel.

The spent fuel stor-I l

age pool presently contains 216 new fuel assemblies, 764 EOC-5 fuel assem-blies, 260 E0C-4 fuel assemblies; 232 E00-3 fuel assemblies; 156 EOC-2 fuel assemblies; and 168 EOC-1 fuel assemblies.

The present capacity is 2,418 i

i locations.

Modification work and testing are in progress to increase the spent fuel pool capacity to 3.471 locations.

2 Unit 2 Unit 2 is scheduled for its fif th refueling beginning on or about June 8, 1984 with a scheduled restart date of November 8, 1984. This refueling outage will involve loading additional 8X8R (retrofit) fuel assemblies into the core, 4

finishing the torus modification, turbine inspection, finishing inspection, finishing TMI-2 modifications; post-accident sampling facility tie-ins, core spray change-out, and feedwater sparger inspection.

There are 764 fuel assemblies in the reactor vessel.

At the end of the

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month there were 248 EOC-4 fuel assemblies, 353 E0C-3 fuel assemblies, 156 EOC-2 fuel assemblies, and 132 E0C-1 fuel assemblies in the spent fuel storage pool. The present available capacity of the spent fuel pool is 861 locations.

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Operations Sn=marv (Continued)

June 1983 Unit ~4 Unit 3 is scheduled for its fifth refueling on or about November 11, 1983, with a scheduled restart date of May 4, 1984.

This refueling will involve loading 8X8R (retrofit) assemblies into the core, finishing the torus modifications, post-accident sampling facility tie-in, core spray change-out, finishing TMI-2 modifications, turbine inspection, and change-out of jet pump hold-down beams.

There are 764 fuel assemblies presently in the reactor vessel. There are 280 EOC-4 fuel assemblies, 124 EOC-3 fuel assemblies, 144 EOC-2 fuel assem-i blies, and 208 EOC-1 fuel assemblies in the spent fuel storage pool.

The present available capacity of the spent fuel pool is 993 locations.

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Significant Operational Events Date Time Event Unit 1 6/01 0001 End of cycle 5 refuel outage continues.

6/30 2400 End of cycle 5 refuel outage continues.

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6 Sinnificant Ooerational Events Date Time Event Unit 2 i

6/01 0001

- Reactor in cold shutdown for maintenance on air leak on main steam isolation valve (MSIV) 1-37 0230 Commenced rod withdrawal for startup.

0450 Reactor Critical No. 151.

0750 Stopped withdrawing control rods due to inability to run "A" recirculation pump.

1240 Commenced controlled shutdown of reactor by inserting control rods.

1412 All control rods inserted.

6/02 0600 Reactor in cold shutdown to investigate problem with "A" recirculation pump.

6/03 0030 Maintenance and startup testing of "A" recirculation

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pump complete, commenced rod withdrawal for startup.

0150 Reactor Critical No. 152.

0945 Rolled turbine-generator.

1022 Synchronized generator, commenced power ascension.

6/04 1600 Stopped power ascension at 66% for R factor calibration.

1900 Commenced power ascension from 66% thermal power.

1919 Stopped power ascension at 73% thermal power, for SI 4.1.B-2 ( APRM gain.)

1 2000 Commenced power ascension from 72%' thermal power.

2010 Stopped power ascension at 75% for SI 4 3.B.1.a (Control Rod Coupling Integrity.)

2230 SI 4 3.B.1.a complete, holding for SI 4.3.A.2.d (Control Rod Accumulator Operability.)

6/05 0100 SI 4 3. A.2.d complete, reactor power at 74% for SI l

4.2.C-1 (APRM.)

l 0215 Commenced power ascension from 74% thermal power.

0500 Commenced PCIOMR from 88% thermal power.

2000 Reactor thermal power at 985, maximum flow rod limited.

2300 Reactor thermal power at 97%, maximum flow, rod limited.

6/ 06 0700 Reactor thermal power at 955, maximum flow, rod limited.

1500 Reactor thermal power at 945, maximum flow, rod limited.

2300 Reactor thermal power at 935, maximum flow, rod limited.

l 6/07 2235 Commenced reducing thermal power for control rod pattern t

adjustment.

2358 Reactor thermal power at 68% for control rod pattern adjustment.

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l 6/08 0015 Commenced withdrawing control rods for control ~ rod l

pattern adjustment.

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0700 Commenced PCIOMR from 86% thermal power.

2000 Reactor thermal power at 995, maximum flow, rod limited.

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Unit 2 (Continued) 6/09 0700 Reactor thermal power at 985, maximum flow, rod limited.

1000 Reactor thermal power at 995, maximum flow, rod limited.

2200 Commenced reducing thermal power for a controlled shutdown to spare out main transformer for maintenance.

6/10 0242 Generator offline at 24% thermal power.

0330 Stopped reducing thermal power at 15%.

1550 Commenced withdrawing control rods for startup.

0535 Rolled turbine-generator.

6/11 0502 Synchronized generator, commenced power ascension from 23% thermal power.

1400 Commenced PCIOMR from 775 thermal power.

6/12 2030 Reactor thermal power at 935, maximum flow, rod limited.

6/13 0700 Reactor thermal power at 91%, maximum flow, rod limited.

2200 Commenced reducing thermal power from 90% for control rod pattern adjustment.

2350 Commenced reducing thermal power from 72% shutdown due to failure to prove operability of "A" and "C" standby gas treatment (SBGT) trains.

2400 SI 4 7.B.1 SBGT operability complete; stopped reducing thermal power at 70%.

6/14 0001 Holding reactor power at 70% due to problems with control rod 50-27 0600 Maintenance and testing complete on control rod 50-27, commenced power ascension.

0735 Commenced PCIOMR from 87% thermal power.

2015 Reducing thermal power from 98% due ta core limits.

6/15 0400 Reactor power at 935 due to core limits.

0625 Commenced PCIOMR from 93% thermal power.

1640 Reactor thermal power at 975, maximum flow, rod limited.

6/18 2140 Commenced reducing thermal power for control rod pattern adjustment.

2300 Reactor thermal power at 72% for control rod pattern adjustment.

6/19 0130 Control rod pattern adjustment complete, commenced power ascension.

0700 Commenced PCIOMR from 84% thermal power.

1130 Stopped PCIOMR at 88% thermal power. Computer out of service.

1530 Commenced PCIOMR from 88% thermal power.

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Unit 2 (Continued) 6/20 0135 Reactor thermal power at 97%, computer out of service.

1500 Reactor thermal power at 965, computer limited.

2230 Computer back in service, commenced PCIOMR.

2300 Reactor thermal power at 100%, maximum flow, rod limited.

6/21 2301 Commenced reducing thermal power, R factor out-of-limits.

6/22 0035 Reactor thermal power at 865, R factor out-of-limits.

0110 R factor in limits, commenced power ascension.

0900 Commenced PCIOMR from 935 thermal power.

1400 Reactor thermal power at 995, maximum flow, rod limited.

6/23 0800 Commenced reducing thermal power for recoval of *B" string high-pressure heaters from service for maintenance.

0910 Reactor power at 83%, "B" string high-pressure heaters out-of service, increasing thermal power.

1400 Reactor thermal power at 895, "B" string high-pressure heaters limited, decreasing thermal power.

1500 Reactor thermal power at 87%, "B" string high-pressure heaters limited.

6/24 0120 "B" string high-pressure heaters in service, commenced power ascension.

0230 Commenced PCIOMR from 90% thermal power.

1230 Reactor thermal power at 995, maximum flow, red limited.

2240 Commenced reducing thermal power for removal of "A" reactor feedwater pump from service for maintenance.

l 6/25 0010 Reactor thermal power at 72%, "A" reactor feedwater pump l

out-of-service for maintenance.

0155 "A" reactor feedwater pump in service, commenced power ascension.

0915 Commenced reducing thermal power from 985 to maintain flow limits.

1000 Reactor thermal power at 97% maximur. flow, rod limited.

1800 Reactor thermal power at 96%, due to high backpressure when unit was placed on cooling towers.

1955 Commenced reducing thermal power due to high river i

temperature.

2200 Reactor power at 78% due to high river temperature.

2255 Commenced power ascension from 785.

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9 Sinnificant Ooerational Events Date Time Event Unit 2 (Continued) 6/26 0001 Commenced PCIOMR from 89% thermal power.

0600 Reactor power at 985, maximum flow, rod limited.

1638 "C" condensate pump tripped on motor overload, commenced reducing thermal power.

2100 Reactor thermal power at 81%,

"C" condensate pump out-of-service, increasing thermal power.

6/27 1843 "C" condensate pump in service, commenced power ascension from 845 thermal power.

1905 Commenced PCIOMR from 89% thermal power.

6/28 0845 Reactor thermal power at 99%, maximum flow, rod limited.

1000 Reactor thermal power at 985, maximum flow, rod limited.

6/29 0200 Reactor thermal power at 97%, maximum flow, rod limited.

6/30 0700 Reactor thermal power at 98%, maximum flow, rod limited.

2400 Reactor thermal power at 98%, maximum flow, rod limited.

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10 Sinnificant ODerational Events Date Time Event Unit 3 6/01 0001 Reactor thermal power at 735, increasing power for control rod pattern adjustment.

0130 Commenced PCIOMR from 77% thermal power.

0935 Commenced reducing thermal power from 85% for removal of bus duct cooling fan from service for maintenance.

1007 Reactor thermal power at 62%, holding for maintenance on bus duct cooling fan.

1045 Bus duct cooling fan back in service, commenced power ascension.

1400 Commenced PCIOMR from 81% thermal power.

6/02 1400 Stopped PCIOMR at 905 thermal power for TIP machine run.

1600 Commenced PCIOMR from 90% thermal power.

f/03 0610 Reactor thermal power at 100%, maximum flow, rod limited.

1200 Reactor thermal power at 995, maximum flow, rod limited.

1500 Reactor thermal power at 1005, maximum flow, rod limited.

2300 Reactor thermal power at 99%, maximum flow, rod limited.

6/04 0700 Reactor thermal power at 100%, maximum flow, rod limited.

2340 Commenced reducing thermal power for removal of "C" j

reactor feedwatcc pump from service for maintenance.

6/05 0136 "C" reactor feedwater pump out-of-service for maintenance, reducing thermal power.

0400 Reactor thermal power at 69% for maintenance on "C"

reactor feedwater pump.

1000 Reactor thermal power at 70% for maintenance on "C" reactor feedwater pump, increasing power.

1610 "C" reactor feedwater pump back in service, reactor power at 72%, holding for maintenance on "B" reactor feedwater pump A.O.P. relief valves.

I 1750 Maintenance complete on "B" reactor feedwater pump, A.O.P. relief valves, commenced power ascension.

1925 Commenced PCIOMR from 955 thermal power.

6/ 06 0040 Reduced thermal power from 99% to 97% to get off of rod blocks.

0140 Commenced PCIOMR from 975 thermal power.

0740 Reactor thermal power at 100%, maximum flow, rod limited.

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Date Time Event Unit 3 (Continued) 6/06 1034 Received 1/4 isolation on "D" main ateam line low-pressure reducing thermal power for SI 4.2.A-6 (Low-Pressure MSL 1/4 Isolation), and SI 4.2.F-18 (MSLRV Thermocouple Temp. and Acoustic Flow Monitor.)

1230 Reactor thermal power at 99% for SI 4.2.A-6 and SI 4.2.F-18.

1410 SI 4.2.A-6 and SI 4.2.F-18 complete, holding for SI 4.1.A-7, XS-3-53 to "A" level control.

1755 While performing SI 4.1. A-7, relay SAK25D dropped out and did not make up when trip signal cleared, reducing thermal power.

2200 Reactor power at 00% for repair of relay SAK25D.

2230 Coil replaced in relay SAK25D, commenced power ascension.

2400 Reactor thermal power at 1005, maximum flow, rod limited.

6/09 1600 Reactor thermal power at 995, maximum flow, rod limited.

6/11 0200 Reactor thermal power at 100%, maximum flow, rod limited.

2320 Commenced reducing thermal pwoer for turbine control valve test and SI's.

6/12 0100 Reactor thermal power at 70% for turbine control valve test and SI's.

0130 Turbine control valve test and SI's complete, commenced power ascension.

0330 Commenced PCIOMR from 81% thermal power.

1800 Reactor thermal power at 100%, maximum flow, rod limited.

6/16 1500 Reactor power at 99%, maximum flow, rod limited.

6/17 2200 Commenced reducing thermal power for control rod pattern adjustment.

2400 Reactor thermal power at 66% for control rod pattern adjustment.

6/18 0050 Increasing thermal power for control rod pattern adjustment.

0635 Control rod pattern adjustment complete, commenced PCIOMR from 79% thermal power.

0830 Reducing thermal power from 82% thermal power for

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12 Significant Ooerational Events Date Time Event Unit 3 (Continued) 0940 Reactor thermal power at 79% for maintenance on control rod 26-35.

1020 Commenced reducing thermal power for control rod pattern adjustment.

1040 Reactor thermal power at 63% for control rod pattern adjustment, increasing power.

1400 Control rod pattern adjustment complete, commenced PCIOMR from 78% thermal power.

6/19 1400 Reactor thermal power at 100%, maximum flow, rod limited.

6/23 1500 Reactor thermal power at 995, maximum flow, rod limited.

6/24 0700 Reactor thermal power at 100%, maximum flow, rod limited.

6/25 1958 Commenced reducing thermal power due to high river temperature.

2200 Reactor thermal power at 81% due to high river temperature.

2250 Commenced power ascension from 81% due to high river temperature.

2350 Reactor thermal power at 915, holding for turbine control valve test and SI's.

6/26 0015 Turbine control valve test and SI's complete, commenced power ascension.

0500 Commenced PCIOMR from 99% thermal power, 0600 Reactor thermal power at 100%, maximum flow, rod i

limited.

6/27 0200 Reactor thermal power at 99%, maximum flow, rod limited.

0800 Reactor thermal power at 100%, maximum flow, rod limited.

1300 Reactor thermal power at 99%, maximum flow, rod limited.

6/30 0700 Reactor thermal power at 985, maximum flow, rod limited.

l 2400 Reactor thermal power at 985, maximum flow, rod limited.

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13 AVERAGE DAILY UNIT POWER LEVEL DOCKET NO.

50-259

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UNIT 1

DATE 7-1-83 CO)IPLETED BY _ T. Thom TELEPHONE.205/729-0834 klONTH June DAY AVERAGE DAILY POWER LEVEL DAY AVER AGE DAILY POWER LEVEL (SfWe Net)

(5fWe-Net) 1

-6

-6 37 2

-6

-6 g3 3

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-6 19 4

-6

-6 20 5

-6

-6 21

-7 6

22

-6

-6

-6 7

23

-6

-6 8

24

-6

-6.

9 25

-8 10 26

-6 11

-6 27

-6

-6 12 28

-6

-6

-6 13 29

-6

-6 14 30

-6 IS 31

-5 16 INSTRUCTIONS On this f orinat,!ist the average daily unit power lesel in slwe. Net for each '1d) '" 'h# P"Itirig snonth. Compute to the nearest whole nwgawait,

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i AVERAGE DAILY UNIT POWER LEVEL i..+

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50-260

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UNIT 2

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7-1-83 DATE COMPLETED f:I.

T. Thom :

205/729-0834 TELEPHONE t

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s DAY AVERAGE DAILY POWER LEVEL DAY AVER AGE DALLY POWERl. EVE L IMWe-Net) g g w e,.Neti

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-13 1R54 37 2

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1023' 259 932

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20 1036 5

957 1074. -

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979 23 972 5

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'1033 25.

964 i 9

945 10 107 26 969 11 395 27 887 s,

12 952

= 23 1038' 13 956 29, 1046 14 929 1037-30 15 1022

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INSTRUCTIONS

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On this format. fist the aser.r.;e daib t. nit power leselin MWe.Nc4 i;,r.each dahin the rerorting monih. Gompu:$ ili -

the nearest whole megawati.

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15 AVER.\\GE 1)AILY UNIT POWER LEVEL DOCKET NO.

50-296 UNIT 3

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'DATE 7-1-83 COMPLETED BY T. Thom TELEPil0NE 205/729-0834 d*

MONTil DAY AVERAGE DAILY POWER LEVEL DAY A\\'ER AGE DAILY POWER LEVEL (MWe-Neu

( M we. Net i I

829 17 1035 2

920 799

,3 3

1052 1013 g9 4

1045 1041 20 5

795 21 1045 1045 1042 6

1031 7

23 1041 s

1051 1071 24 9

1039 25 1001 10 1054 26 1021 11 1046 27 1030 12 959 23 1029 13 1048 1040 29 I4 1053 30 1021 IS 1046

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3, 16 1039 INS TR UC r!ONS On tlus hinnat. !ist the aserage.)..ih una p. we, rese! in uwe. Net hu each day in the repiuting in.inih. c.,inpure to

- the nearest u hole inegaw.itt.

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16 OPERATING DATA REPORT DOCKET NO. 50-259 DATE 7-1-83 COSIPLETED BY T. Thom TELEPflOSE 90s/729-0834 OPERATING STATUS

1. Unit Name: Brcuns Ferry-1 Notes Jur.e 1983

2. Reporting Period:

3. Licensed Thermal Power (MWt):

3293 1152

4. Nameplate Rating (Gross MWe):

1065

5. Design Electrical Rating (Net MWe):

6. Maximum Dependable Capacity (Gross MWe):

1098.4

7. Maximum Dependable Capacity (Net MWe):

1065

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

N/A

9. Power Lesel To Which Restricted,If Any (/ANet MWe):N/A N

10. Reasons For Restrictions. lf Any:

This Month Yr..to Date Cumulative 720 4,343 78,145

11. Ifours In Reporting Period 0

12. Number Of flours Reactor Was Critical 2.363.25 49,752.79

13. Reactor Reserve Shutdown llours 0

47.71 5,785.02

14. flours Generator On-Line 0

2,317.52 48,717.64 0

0

15. Unit Reserve Shutdown llours 0

, 6,784,675 138,557,679

16. Gross Thermal Energy Generated (MWil) 0

17. Gross Electrical Energy Generated (MWil) 0_

2,244,900 45,645,620 0

2,175,548 44,325,327 IS. Net Electrical Energy Generated (MWil)

19. Unit Service Factor 0

53.4 62.5

20. Unit Availability Factor 0

53.4 62.5

21. Unit Capacity Factor (Using MDC Net 1 0

47.0 53.3

22. Unit Capacity Factor (Using DER Net) o 47.0 53.3

23. Unit Forced Outage Rate 0

8.1 23.8

24. Shutdowns Scheduled Oser Next 6 Months (Type. Date.and Duration of Eacht:

s

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

Oct-

7. 1983

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

Forecast Achiesed INITIAL ClllIICALITY INITIAL ELECTRICITY COMMERCI A L OPER ATJON

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17 OPERATING DATA REPORT DOCKET No. 50-260 DATE 7-1-83 COSIPLETED BY T.

Thon TELEPil0SE 205/729-0834 OPERATING STATUS

1. Unit Name:

Browns Ferry-2 Notes

2. Reporting Period:

June

3. Licensed Thermal Power (5tht):

3293 1152

4. Nameplate Rating (Gross 31We):

5. Design Electrical Rating (Net alWe):

1065

6. Stasimum Dependable Capacity (Gross 31We):

1098.4 1065

7. Stasimum Dependable Capacity (Net 31We):

8. If Changes Occur in Capacity Ratings (Items Number 3 Through 7) Since Last Iteport.Give Reasons:

N/A

9. Power Lesel To which Restricted,if Any (Net 31We):

N/A

10. Reasons For Restrictions.lf Any:

N/A This alonth Yr..to.Date Cumulati

11. Ilours in Reporting Period 720 4,343 73.086

12. Number Of flours Heactor Was Critical 679.53 2,366.57 45,660.04

13. Reactor Reserve Shutdown llours 40.47 102.68 13,787.50

14. Ilours Generator On-Line 634.30 2.248.78 44,224.23

15. Unit Rewrve Shutdown llours 0

0 0

16. Gross Thermal Energy Generated (31Wil) 1,911.050 6.428.078_

126.837.925_

17. Gross Electrical Energy Generated (5thil) 624J8_0,.

2.154.260 42.179.168_

18. Net Electrical Energy Generated (.\\lWil) 607.206 2.092.744 40,965,819

19. Unit Service Factnr 88.1 51.8 60.5

20. Unit Asailability Factor 88.1 51.8 60.5

21. Unit Capacitv Factor IUsing SIDC Net) 79.2 45,2 52.6

22. Unit Capacity Factor IUsing DER Net) 79.2 45.2 52.6 l

23. Unit Forced Outage Rate 11.9 8.9 26.4 l

24. Shutdowns Scheduled Oser Nest 6 Slonths1 Type. Date,and Duration of Eacht:

s

25. If Shut Down At End of Report Period. Estimated Date of Startup:

26. Units in Test Status IPrior io Commercial Operation):

Forecast

.Achies ed INITITI. ClllilCA Li TY INITIAL ELECTRICITY CO\\l\\lERCI.\\L Ol'FR A T.10N P3/77 )

18 OPERATING DATA REPORT DOCKET NO.

50-296_

DATE 7-1-83 COMPLETED By T. Thom TELEl;.;.E 205/729-0834 OPERATING STATUS

1. Unit Name:

Browns Ferry-3 Notes June 1983

2. Reporting Period:

3. Licensed Thermal Power (MWt):

3293

4. Nameplate Rating (Gross MWe):

1152

5. Design Electrical Rating (Net MWe):

1065

6. Maximum Dependable Capacity (Gross MWe):

1098.4 1065

7. Masimum Dependable Capacity (Net MWe):

8. If Changes Occur in Capacity Ratings (items Number 3 Through 7) Since Last Report. Give Reaso is:

N/A

9. Power Level T.) Which Restricted,If Any (Net MWe)

N/A

10. Reasons For Restrictions,if Any:

N/A This Month Yr to.Date Cumulative

11. Ilours In Reporting Period 720 4,343 55,511

12. Number O!Ilours Reactor Was Critical 720 3.852.67 41,464.95

13. Resetor Resene Shutdown flours 0

490.33 3,862.48

14. Ilours Gen.:rator On Lir.e 720 3,807.28 40,581.34

15. Unit Reserve Shutdown llour, 0

0 0

16. Gross Thermal Energy Generated (MWil) 2,278,166 12,034,344 121,370,448

17. Gross Electrical Energy Generated (MWil) 745:580_..

3.971.760 40.011_550

18. Net Electrical Energy Generated (MWH) 726.638 3,865,800 38.846.704

19. Unit Senice Factor 100 87.7 73.1

20. Unit Availability Factor 100 87.7 73,1

21. Unit Capacity Factor (Using MDC Net) 94.8 83.6 65.7

22. Unit Capacity Factor iUsing DER Neti 94.8 83.6 65.7 -

23. Unit Forced Ontage Rate 0

12.3 16.9

24. Shutdowns Scheduled Oser Nest 6 Months (Type. Date.and Duration of Each):

s

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

26. Units in Test Status iPrior to Commercial Operation):

Forecast Achiesed t

INITIT L CRITICALITY INITIA L ELEClRI':ITY CO\\l\\lERCIAL OPl?R ATJON

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UNIT SilUTDOWNS AND POWER REDUCTIONS DOCKET NO.

50-259 UNIT NAME Browns Ferry-1 7-1-53 DATE COMPLETED BY T. Thom REPORT MONTil June TELEPl10NE 205/729-0834 "6

re 3 to 0 6

.=5 _e s

7.s 'd 1.icensee g-r, c

Cause & Corrective

$.7.,

-o No.

Date g

gg g

,3 g $

Event u?

3 Action to

$5 j@g Repint e N0

}U Prevent Recurrence 6

264 6/1/83 S

720 C

4 EOC-5 Refuel Outage Continues e"

i 1

~

i 2

3 4

F: Forced Reason:

Method:

Exhibit G. Instructions S: Scheduled A Equipment Failure (Explain) 1-Manual for Preparation of Data B Maintenance of Test 2-Manual Scram.

Entry Sheets for I.icensee 4

i C-Refueling 3 Automatic Scram.

Event Report (l.I:RI File (NURI:G-D-Regulatory Restriction 4-Other ( Explain) 0161)

E-Operator Training & License Examination F-Administ rative 5

G-Operational Error (Explain)

Eshibit I - Same Source 19/77) 11-01her (Explain) 9 9

UNIT SI(UTDOWNS AND POWER REDUCTIONS DOCKET NO.

50-260 UNIT NAME Browns Ferry-2 DATE 7-1-83 REPORT MONTH June COMPLETED BY T. Thom TELEPHONE 205/729-0834

.! ?

"s kY Licensee

,E-r, Cause & Correcthe No.

Date g

3g 4

,3 g 5 Event 3?

93 Action to

$E

s 5 g2 =

Report :

EU 5'

Prevent Recurrence v

6 257 6/1/83 F

58.37 H

2 Reactor in Cold Shutdown for Main-tenance on Air leak on MSIV l-37 and "A" Recirculation pumy.

258 6/7/83 S

H Derated for Control Rod Pattern _ _ _

Adjustment.

259 6/9/83 F

27.33 A

Generator Off Line to Spare out main

?

transformer for Maintenance. No Reactor scram.

c$

260 6/13/83 S

H Derated for Control Rod Pattern Adjustment, SI4.5.B.1 (SBGT Operabil: ty),

Maintenance on Control Rod 50-27 261 6/18/83 S

H Derated for Control Rod Pattern Adjustment.

262 6/24/83 F

B Derated for Maintenance on "A" Reactor Feedwater pump.

'I 2

3 4

F: Forced Reason:

Method:

Exhibit G -Instructions S: Scheduled A Equipment Failure (Explain)

! Abnual for Prepaiation of Data B. Maintenance of Test 2 Manual Scram.

Entry Sheets for 1.ieensee C-Refueling 3-Autom stic Stram.

Event Report (1.ERI File iNUREG-D-Regulatory Restriction 4-Ot her (E xplain) 01611 E-Operator Training & liteme Examination F-Administrati.e 5

G-Operational Eiros (Explain t Exlubit I - Same Source pi/77)

Il-Other (Explain) y

UNIT MlUTDOWNS AND POWER REDUCTIONS DOCKET NO.

50-296 UNIT NA5f E Browns Ferry-3 DATE 7-1-83 REPORT MONTil June COMPLETED BY T.

Thom TELEPff0NE ?ns/7?o-nor, 3?

'h k N')

1.isensee

[-r, h%

Cause & Correctise No.

Dat e c-EE I

iE3 1.sent 3?

F '2 Action to 0'

[ 2[

] j, }

Report :

E0

,50 Prevent Recurreni.e e

v 6

134 6/4/83 F

B Derated for Maintenance on "C" Reactor feedwater pump.

135 6/11/83 S

B Derated for Turbine Control Valve Tests and SI's 136 6/17/83 S

II Derated for Control Rod Pattern Adjustment, to

>=

2 3

4 F: Forced Reason:

M ethod:

Exhibit G. Instructions S: Scheduled A b uipment Failure (Explain)

!-Manual for Preparation of Data l

B. Maintenance of Test 2-Manual Scram.

Entry Sheets for Ixensee C.Refuchng 3-Autom.it ic Scram-Esent Report t LERI File iNUREG-D-Regulatory Restrietion 4 0;her (Esplun1 01611 E Operator Traming & t hense I san:ination F-Administ ra ti.e 5

G-Operational l'irin (E xplaio )

Esinbit I - Same Souiee 69/77)

Il Other iExpbin) f

g,p{ASIL30 3

1 and Common BRO'4;S FF.PEY !!IICLEAR PLA:;T UNIT Er t.

Appendix B

~

CSSC EQUIPMENT ELECTRICAL MAINTENANCE SL?::"ARY

~

9/29/S2 For the Month of June 19 83 l

Effect c: Safe Action Taken Nature of Operation of Cause of Results of To Preclude Dr. : e Systen Component Maintenance

'I be Fenctor Malfunction Malfunctica Eccurrence d4/83 Standby Flow switches While perform-SBGT "B" Train Erratic flow "B" SBGT train was Damper 0-65-503 Gas-for SGT train ing SI 4.7.B.1 inoperabic.

switch operation inoperabic for about was adjusted to Treatment "B",

(McDonnel (SBGT Systera was due to low 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

increase train (SBGT) and Miller Operability air flow and flow within model AF-1 Test) the turbulence at acceptable limits flow switches)L relative hum-the switch. This and to reduce idity control flow switch turbulence in heater failed problem is due order to cause to operate as to the type and positive flow required due location of the switch operation.

to erratic op-flow switches The paddle type cration of the with respect to flow switches on w flow switches, damper location Trains "A" and and position.

"B" are expected j

to be replaced and relocated with more reliable and sensitive differential y

l pressure switches (similar to those installed on "C" Train) by February 15, 1984.

MR #A-148656 g

LER#BFRO-50-259/

83029 e

9 i

EROW S FERRY NUCLEAR PLANT UNIT 1 and Common

1. C Fm 30 Appendi:c B CSSC EQUIPMENT ELi'CTRICAL MAINTENANCE SUBS!ARY 9/29/82 For the Month of June 19 83 Effect on Safe Action Taken Nature of Operation of Cause of Results of To Preclude Da e System Component

!!a i n t enanc e The Reactor Malfunction Malfunction Recurrence

i/7/83 High-IIPCI inverter Inverter was None, unit 1 Undertermined HPCI inoperable.

Tightened two Pressure located in blowing fuses, was in refuel-loose connections Coolant panel 9-3.

ing outage.

and replaced fuse.

Injection MR #A-148793 (HPCI) i/12/83 Fire Smoke detector A trouble Some of the 16 Loose inter-Power was lost to A fire watch was Protection XS-39-104-BA alarm from smoke detectors-connecting cable some of the 16 smoke established. Two control bay in the battery wires on the detectors in the loose screws on elevation 593 and battery terminal block battery and battery the smoke detec- ;

fire protec-board room of smoke detec-board room areas.

tor terminal i

u tion panel areas were tor XS-39-104-BA.

block were t ighH-l l-25-325 was inoperabic.

observed.

enedwhichrestorj ed power to the smoke detectors and c1 cared the trouble alarm.

MR #A-148797 i

LER#BFRO-50-259/ I 83032 t

0 e

e e

B g

e

BROW';S FERRY ';UCLEAR PLANT UNIT 1 and Common g

3g Appendix B CSSC E0UIPME:T ELECTRICAL MAINTENANCE SU:' MARY j

9/29/82 For the Month of June 19 83 Effect on Safe Action Taken Nature of Operation of Cause of-Results of To Preclude iDe:e System Component Maintenance The Reactor Malfunction Malfunction Recurrence I

fl2/83 Radiation Off-Gas stack Stack monit.or Mone Excessive motor Stack gas monitoring on 6/12/83 the Monitoring monitor pump pump "B" current.

channels inoperable.

"B" pump was "B".

tripped, replaced and the pump returned to service. On j

6/13/83 the stack gas monitoring pump "B" tripped again. The sample l pump and motor wasi' replaced and returned to ser-vice. The "B" $

pump motor was replaced on 6/18/

83 with a motor i

whose load current is less.

MR #A-133433 MR #A-141834 LER!iBFRO-50-259/

83030 l

t

Page 3 BROR:S FFERY NUCLEAR PLANT UNIT 1 and Common BF EMSIL 30 Appendix B CSSC EQUIPMENT ELECTRICAL MAINTENANCE SU:: MARY 9/29/82 For the Month of June 19 83 l

Effect on Safe Action Taken Nature of Operation of Cause of Results of To Preclude Dr. a System Component Maintenance The Reactor Malfunct*cn Malfunction Recurrence

./13/83 Standby Flow switches During the SBGT Train "B" Erratic flow SBGT Train "B" Damper 0-65-503 Cas Treat-for SGT train performance of inoperable.

switch operation inoperable.

was adjusted to ment "B",

SI 4.7.B-2 on due to the type increase train (SBGT)

(McDonnel and SBCT Train "B" and location of flow within Miller model the 40KW rela-the flow switches acceptable limits AF-1 flow tive humidity with respect to using instruments switches).

control heater damper location other than the failed to and position and control room flow operate.

inaccurate con-instrumentation, trol room flow Control room flow instrumentation.

instrumentation will not be uses l to make flow adW justments in the l future without confirmatory instrumentation flow measurements.

The flow switches will be changed to a different type and relocat-ed by 2/15/84.

LER#BFRO-50-259/

83034 0

4

BROtl';S FERRY NUCLEAR PLANT U'!1T 1 and Common g 3 Appendix B

~

QSSC EQUIPMENT ELECTRICAL MAINTE:!ANCE

SUMMARY

9/29/82 For the Month of June 19 83 Effect on Safe Action Taken Nature of Operation of Cause of Results of To l'reclude Daze System Component Maintenance The Reactor Malfunction Malfunction Recurrence

/15/83 Diesel No voltage Received a None NVR relay coil Received a false Replaced the relay Generators relay (NVR) on false " control burned.

alarm " control power per EMI 23 and diesel genera-power off" off" for D/G "B".

EMI 58.

tor "B".

alarm for D/G MR #A-141830 I

"3" on panel MR #A-154238 9-23-7.

/17/83 24 Volt DC 24 volt power L Battery None Battery charger One of the two off-Reset the battery Power supply system charger A2-1 output breaker gas stack monitoring chareer output System battery inoperable.

t. ripped due to channels was made breaker, charged changer A2-1.

loss of I & C inoperable.

batteries per g

bus voltage dur-EMI 4.

e ing outage work MR #A-147123 i

on the I & C I

bus.

/20/83 48 Volt DC 48 volt ann-Electricians None Burned coil in Battery charger "A" The spare battery Power unciator noticed a the battery was inoperable.

charger was placed-System battery charg-smoking coil charger contrac-in service. The er "A".

in the battery tor.

contactor was l

charger.

replaced in bat-l

'tery charger "A" and the charger was returned to service.

MR #A-154007

BROIC S FERRY NUCLEAR PLANT UNIT 1 and Common E!:SIL 30 Appendix B CSSC EQUIP 3ENT ELECTRICAL >Lil*;TENANCE Sl2: MARY

, gjg For the !!anth of June 19 83 Effect en Safe Action Taken Nature of Operation of Cause of Recults of To Preclude Dn:e Svstem Component Maintenance The Reactor Malfunction

!alfuncticn Recurrence 5/22/83 Radiation 1-CAM-90-249 CAM inoperable, None Bad motor switch.

1-CAM-90-249 Replaced the bad Monitoring inoperable.

motor switch and returned the CAM to service.

MR //A-147871

{

5/27/83 Fire Pro-Smoke detector A trouble Some of the 16 Loose inter-Power was lost to A fire watch was tection XS-39-104-BE alarn from smoke detectors-connecting cable some of the 16 smoke established, control bay in the battery wire on the detectors in the Tightened the elevation 593 and battery terminal block battery and battery loose terminal fire protection board room of smoke detec-board room areas, screw which re g I panel 1-25-325 areas were tor 1:S-39-104-BE.

stored power to" I

was observed.

inoperable.

smoke detectors and cleared the trouble alarm.

Maintenance Report A-062718 has been,

I initiated to in-l spect and tighten' '

all wire terminals in this smoke detector loop.

MR (IA-147168 LER/!BFRO-50-259/

83038 a

e f

=

4

3 BRO'.C:S FERRY NUCLEAR PLANT U:;IT 2

1. E$

Br c2!SIL 30 Appendi:c B CSSC EOUIPMENT ELECTRICAL MAINTENANCE SDOiARY 9/29/82 For the ':onth of June 19 83 Effcet on Safe Action Taken Nature of Operation of Cause of Results of To Preclude Dr.:e Svsten Component Maintenance The Reacter Malfunction Malfunction Recurrcnce

'/28/83 Radiation Drywell leak Annunciation Drywell air The sample pump Drywell air sampling The blown fuse was Monitoring detection rad-RA-90-256B sarnpling system for RE-90-256 was system was inoper-replaced and the intion monitor (Drywell Leak was inoperable.

found to be trip-able for approxi-sample pump re-(RE-90-256)

Detection ped due to a mately one hour.

turned to service.

sample pump.

Radiation blown 15 amp Investigation did Monitor Down-supply fuse.

not reveal an scale) was apparent cause for received on the blown fuse.

panel 9-3.

MR #A-148107 LER#BFRO-50-260/

S3029 co

/1/83 Reactor 2A recirc pump When trying to None, unit 2 was Neutral bus Recirc pump 2A The burned' bus Water motor neutral start recirc not in opera-burnt into at inoperable, was replaced with Recircula-bus T5 connec-pump motor 2A tion.

T5 connection to the bus from tion tion to common annunciation common neutral recirc pump 1A.

neutral bus, of no differ-bus.

Loose con-The pump motor was ential pressure nections were successfully test-i (Pds-68-65) found at T4 to ed and returned toi and Incomplete common, T4 leg service.

Starting to motor terminal MR #A-140973 Sequence was and T5 leg to MR #A-130640 received.

motor terminal.

9 i

BROE:S FERRY NL'CI. EAR PLA?'T U: IT 2

E 7g 39 Appendix B CSSC EQUIPMD:T E!.ECTRICAL MAINTENANCE SLMMARY 9/29/S2 For the Month of June 19 83 Effect on Safe Action Taken Nature of Operation of Cauce of Results of To Preclude Date System Component Maintenance The lienctor Malfunction Malfunction Recurrence

-/7/83 Reactor Torus vent 2-FCV-64-34 None Limit switch out-2-FCV-64-34 failed Adjusted the limit Building relief valve closed too of-adjustment.

to meet its required switch.

Ventila-(2-FCV-64-34).

slow.

5 seconds operation.

MR #A-147524 tion

/7/83 Core PSC head tank Broken switch None Natural fatigue.

Broken switch Replaced the Spray pump 2B hand handle.

handle.

broken switch Cooling switch.

handle.

MR #A-154203 a/15/83 High HPCI inverter.

HPCI inverter llPCI inoperable.

Blown inverter llPCI was inoperable The fuse was rec m

j Pressure failure alarm fuse Fl.

for approximately placed and the j

Coolant was received or 55 minutes.

Inverter was i

Injection panel 9-3.

returned to ser-i (HPCI) vice. SI 4.5.E.1.b!

was then success-fully completed and the ilPCI sys-tem returned to service.

MR #A-147536 LER#BFRO-50-260/

83034 O

e e

a

Page 3 BR0!C;S FERRY NUCLEAR Pl. ANT UNIT 2

F EMSIL 30 Appendi:< B CSSC EQUIPMENT ELECTRICAL MAINTENANCE SUME\\RY 9/29/82 For the Month of June 19 83 Effcct on Safe Action Taken Nature of Operation of Cause of Results of To Preclude Daze System Component M:tintenance The Reactor Malfunction Malfunction Re.'urrence

'16/83 Core PSC water head Pump inoper-None The pump motor Pump inoperable.

The A phase motor Spray tank pump 2B able, tripping A phase lead was lead was recon-Cooling feeder circuit out on found to be dis-nected to the (CSC) breaker.

terminal over-connected at the circuit breaker,

loads, circuit breaker.

MR #A-154245 t

W l

O I

O I

e 9

9 a

e k

page 3 DRO'T. S FERRY :R' CLEAR PLA::T U:;IT 3

BF EMSIL 30 Appendix B CSSC EQUIP.':E::T ELECTRICAL MAI::TE::ANCE SU:IMARY 9/29/82 For the Month of June 1983_

Effeet on Safe Action Taken

!;ature of Operation of Cause of Results of To Preclude Dr. : e System Component Maintenance The It eac t o r Mal f t:rct ion Malf t:nc t ion Recurrence

/1/83 Diesel Diesel genera-During a daily None, the auxi-The oil pump Diesel generator was The oil pump motor Generators tor 3EA lube inspection, it liary oil system motor tripped taken out of service was replaced and oil circulating was discovered operates con-due to worn motor for repairs to the the diesel genera-pump motor.

that the lube tinuously and bearings.

oil pump, tor returned to oil circulating upon engine service.

pump mctor had shutdown main-MR #A-147305 tripped off.

tains enginc oil LER#BFRO-50-296/

g temperature and 83033 lubrication for' I

fast startup.

l I

D

/6/83' Reactor Relay 5AK25D While perform-None, this Bad relay coil.

Relay SAK25D was Replaced the re ay Protection in panel 9-17, ingS14.1.A-7l relay'sonly inoperable, coil and S14.1.A-7 System relay SAK25D

! function is to was successfully dropped out annunciate completed.

and did not

" Reactor Vessel MR #A-149972 make up when lLowLevelTrip".

the trip signal'This relay has was cleared.

no effect upon the operation of the system.

i I

em 9

S I

S Y

~

Page 3 T,PO C S TERRY NUCI. EAR PLANT UNIT 3

EF EMSIL 30 Ap;)endix B

~

CSSC EQUIPMENT ELECTRICAL I'AINTENANCE SUIDIARY 9/29/82 For the Month of June 19 83 Effect en Safe Action Taken Nature of Operation of Cause of Results of To Preclude Dare Svstem Conponent Maintennnce The Reactor Malfunction Malfunction Recurrence

/18/83 Control Rod notch over SLM switch was None Dirty switch Switch was incapable Cleaned switch Rod ride SBM not operatin;;

contacts.

of providing rod contacts and lub-Drive switch.

properly.

continuous withdraw.

ricated the switch stem.

The SBN switch operated properly.

MR #A-147345 MR #A-149844

./20/83 Reactor 3-FCV-69-2 During the per* None, redundant The valve motor 3-FCV-69-2 was The valve motor Water formance of valve FCV-69-1 armature winding inoperable.

was replaced and Cleanup SI 4.7.D.b-1, was kept in the failed.

the valve returned valve FCV-69-2 closed position to service.

g would not fully until FCV-69-2 MR #A-141886 close.

was returned to LER#BFR0-50-296/

service.

83035 1

/21/83 Reactor 3A RBCCW pump Excessive None Bad pump motor Excessive motor Replaced the

]

Building

motor, motor noise, bearings.

noise, motor bearings.

Closed MR #A-147350 Cooling Water.

(RBCCW) 4 S

t i

_-E: _ !QU:im.7 1 ;,....c

.. ; C.:

Junt>

'. <. 83 l

! U. ~~,

• R L L E: M i..

.c.- :

i C.c ;,

I

/,C T : C:;

..,.-C.

.2 l

S'.'3 7:C:

CC <mn..

{

{

FI 73.!5 CF l

TO P~.YC'

c. : r,, j,7 c.; c y cp P>. N.T.%3.':c::

i T ;. : 5 n.c v;;<

'.s: : r*:cT:r:

I y.,ir_ y, :r- ; c;;

.I P.I C ';..- -

_U- 0_

-14 65 FM 65-50 Replace None Age Loss of Indication None

-22 65 MIS 65-35 Rapair None Age (Lamp)

Loss of Indication None

-13 90

, RM-90-251 Repair None

-22 90 RM-90-2'49 Repa'ir Age (Iodine Det)

Loss of Record None None Age Loss of Indication None U-2_

t

-l 92 APRM E D.C. Amr Repair

None, Age

' Loss of Indication None

, w

-13 90 RR-90-140 Repair None Age (AMP) w

!" Loss.ofRecord None 3_+ 3__

l

-31 73 TR-73-54 Repair' None

,End of Life Loss of Record

?None

-2 74 TRS-74-80 Repair None End.of Life Loss of Record

• None

-8 64 FI-64-38 Replace None A g e.,

Loss of Indication..

None

-18

.68 TR 68-58 Repair None Age Loss,of Record None

-24 rs4 TI-64-55 Replace None Age Loss of Indication None G

0 f

9 m

r ni,,, rr o,i., s t. i.... :- a u.. t vi l i A

Page 3 of 6

,;rsc t.c!:I PriFN r

• TCi: J:! CAL :'AI::TI";i::C S t"'"A RY For the *: nth of June 19 83

' En CC: 0:; S/IE ACTIO:: TU:EA DATE SYSID!

CO:!PCNiGT

AT!GI: 01' OPE!;A rlO:, OF cal'SE OF RESCl.TS UI' 10 PRECLUDE

't\\ I I:TE" ' !;Ci:,_ '1H E REACTO:',

MAI.FL CTION l'A LFG:CIION U:CUnRE!!CE

'6-9 Diesel "A" A/C on "C" corrective N/A blown gasket N/A replaced gasket Generator D/G MR0 154211 I

6-18 EECW B 6 C north corrective N//s noriaal wear N/A cicaned elements header supply MR# 062158 to D/G

-03 Control IB CB chiller corrective N/A poor welds by N/A welded baffle Bay lleating vendor MR# 133519 6 air conditioning 6-03 Control 1B CB chiller routine N/A N/A N/A

!cleanedtubesonoil Bay lientinn cooler

! & air MR# 060880 m

conditioning e

0 9

=

G e

e e

1

,, s.. 3......,.......

rage o 01 6 s :, r: imf1 P:iEN T "r.f':

' ICAL m.I! TE:'A CE SU:O'ARY

~

For thc Month of

,1une 19 83

~

EFFECf 0:. SAFE ACTION TAKEN

>A TE SYS TEM CO:!PCNE;;T

. \\TititE OF OIT!LiTT.c:: OF cat *SE Cr RESULTS OF TO PRTCLUDE

': Ci: [ ' t!E REACTOR MALFUNCTIO::

Mi TI TE:

'" LFG;CTION RECURRENCE i-14 CRD directional corrective N/A unknown N/A replaced valve control valve MR# 136271 85-40D l

5-22 IIPCI pipe support corrective N/A

' normal wear N/A' '

replaced bolts on hanger #78 hanger MR# 130702 3-17 Core Spray PSC pump routine N/A normal wear N/A cleaned suction filters

>!R# 129102 6-08 Fire star valve corrective N/A unknown N/A reset valves Protection.

0-26-73C MR# 133516 5-13 RCIC TCV-71-6 corrective I/A normal wear N/A tighten packing MR#148151 uw 6-13 Radiation RM 90-250 corrective N/A low oil level N/A added oil

. Monitoring MR# 060370

+

e IL

=

l 1

n:,,... i t.;o.4

..%:.<..s

-*s*-

Page 5 of 6 MEGA'!ICAL lL*.I::TL':3:!CE SU "LiEY

. g,.

r.,u,, g ;..... ;-

For the ::nnth of June 19 83 EFFET:T 0:: 5AFE ACTIO:. TAEEN LITE SYSTDI COMPCNi:NT I:ATtGE OF Ori.1:ATI O:: OF cal'3E OF RESUI.TS Or 10 PRECLUDE

Lii::TE!!AI:CE THE kEACE0il M.'. I.F U':CT IO!!

Mal FI':!CTIO::

RECURRENCE

.i-14 IIPCI PCV 73-43 corrective N/A normal wear N/A cleaned diaphragm and gaskets MR# 133467 I

i-09 Control Bay 3B chiller routine N/A N/A N/A cleaned tubes lleating &

MR# 133415 Air Condi-tioning 16 IIPCI FCV 73-44 corrective N/A N/A N/A tighten packing MR(/ 133529

-16

. ilPCI FCV 73-34 corrective N/A N/A N/A tighten packing MR# 133527 v

5-13 RBCCW D/W A/r at corrective N/A N/A N/A tighten nipple o'

RBCCW connec-MR# 133496 tion Ii O9 liPCI FCV 73-16 corrective N/A packing gland N/A tightened packing nuts loose gland nuts MR# 147682 i-19 CRD CRD Pump "B" corrective N/A normal wear N/A replaced filters MRf! 149848 5-16 IIPCI CKV 73-0603 corrective N/A N/A N/A tightened plug MR# 133478 e

e 9

r stLI.., F i sw +'

..bu.r.Ah I ;.'t.; 1 Vi. A :

Lv uual' Page 6 of 6 a

4 : se: 1:rit'! P 9 ';T

'!ECli/.:!ICAL :nI!! Tera!!CE SUIDIARY 19 83 For t!ic Ilent.h of June EFFL_t 0:; SAFE ACTIO 7 TAl;E?i uTi SYS11:M COMPOI ENT I!ATUiiE OF OPEP.\\ TION OF CAUSE OF RESULTS OF TO PRECLUDE i

MAI::TE;!A::CC ale REACTOR MALFU::CTIC:I MAtre::cyION R!:CIIRRE' CE i-02.lRilRSW air release corrective N/A N/A N/A replaced valve valve on RIIRSU MR# 131011 I

pump B3

.-06 Fire "B"

IIP fit <

corrective N/A normal wear N/A tightened packing Protection pump MR# 147315

>-16 [':AD "A" CAD tank corrective N/A faulty tubing N/A repInced tubing l

MR# 133489 m

N l

I i

I L

1 1

I l

I

38 FIELD SERVICES

SUMMARY

June 1983

\\

Ma_ior Work Areas l

A.

Refuel Floor - During the first week of June, fuel sipping was completed and 16 suspect leakers reteated by General Electric, with final analysis that reconstitution is not required.

Vessel drain down started on June 3 to start decontamination efforts in cavity for installation of service platforms required for jet pump hold down beam change-out.

Control rod drive change-out was completed on June 7 with a final count of 102 versus 100 planned, and was completed ahead of schedule. To the end of the month, activities on the refuel floor included jet pump holddown beam changeout, boral test of unit 1 fuel storage racks and recirculation riser nozzle flushing to reduce radiation levels in support.of ISI work.

B.

Turbine - The May monthly report reported the requirements for blade repair on the 13th stage (turbine end) of both the "A" and "B" low-pressure turbines.

The repair on "A" turbine can be accomplished onsite and currently this repair is underway. The repair of the "B" turbine required the blades to be sent to Schenectady,-New York for portions of the repair.

Prior to shipment to New York (shipped June 21, 1983) the blades had to be sent to Quadrex for additional deconning before they could enter the State of New York.

,,r

~

w "r

39 FIELD SERVICES

SUMMARY

June 1983 Ma.ior Work Areas B.

(Continued)

The schedule that General Electric is working toward for the repair has a receipt onsite (Browns Ferry) of August 15, 1983 The subsequent site repair, reassembly of turbine, coupling, oil flush and generator air test pushes the turbine completion out to two days prior to closing of the breaker. Methods for reducing this time span are being analyzed but the turbine work has become joint critical path with the torus.

The "B" and "D" control valve work continues.

Need inner and outer springs to complete assembly of the "B" valve.

Repairs contiued during June on diaphragms and also the upper and lower horizontal joints for both low-pressure turbines and the RFPT "C".

The bull gear and turbine oil pumo gear is expected to be repaired and back onsite by July 25, 1983 C.

Drywell - ISI work inside the drywell increased dramatically from 29 weld inspections on recirculation system to 91 welds by the end of June. This work is essentially complete for final repair selection with 33 suspect rejects and 58 okay. An additienal 32 welds were inspected on the residual heat removal system (RHR) with 14 suspect rejects and 18 okay. A total of j

30 welds may require repair; contracts for weld repair are being issued.

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FIELD SERVICES

SUMMARY

June 1983 Ma_ior Work Areas C.

(Continued)

Main steam isolation valve (MSIV) work continued throughout the month of June with testing completed during the first week.

Lapping of poppet seats is now complete on A, B, C and D inboards and D outboard, back seat lapping and guide rib welding has started and plug welds on P0242 are complete.

Other activities in the drywell progressed as follows: stubber installation on Yarway column complete, and recirculation system snubbers 80-percent complete, main steam release valve (HSRV) testing and modification at Wyle Lab started Juno 20, and 12 of 13 vacuum breakers are modified and ready for reinstallation.

D.

Electrical / Instrumentation - During the month of June all of the major elecrical/ instrumentation modificatins were in work.

Only five modifications have not been released for work and they are as follows:

P0126 Invertors, P0361/L2079 H 0 Valves, P0590 Control Room Emergency 22 Lights, P0586 Rod Consolidation, and P0600 Recirculation Motor-Generator Set Brushs Holders.

In addition to the modification, all major maintenance items are in work.

A brief status of the modifications and maintenance work is listed below.

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41 FIELD SERVICES

SUMMARY

June 1983 Ma.ior Work Areas D.

(Continued) 1.

Modifications a.

P0399 Long Term Solution to Instrument and Control Bus Problems -

completed all equipment installation and cable pulling with exception of that requiring the "B" bus outage. Made tie-ins on the "A" bus.

b.

PO422 Provide Redundant Class IE Protection at Interface of Non-class IE Power Supplies and the Reactor Protection System -

95-percent complete with this modification.

All cabinets have been set and cables have been pulled.

Awaiting approval of work plan for wiring terminations and the "B" bus outage in order to complete work.

c.

F0533 Torus Temperature Monitoring System - Continued installation of conduit on Elevation 593 reactor building and auxiliary instrument room.

No work has been accomplished on Elevation 519 due to lack of material (16 junction boxes.)

d.

P0322 Drywell Wide-range Pressure Monitors and P0323 Torus Wide-range Level Transmitters - Conduit installation, core drilling and mounting of junction boxes started this month. As of this writing, these modifications are approximately 45-percent complete. These modifications are projected to complete during the month of July.

42 FIELD SERVICES

SUMMARY

June 1983 Ma.ior Work Areas D.

(Continued) e.

P0324 Containment Wide-range Radiation Monitors - This modification started in June with installation of conduit, core drilling and some cable pulls. Material problems have slowed the progress of this modification, primarily junction boxes and material required for panel 92. If material problems can be resolved, this modification is projected to complete in July.

Also design drawings are required to resolve seismic qualifications of panels 9-54/55 (mounting of recorders) and detection mounting brackets and detector location. Need EN DES resolution.

f.

Electrical Material - Material deliveries for the above modifications would not have been adequate to support the outage schedule had we not been able to secure surplus material, primarily conduit and fittings. In addition the sheetmetal craf t was unable to support junction box fabrication due to the sheetmetal scope of work.

2.

Electrical Maintenance a.

Continued recirculation pump motor-generator set maintenance l

after completion of control rod drive changeout. This work is

(

approximately 95-percent complete.

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FIELD SERVICES

SUMMARY

June 1983 Major Work Areas D.

(Continued) b.

Supported the outside electrical work required on the three new buildings under construction.

c.

Continued the electrical support of the torus modification.

d.

Continued to perform the EMI-7 and 71 testing.

EMI-7 has 19 of 60 breakers completed and EMI-71 has 23 of the 48 motors completed.

Started maintenance of the recirculation pump motor "A",and "B" e.

June 29, 1983 E.

Mechanical - Material delivery problems continued to delay prefabrication.

of duct work for diesel generators into second week of June and then was further delayed by defective angle iron and weld rod certification problems. By the end of the month "3A" ducting was complete and "3B" uas 80-percent complete. A test run on "3A" revealed the system ineffective without further modifications, which were started immediately. After modifications, PMT on 3A met all criteria.

Probolog contractor completed turbine oil lube coolers "1A" and "1B", "1A" and "1C" RHR heat exchangers, reactor building closed cooling water (RBCCW) heat exchanger "1C",

recirculation M-G set coolers "1 A" and "1B", reactor feed pump turbine oil coolers "A" and "B", and started "C4" feedwater heater.

44 FIELD SERVICES

SUMMARY

June 1983 Major Work Areas E.

(Continued)

ANI Requirements - P0392 scram discharge header prefabrication and its flush connections on P0538 required ANI-involvement, also P0361 attached piping and nozzle reinforcing, P0613 MSIV guide rib, hold points have been established in work plans. Maintenance items under Section II during the month of June did not require any welding work.

F.

Planning and Scheduling - During the early part of June, the torus internal modification schedule required major changes because of late start on critical pathwork in some bays. The release of bays 4 thru 11 had to be changed to 7 thru 14 in order to get sandblasting and painting started on time without impacting outage end date.

G.

Torus - Throughout the month of June, modification work in bays 7 thru 14 were pushed for completion with the help of several attached piping crews on third shift.

On June 17 bays 8, 9,10, and 11 were released to Williams Paint Contractor and on June 29 bays 7,12,13, and 14.

Sandblasting started the following day. Work in remaining bays 1 thru 5 continued and at the end of June status was as follows:

tie-bars (60-percent,) catwalk (35-percent,) 18" RHR modification (45-percent,) X, Y, Z guasets (60-percent,) thermowells (100-percent,) step removal (75-percent,) vent..

header drain (100-percent,) 24" HPCI modification (45-percent,) SRV restraints (70-percent,) and penetration reinforcing (100-percent.) All i

45 FIELD SERVICES

SUMMARY

June 1983 Ma.ior Work Areas G.

(Continued) modification work outside torus and inside vent headers remained shut down for the entire month. Despite the cancellation of cathodic protection, the torus activities remain critical but the origial torus fill date still is attainable.

Attached piping efforts continued throughout the month and since June 17, 1983 with 50-percent of crews. A total of 89 pipe supports were completed, boosting the total to 219 of 358. By system the following progress was made: HPCI percent; ncIC percent; RHR Loop 1 percent; RHR Loop II percent; CS Loop I percent, and Loop II percent, drywell and torus purge percent; and PSC ringheader percent complete. The total attached piping program is 51-percent complete and remains on a near critical path.

H.

Administrative - The overtime percentage for the month of May was 19-percent with 189,694 straight time hours and 43,637 overtime hours.

As of May 31, 1983, year-to-date overtime percentage was 20-percent, 807,184 straight time hours and 276,583 overtime hours. The overall goal of the overtime percentage is 17-percent.

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FIELD SERVICES

SUMMARY

June 1983 Maior Work Areas H.

(Continued)

The O&M budget for May was $2,671,098 and the expenditures were $3.241,293 with year-to-date budget being $22,156,462 and actual year-to-date expenditures being $21,454,088. The capital budget was $3,149,569 and the expenditures were $5,014,151 with year-to-date budget being $26,511,369 and actual year-to-date expenditures being $15,950,271. Overall budget was

$5,820,667 and the overall expenditures were $8,255,444 with year-to-date budget being $51,667,831 and actual year-to-date expenditures being

$37,404,358.

), Y 4

TENNESSEE VALLEY AUTHORITY

~

Browns Ferry Nuclear Plant P. O. Box 2000 Decatur, Alabama 35602 1

Nuclear Regulatory Commission Office of Management Information and Program Control Washington, DC 20555 Gentlemen:

E.1 closed is the June 1983 Monthly Operating Report to NRC for Browns Ferry Nuclear Plant Units 1, 2, and 3 Very truly yours, TENNESSEE VALLEY AUTHORITY s h.

==

J. A. Coffey Acting Power Plant Superintendent Enclosures oc: Director, Region II Mr. Bill Lavalee Nuclear Regulatory Commission NSAC Office of Inspection and Enforcement P. O. Box 10412 101 Marietta Street Palo Alto, CA 94303 Atlanta, GA 30303 (1 copy)

Director, Office of Inspection and Enforcement Nuclear Regulatory Commission Washington, D. C.

20555 (10 copies)

Mr.. A. Rub'io, Director Electric Power Research Institute P. O. Box 10412 Palo Alto, CA 94304 ZG Aaf f

l An Equal Opportunity Employer

.