ML18024A850

Monthly Operating Rept for May 1979

ML18024A850
Person / Time
Site:	Browns Ferry
Issue date:	05/31/1979
From:	Dewease J TENNESSEE VALLEY AUTHORITY
To:
Shared Package
ML18024A849	List: ML18024A848 ML18024A850
References
NUDOCS 7906150283
Download: ML18024A850 (36)

Text

TENNESSEE VALLEY AUTHORITY DIVISION OF POWER PRODUCTION BROWNS FERRY NUCLEAR PLANT MONTHLY OPERATING REPORT Hay 1, 1979 i~iay 31, 1979 DOCKET i%uSERS 50-259, 50-260, AND 50-296 LICENSE NUiiBERS DPR-33'PR-52'ÃD DPR-68 Submit.tted By:

Plant Superintendent 790615099+;

TABLE OF CONTEiXTS Operations Summary .

Refueling information ~ 2 Significant Operational Events Average Daily Unit Power Level ~ 9 Operating Data Reports ~ 12 Unit Shutdowns and Power Reductions. 15 Plant Maintenance 18 Outage Section ifonthly Report 34

0 erations Summar 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 six reportable occurrences repoxted to the i'uxing the month of May.

Unit 1 The unit did not scram during the month.

Unit 2 The unit was down for refuel the entire month. The unit scrammed four times during startup. On May 26, the unit scrammed on high IRK flux during rod withdrawal. On May 28, the reactor scrammed on TRM high flux due to a feedpump control malfunction. The reactor scrammed on May 29 due to vessel low water level (feedwater control, malfunction).

On May 30, the reactor scrammed when the MSIV's closed during venting of the main steam line flow sensors.

Unit 3 The unit scrammed once during the month. On May 13, the reactor scrammed on low water level due to a feedpump control malfunction.

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

Location Usa e Factor Unit 1 Unit 2 Unit 3 Shell at water line 0.00407 0.00280 0.00251 Feedwater nozzle 0.18688 0.12200 0.09658 Closure studs 0.17378 0.10829 0.07406 Note: This accumulated monthly information satisfies technical specification section 6.6.A.17.b(3) reporting requirements.

Common S stems Approximately 1.07E+06 gallons of waste liquid were discharged containing 5.87E-OI. curies of activity.

Cooling towers 1, 2, 3, and 6 were operational. Repair work on Tower 4 was completed. Installation of new fillmaterial on Tower 5 continues.

Refueling Information Unit 1 Unit 1 is scheduled for its third refueling beginning on or about December 15, 1979, with a restart date of January 25, 1980. This refueling will load additional 8 x 8 R (retrofit) fuel assembl'es into the core, replacing presently loaded 7 x 7 fuel.

Unit 1 (Continued)

I There are 764 fuel assemblies in the core. The spent fuel storage pool presently contains 322 spent 7 x 7 fuel assemblies and two 8 x 8 R fuel assemblies. Because of modification work to increase spent fuel pool capacity to 3471 assemblies, present capacity is limited to 524 assemblies.

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

Unf.t 2 Unit 2 began its second refueling beginning on April 27, 1979, with a scheduled restart date of June 1, 1979. 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 was submitted to the NRC in February. This refueling involves replacing some more 7 x 7 fuel assemblies with 8 x 8 R (retrofit) assemblies.

There are 764 fuel assemblies in the core. At the end of the month there were 132 discharged cycle 1"fuel assemblies and 268 discharged cycle 2 fuel assemblies in the spent fuel storage pool. The present storage capacity of the spent fuel pool is 1080 assemblies. Present planning is to increase that capacity to 3471 assemblies. With present capacity, the 1979 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.

4 Unit 3 Unit 3 is scheduled for its nezt refuel outage beginning on September 1, 1979, with a scheduled restart'ate of november 20, 1979. This refueling will involve loading additional 8 x 8 R (retrofit) assemblies into the core, torus integrity modifications, core spray piping modifications, EECW piping changes, feedwater sparger modifications, and LPCI modifications.

Resumption of operation following refueling will require changes in technical specifications pertaining to the core thermal limits. Licensing information in support of these 1

changes will be submitted before the refueling.

There are 764 fuel assemblies presently in the core. There are 208 fuel assemblies in the spent fuel storage pool. The present licensed storage capacity of the spent fuel pool is 1132 assemblies.

Si nificant Onerational Events Uait 1 Date T~4e Event 5/01/79 0001 Reactor thermal power at 20% with power ascension in progress 1530 Commenced PCIOMR from 75% thermal power S/O2 2305 Reduced thermal power from 86% to 45% for control rod A

pattera adj'ustment e

S/O3 0018 Control rod pattern adjustment completed, commenced power ascension 0300 Commenced PCIOHR from 70% thermal power s/o4 1930 Reactor thermal power at 99%, steady state 5/05 2210 Reduced thermal power from 99% to 85% for turbine CV tests and SI's 2355 Turbine CV tests ann SI's completed, commenced power ascension s/o6 0030 Commenced PCIOHR from 95% thermal power 0700 Reactor thermal power at 99%, steady state 5/07 0300 Reduced thermal power from 99% to 70% due to "A" recirculation pump run back (blown fuse 2A-P16A) 0330 Blown fuse replaced, commenced power ascension 0430 Commenced PCIOHR from 95% thermal power 0700 Reactor thermal power at 99%, steady state S/11 1500 Reduced thermal power from 99% to 93% and locked "B" recirculation pump scoop tube when placed on manual due to HG set coatroller malfunction.

2000 "B" recirculation pump scoop tube unlocked, commenced power ascension S/12 0630 Reactor thermal power zt 99%, steady state 5/18 2200 Reduced thermal from 99% to 40% for control rod sequence ezchange from "B" to "A" S/19 0020 Commenced turbine CV tests and SI's 0225 Turbine CV tests and SI's completed, holding for control rod sequence exchange 0405 Control rod sequence e:<change from "B" to "A" completed, commenced. power ascension 5/20 0330 Commenced PCIOHR from 90% thermal power 5/21 0350 Reactor thermal power at 99%, steady state

I Si nificant Operational Events Unit 1 Date Time Event 5/23 1155 Reduced thermal power f om 99% to 90% for isolation oz "A" low pressure heaters for level controller maintenance 1200 "A" low pressure heater level controller replaced and heaters placed in service, commenced power ascension 1300 Reactor thermal power at 99%, steady state

'=* '/24 2140 Reduced thermal power from 99% to 55% for control rod pattern adjustment 2310 Control rod pattern estaolished, commenced power ascension 5/25 0100 Commenced PCIOHR from 80% thermal power 5/26 0800 Reactor thermal power at 99%, steady state 5/31 2400 Reactor thermal power at 99%, steady state

7 Si nificant Operational Events Unit 2 Date Time Event 5/01/79 0001 Reactor at cold shutdown for scheduled refueling outage (cycle 3 fuel) 5/26 1816 Commenced rod withdrawal for startup (turbine unavailable) 1928 Reactor scram no. 77 while subcritical on I%M hi flux 5/27 0207 Commenced rod withdrawal 0322 Reactor critical no. 88 0327 Reactor made subcritical 1443 Reactor critical no. 89 5/28 2213 Reactor scram no. 78 (1) on IRM hi flux (feedpump control malfunction) 5/29 0027 Commenced rod withdrawal 0200 Reactor critical no.($

0632 Reactor scram no. 79 ) on low water level (feedwater control malfunction) 0808 Commenced rod withdrawal 0910 Reactor critical no. 91 0912 Reactor made,subcritical 1223 Reactor critical no. 92 5/30 1000 Reactor scram no. 80 (1) on HSIV isolation during venting of main steam line flow sensors 1532 Commenced rod withdrawal 1740 Reactor criticaL no. 93 5/31 2400 Reactor critical with startup in progress with turbine still unavailable

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Si nificant Operational Events Unit 3 Date Time Event 5/01/79 0001 Reactor thermal power at 80%, holding for maintenance on "C" reactor feedwater pump 5/13 0110 Maintenance and vibration checks completed on "C" reactor feedwater pump and pump placed in service, commenced power ascension 0230 Commenced PCIOMR froyi)8% thermal power 0835 Reactor scram no. 72 from 95% thermal power on low reactor water level due to reactor feedwater 5/14 2355 Reactor feedwater pump maintenance completed, holding for hydrogen sensor replacement 5/16 0510 Hydrogen sensor replaced, commenced rod withdrawal 0629 Reactor critical no. 82 1447 Roiled T/G 1547 Synchronized generator, commenced power ascension 5/17 0700 Commenced PCIOMR from 70% thermal power, control rod sequence "B" J

5/18 1720 Reduced thermal power from 90% to 75% for maintaining reactor water level while charging "C" string high pressure heaters 1745 Commenced PCIOMR from 75% thermal power 5/19 2315 Reduced thermal power from 88% to 50% for control rod pattern adjustment and for turbine CV tests and SI's 5/20 0137 Concrol rod pattern adjustment completed, holding for turbine CV tests and SI's 0145 Turbine CV tests and SI's completed, commenced power ascension 0700 Commenced PCIOMR from 72% thermal power 5/21 2300 Reactor thermal power at 99%, steady state 5/25 2240 Reduced thermal power from 99% to 80% for turbine CU tests and SI's 5/26 0045 Turbine CV cests and Si's completed, cormnenced power ascension 0240 Commenced PCIOMR from 88% thermal power 1523 Reactor thermal power a" 99%, steady state 5/31 2400 Reac or thermal power at 99%, sceady state (1) Equipmenc malfunction

9 AVERAGE DAILYUNIT POWER LEVEL DOCKET NO.

COPIPLETED BY MONTH DAY AVERAGE DAILYPOWER LEVEL DAY AVERAGE DAlLYPOWER LEVEL (irlWe.Net) (MWe.Net) l7 872 18 1048 l9

~1. 1056 20 2l 1057 5

1060 1053 1045 23 1051 1063 15 868 IO 26 1043 27 1070 1044 '2S 1070 12 l3 '79 30 76 l5 1063 3l 1065 l6 1056 INSTRUCTIONS Qn this format. list the average daily unit power level in iNIWe.Net for each day in the reporting tnt>nth. Cotnpute to the nearest whole megawatt.

(')l>7)

AVERAGE DAILYUNIT POWER LEVEL i

DOCKET NO. 50-260 Browns Perry 2 DATE COMPLETED BY TELEPHONE 205-729-684 6 hIONTH DAY AVERAGE DAILYPOWER LEVEL DAY AVERAGE DAlLYPOWER LEVEL (hiWe.Net) (hIWe-iNet) 17

-2 l8 l9 80 5

6 22 7 23 8

9 25 10 26 27 l2 -10 28 l3 29

-10 14 30

-10 IS 31

-10 I6 INSTRUCTIONS On this format,!ist the average daily unit power level in M~Ve.Net for each day in the reporting tnonth. Compute to the nearest whole megawat t.

(9 j77 l

AVERAGE DAlLYUiVITPOWER LEVEL Browns Perry 3 DATE ~2~7 COMPLETED BY TEI.EPHONE 205-729-6846 MONTH DAY AVERAGE DAILYPOWER LEVEL DAY AVERAGE DAILYPOWER LEVEL (MWe-iVet) (MWe.Net) 856 747 I 17 853 18 898 877 894 3 19 879 803 10 879 1010 21 6 22 1054 877 23 1043 875 14 1051 873 1048 9 25 873 1066 10 26 27 1010 868 28 1068 339 19 1071 13

-13 1050 30 IS 31 1064 16 INSTRUCTIONS On this format. !ist the average daily unit power level in ib('iVe.Net for each day in the reporting month. Compute to the nearest whole rnegawat t.

('>!77)

12 OPERATING DATA REPORT DOCKET NO.

DATE COMPLETED SY TELEPHONE

~~n

~~9 6-2-79 6846 OPERATING STATUS Notes I. Unit Name'

2. Reporting Period:

3. Licensed Thermal Power (MWt):

4. Namephte Rating (Gross MWe):

5. Design Electrical Rating (Net MWe):

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

9. Power Level To Which Restricted, If Any (Net i~IWe):

10. Reasons For Restrictions. If Any:

'his Month Yr.-to.Date Cumuhtive Il. Hours In Reporting Period

12. Number Ot Hours Reactor Was Critical

13. Reactor Reserve Shutdown Hours 0 167.31 4566.44

14. Hours Generator On-Line 744 2937.72

15. Unit Reserve Shutdown Hours 0 0 '22629.069,382,694

16. Gross Thermal Energy Generated (MWH) 2, 315,045 8,610,022 I'7. Gross Electrical Energy Generated (MWH) 770,280 19,6 8,5 0

18. Net Electrical Energy Generated (MWH) 750 029 2 794 415 19'00 635

19. Unit Service Factor 100 81.1 53.4

20. Unit Availability Factor . 100 81.1 53.4

21. Unit Capacity Factor (Using MDC Net) 94.7 72.4 42.3

22. Unit Capacity Factor (Using DER Net)

23. Unit Forced Outage Rate 0 6.7 37 3

~

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

5

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

26. Units In Test Status (Prior to Commercial Operation): Forecast Achieved INITIAL CRITICALITY INITIAL ELECTRICITY COiIAIERCIALOPERATION (oi77)

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13 OPERATL iG DATA REPORT DOCKET NO.

DATE COMPLETED BY TELEPHON E ~~6846 OPERATIj IG STATUS Unit Name. Browns Ferrv 2- Notes Z. Reporting Period:

3. Licensed Thermal Power (MWt):

4. Namephte Rating (Gross MWe):

S. Design Electrical Rating (Net MWe):

6. Maximum Dependable Capacity (Gross jlfWe):

7. ibfaximum Dependable Cap a c itv (Net MWe:)

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

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

10. Reasons For Restrictions'If Any:

This Month Yr..to.Date Cumulative

11. Hours In Reporting Period

~

12. Number Of Hours Reactor Was Critical o 0

"-'3. Reactor Resene Shutdown Hours 8. 25 11 534.96

"', 14. Hours Generator On-Line 0 2770.40 18 838.26

15. Unit Reserve Shutdown Hours 0 0 0

16. Gross Thermal Energy Generated (MWH)

17. Gross Electrical Energy Generated (MWH) 0 2,857,580 17, 171,368 0 1 7 747 0 IS. Net Electrical Energy Generated (MWH)

19. Unit Service Factor 76.5 50.5

20. Unit Availability Factor 0 76.5 50.5

21. Unit Capacity Factor (Using ifDC Net) 0 72.2 42 '

72.2 42.0

22. Unit Capacity Factor (Using DER iNet)

23. Unit Forced Outage Rate 0 1.3 41.9

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

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

26. Units In Test Status (Prior to Commercial Operation): Forecast Achieved INITIAL CRITICALITY liNITIAL ELECTRICITY CO%I if ERCI A L OPER ATIOi i

• Inforajation unavailable (9/77)

OPERATIi IG DATA REPORT DOCKET NO.

DATE 6-2-79 COibIPLETED BY DRIES ~rg TELEPHONE ~y'~ol46 OP ERAT li lG STATUS Notes

1. Unit Name'

2. Reporting period: Mav 1 7o

3. Licensed Thermal Power (ilIWt):

4. Nameplate Rating (Gross ibIWe):

5. Design Electrical Rating (Net siIWe):

1065

6. Maximum Dependable Capacity (Gross MWe):

7 Maximum De p endableCa p acit y(Net MWe:,

~ s )

1065

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

9. Power Level To which Restricted, If Any (Net ibIWe):

10. Reasons For Restrictions, If Any:

This sblonth Yr:to-Date Cumulative ~ I e

Il. Hours In Reporting Period 744 3623 19'27

12. Number Of Hours Reactor Was Critical 3539.25 16,630.45

13. Reactor Reserve Shutdown Hours 69 9~ 83.75 1189.16

14. Hours Generator On-Line 664.8 3522.17 16252.15

15. Unit Reserve Shutdown Hours 0 0

16. Gross Thermal Energy Generated (MWH) 1,927,118 10,762,566 46,913,948 ty. Gross Eiectrient Energy Generated iMtVH) 3 593 640 15 361,140

18. Net Electrical Energy Generated (M'IVH) 3,504,795 14,909,983

19. Unit Service Factor 97.2 82.4

'.8

20. Unit Availability Factor 9 0 8 ~ 71.0

22. Unit Capacity Factor (Using DER Net) 78.0 90.8 71.0

23. Unit Forced Outage Rate 10.6 8.1

24. Shutdowns Scheduled Over Next 6 i~lonths (Type, Date. and Duration of Each):

uta e Seotetaber 1. 1979

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 ELECTRlCITY CORI!it ERCIA L OPERATION

(</77)

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DOCKET NO.

UNIT SIIUTDOWNS AND PO1VER REDUCTIONS REPORT hION fll COMPLETED IIY JlOa QKLCQ=

TELEPI ION E I

C ~

PI Ci Ltccrtscc C+0 c Cause &. Corre<ttve Q 0 No. Date Vl l . Event N o D Action lo Q

v l/l Rcport rr m Cr C O

~ Prevent Recurrcncc Cr 80 79 05 02 Derated for control rod pattern ad ustment 79 05 07 Derated due to "A" reclrc pump run back 82 79 05 38 Derated for control rod sequence exchan e from "II" to "A" 83 79 05 24 Derated for control rod pattern ad ustment F: Forced Reason: hlethod: Exlribit C ~ Instructions S: Scheduled A.Equipmcnt Failure (Explain) I.hlanual for Preparation of Data II hlaintenance or Test 2.hlanual Scram. Entry Sltecls lor l.icc>>see C-Rcfuelinl, 3-Automatic Scram. Event Report (I.L'R) File (NUREC-D.i<et;ulatory Restriction 4.0ti>er (Explai>>) OI6I)

E.Operator Training & I.iccnsc Examination F-Administrative C Operational I.rror (Explain) Fxhibit I ~ Satnc Source

()/>>) II Other (fixplain)

DOCKET NO. 50 260 UNIT SI IUTDO)UNS AND POlVER REDUCTIONS Bt-ownn F 2 UNIl NAhIE REPORT h(ONTII COh(PLETED OY TELEPIIONF

~~~n 205-729-684<6 fP~

I

<'< Q A 0 Cause k, Corrective

~ n Liccllscc <<>

O No, Date IA rj ~ cc Event Q O Aclloll t<l o

l(cporl 4 0 Prevent Recurrence

~ CA 86 79 05 01 744 Refueling F: Forced Reason: hlethod: Exhibit G- Instructions S: Scheduled A.Equipment Failure (Explain) I hIanual for Preparation of Data I).hlaintenance or Test 2.hlanual Scram. Entry Sheets for I.iccnsee C. Refueling 3-Aulontatic Scram. Event Report (LL'R) File (NUREG.

- D Regulatory Restriction 4.Other (Explain) 016I)

E.Operator Training A license Examination F.Administrative G Olrerati<mal (error (I'.xplain) Exhibit I - Same Source

(<>/77) II Other (Explain)

UNIT SIIUTDO\VNS AND POPOVER REDUCTIONS Browns Perr 3 UNIT NAhfE COhIPLETED BY TELEPllONE gr, r ~

PI c '~ CQ u

Licensee Cause &. Corrective IV 0 o p o No. Date . Event Vl Action lo u U~

w rir r. Rcport 8 cn G I~ Prcvcrtt Rccurrcrtce 93 79 05 01 Derated due to high vibration on oCo Rx feed um 9'9 05 13 F 79.2 Low Rx pump water level due to feedwater controls malfunction. Unit remained down for replacement of torus H2 sensors 79 05 19 Derated for control pattern adjustment and turbine CV tests F: Forced Reason: Method: Exhibit G - Instractions S: Scltcduled A.Equipment Failure (Explain) I.hlaoual for Preparation ol'Data B.hlaintenance or Test 2 hlaoual Scram. Entry Sheets I'or Licensee C.Refueling 3.Aulotnatic Scram. Evcllt Rcport (LER) File (NUREG-D Regular ory Rest r iclion 4.0t I>er (L'xplain) OI 6I )

E Operator Training k License Examination F-Ad odrrisl ra I lac 5 G Operational Lrrur (Explain) ~

Exhibit I - Satnc Source

('>/77) I I.Other (lixplain)

BROWS PERRY NUCLEAR PIANT UNIT CSSC E UIPHEHT HEC1IANICAL HAINTENANCE SUI DIARY Por the Honth of Hay 19 79 EFFECT ON SAFE ACTION TAKEN NATURE OP OPERATION OF CAUSE OP RESULTS OF TO PRECLUDE DATE SYSTEH COHPONENT IIALFUNCTION HALFUNCTION RECURRENCE IIAINTENANCE THE REACTOR Rx. and Air washer Dirty screens Insured clean Airborne parti- Dirty'screens Cleaned screens Turbine screens air in reactor cles Bldg. Vent and turbine bldg i/22 Rllk SN Cl RIIRSW pump Seat and floe None Defective seat Lack of seal Replaced seal an discharge vent damaged; woul and float float not seal off i/20 SI.C SI.C accumula- IlHI 40 None None None HHI 4O tors i/17 Control lB control Clean tubes None Dirty tubes None Cleaned oil cooler Bay bay chiller and installed new Vent gaskets, cleaned evaporator and reassembled opened raw water cooler and inspected.

0 i/20 Control C Bay chiller Valve needs None Valve leaking Hone Plugged holes Bay lA replacing Vent

BROMNS PERRY NUCLEAR PIANT UNIT 1 CSSC H VIPHHNT hfEClfANICAL 1fAINTENANCE SUM fARY For the Honth of Nay 19 ~9 EFFECT ON SAPE ACTION TAKEN DATE SYSTEH COHPONENT NATURE OPERATION OP CAUSE OP RESULTS OP To PRECLUDE Or'fAINTENANCE TflE REACTOR ffALPUNCTION ffALFUNCTION RECURRENCE Rx. Recirc Recirc pump Check pressure None None one hecked pressures and shaft seals and annuncia- mnuncia tions tions .

Control Computer room Excessive cabl None Excessive cable ables heavier than rnstalled weights on Bay Vent. CO2 operated weight weight ampers dampers dampers 1-85-516A Packing leak Necessary for Loose packing 'eeking leak ightened packing safe shutdown

BROWS PERRY NUCLEAR PLANT UNIT 2 CSSC E UIP11ENT ~

MECHANICAL MAINTENANCE SUNHARY Por the Honth of 14y 19 79 EPFECT ON SAPE ACTION TAKEN DATE SYS TEN COHPONENT NATURE OF OPERATION OF CAUSE OP RESULTS OF TO PRECLUDE NAINTENANCE THE REACTOR W LPUNCTION 11ALFUNCTION RECURRENCE

'7 Rx. Recirc Recirc pump Check pres- None None None Checked pressures shaft seals sures and and annunciations annunciations I9 Rx. Zone Vent 2-6~i-510 area Remove metal sheet- None Sheetmetal lloles blocked off'emoved patch cov ng covering openings openings

'23 2-PSV-85-37B Install for CRD CRD Necessary Needed CRD drain None', Installed kits drain and safe Rx. shut- and vent pilot vent pilot dowll valve repair kit valve repair installed kit

BROWS FERRY NUCLEAR PLANT UNIT 3 CSSC E UIPffENT MECHANICAL tfAINTEHANCE SUM fARY For the lfonth of 'y 19 79 EFFECT ON SAFE ACTION TAKEN CO>1POHENT NATURE OF OPERATION OF CAUSE OF RESULTS OF TO PRECLUDE DATE SYS TEH lfAIHTENANCE TflE REACTOR MALFUNCTION lfALFUNCTION RECURRENCE 5/7 Rx. Recirc Recirc pump Check pressure None Hone Hone Checked pressure and shaft seals and annuncia- annunciations tions 5/8 Control CO> operated Excessive Hone Excessive cable Cables heavier than Installed weighes Bay Vent. dampers in cable weight weight dampers on dampers computer room 3 5/13 Fuel pool 3A fuel pool Leaking at None Packing leaking Leaking Adjusted packing Cleanup cleanup'pump inboard pack-ing 5/14 Primary Torus Open manhole None None None Hanhole opened Contain-ment Primary Torus Open Hanhole None None None kfanhole opened Contain-mene 5/15 Drywell Drywell doors Replace o-ring Insures primary Worn gaskets Heeded gaskets Replaced gaskets Doors gaskets containnlent

BROILS PERlti NUCLEAR PLAM1 UHIT EI.ECTRICAT. HAINTENANCE SlkkfARY Page 1 of 1

)ate System Component 'ature of Haintenance E ect Opera on Sate tion The Reactor o f Cause of Halfunction Results of Halfunction Action Taken To Preclude Recurrence 79 Standby Battery char- Battery char- Not applicable Failed resistor Batteries not charg- Replaced resistors, diesel ger A for D ger mould not on chargers ing- placed on equalia-diesel gen-. charge ing charge, per-erator and formed EHI 4, checked battery char- OK, TR's 125928 a ger A for C 125931 diesel gen-erator

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BRO'alHS FERRY NUCLEAR PLANT UNIT CSSC E UIPtlENT ELECTRICAL HAIHTEHAHCE SIQfARY For the 11onth of Hay ]'9 79 . Page 2 of 5 E ecton 'a e Action Taken System Component Nature of Opera tion o f Cause of Results of To Preclude Ilaintenance .The Reactor Nalfunction Halfunction Recurrence Hain Limi:torque Perform EtK Not applicable Beacon 325 Potential failure Inspected and steam, motor opera- 16 (limi- grease breaking of geared limit removed all Beacon Rt 1CU, ted valves torque geared down due to high switch 325 grease, replaced RCIC$ located in lind.t switch temperatures lubricant with Mobil 11PCI, and drywell, gear box grease 28, performed RHR steam tunnel, lubricant EHI 18 and EHX 16~.

and RHCU room inspection listed in and replace- Valve 8 rat a t taclunen t A ment unit 2 FCV-1-55 87940

-of EtlI 16 1-57 137903 1-56 142746 71-3 137913 1-169 137907 1-170 137908c-69-1 137910 68-33 130997 68-1 87944 68-77 142773 68-79 130996 68-3 87945 74-78 137915 73-2 1427 71-2 69-2 137911 68-35 130998 74-48 137914, 1-58 137904 Primary lli rad-refuel Annunciator Not applicable Open relay coil Annunciation would Replaced coil, contain- zone relay inoperable not clear tested functional, ment 16AK63A coil TR 127244

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VRIT BROlPilR FERRY MVCLEAR PLANT CSSC E UIPHENT ELECTRICAL HAINTENANCE SUGARY For the ffonth of Hay 19 79 . Page 4 of 5 ect on 'a c Action Taken I)ate System Component Nature of Operation of Cause of Results of To Preclude llaintenance The Reactor Halfunction Halfunction Recurrence 5-24-79 IfPCI Uni.t 2 IfPCI Ramp genera- Not applicable Electronic If in operation, Replaced-ramp gen-ramp genera- tor and EGH equipment ap-. .

ffPCI would have erator and EGH box, tor and EGff box would not parently shorted failed to operate checked OK, TR box operate pro- out by mechani- 125916 perly c'al problems in EGR 5-24-79 Reactor FCV-68-1 Adjust limit Not applicable Limi.t swi.tch out Unable to start Adjusted limit water (R/C 2-A switch 813 of adjustment recirculation HQ switch 813, checked recircu- suction set OK, TR 110327 lation valve) limit switch 813 5-24-79 Reactor FCV-68-3 Adjust limit Not applicable Limit switch out Unable to start Adjusted limit cn water switch 813 of adjustment recirculation HG switch 813, checked recircu- set OK, TR 125917 lation 5-24-79 Reactor. FCV-68-77 Adjust limit Not applicable Limit switch out Unable to start Adjusted limit water switch 813 of adjustment recirculation HG swi.tch 813, checks recircu- set OK, TR 125919 lation 5-24-79 Reactor FCV-68-79 Adjust limit Not applicable Limi.t switch out Unable to start Adjusted limit water I switch 013 of adjustment recirculation HQ switch 813, checked recircu- set OK> TR 125918 lation

RROMiYE PERRY RUCLEi'R PLRRT UUTT 2 ELECTRXCAL MAINTENANCE SUHIIARY 39 79 Page 5 of 5 ect on ba e Action Taken it e System Component Nat:ure of Operation of Cause of Results of To Preclude llaintenance The Reactor Malfunction Malfunction Recurrence 25-79 llPCI Auxiliary oil Check start None, unit in Motor and 250V Xf in operation, Replaced circuit auxiliary'il pump motor refueling out-. breaker failed 1IPCX would have not pump motor and age operated properly breaker,. teated OK, TR 126988

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30-79 Radiation Cam 90-57 Pump inopera- Not applicable Pailed motor Motor. inoperable Xnstalled new motor, monitorin pump mot:or tive bearings tested OK, TR 138902 79 Hain Hain steam Valve posi- Not applicable Loose limi.t Green light (closed Tightened limit steam isolation t:ion indica- switch arm stays on with valve switch arm, tested valve 1-37 tion inopera- open OK, TR 124737 tive 79 Control IIS-85-47 Chtlck over- Not applicable Pai.led override Override switch Replaced override rod drive rod out, rod ride switch switch inoperable switch, tested OK,'R notch over- 124785 ride switch

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ER0%13 FERRY NUCLEAR PLANT UllLT 3 CSSC E UIFIIENT ELECTRICAL HAINTENANCE SIMARY A For the IIonth of Hay 19 79 Page 2 of 3 E ect on a e Action Taken

)ate System Component Nature of Operation of Cause of Results of To Preclude Ilaintenance The Reactor . Halfunction ARfalfunction Recurrence 3-15-79 Hain Check relay Not applicable Limit switch 3 Relay de-energized Adjusted limit steam and 4 on FCV switch actuator, 14 and limit tested OK, TR's switch on FCV- 115816, 115815, and 1-26 106115

>-3.5-79 IIPCI FCV-73-45 Check red Not applicable Limit switch out Red light (open Adjusted and clea (testable light cir- ,of adjustment .position indica- limit switch and check valve) cuit tion) inoperable tested valve OK, indicating TR 126&61 lights 5-15-79 RPS Reactor Scram Spring does Not applicable Spring out of Failure of spring Replaced spring, reset switch not function keeper to return to nor- tested operation OK, return spring properly mal position TR 122627 5-15-79 Hain FCV-1-52 Limit swi.tch Not applicable Limit switch 5AK3H relay dropped Replaced limit steam for 5AK3II failed out switch, checked OK, relay out of TR 106114 adjustment 5-15-79 Radiation Cam unit:s 3- Check belts Not applicable Morn belts Preventative 'Replaced belts, Honitorin 90-249

~ and maintenance checked OK, TR 3-90-251 131042 vacuum pump belt:s

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,, RRO'.iWS Pram Wcr.ml rr.@AT,ynZT 3 CSSC E UIPHENT ELECTRICAL MAINTENANCE SRMARY For t: he lfonth of Hay 19 79 Page 3 of 3

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ect on a e Action Taken System Component Nature of Operation of 'ause of Results of To Preclude Haintenance The Reactor. lfalfunction Halfunction Recurrence 79 Rllk FCV-.74-68 .

Closed posi- Not applicable Broken leads at Green'light- failure Repaired leads, (testable tion.(green)" Reed switch on tested OK, TR check valve) indicating valve 126856.

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light irioper-

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able i-16-79 RCIC FCV-71-3 ChecIc limit , Not applicable Defective limit Unable to determine Replaced limit limit switch switch switch proper positiop of switch, performed valve EllI 18, TR 142759 i-16-79 Air con- 3B chiller Check operat- Not applicable Oil pump starter Chiller inoperable Tightened starte'r ditioning ing cycle contactor fail- connection, checked ure OK, TR 126847 (A i-21-79 llPCI LA-73-8 (HPCI Check hi level Not applicable Float stuck Alarm in Freed float, cleared turbine drain annunciator, checked exhaust: drain operation, OK, TR pot hi level 126699.

annunciation) 5-22-79 Fuel pool LS-78"28 lli level Not applicable Bad switch Would not come-in Replaced switch,-

cooling (fuel pool) sbitch in- for .high level 'performed Etll 48, and de- operable TR 127326 mineraliz-ing

HROIINH IHRRRY NVCI.HAR PLASHY UHYY INSTRlJt tENT HAINTENANCE StMfhRY For the Honth of CSSC EQUIPHENT

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ect on Sa e Action Taken

)ate System Component Nature of . Operation of Cause of Results of To Preclude Haintenance The Reactor Halfunction Halfunc tion. Recurrence i-29-79 Primary PDT-64-138 Calibrate None Zero drift Indication did not None Contain- agree with redun-ment dant indicator t

i-31-79 Emergency PdS-67-1 Replace None Diapliram rupture High DP al'arm Hone Equipment would not clear I Cooling tJater

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BUO)JtLS FUlNY UUCLEAll 1'LANT UllLT 3 INSTRUffENT HAXNTENANCE SUHffARY For the Honth of Hay 19 79 CSSC EQUIPlfENT E ect on Sa e Action Taken

)ate System Component Nature of . Operation of Cause of Results of To Preclude Haintenance The Reactor Halfunc tion Halfunction Recurrence 79 Radwaste FQ-77-6 Calibrate None Zero shi ft Indicates flow wi.th None pump off

~ 79 Neutron XfQf "F" Repair None Open detector No indication of. None Honitor- ~ cable in dry- power lave'1 inf; well

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34 OUTAGE SECTION MONTHLY REPORT May 1979 Major work for the outage group during the month of May. consisted of scheduled maintenance to Un't 2 which was down for refueling. Scheduled maintenance involved work in the drywell and testing and repair to the

'main steam isolation valves, other primary containment isolation valves and miscellaneous system valves. There were also modifications and maintenance performed on the main steam relief valves, feedwate" heaters and condensers. Electrical work consisted of maintenance on the electrical boards and motors and other scheduled maintenance.

The low pressure "B" section of the turbine was inspected and over 1000 dovetail pins replaced. Major turbine valves, such as the stop, control, bypass,. intercept and cross-around relief, were inspected.

The Unit 2 outage was completed on June 1, 1979, making the total length of the outage 34 days.

There were several ongoing modifications which were not related to the Unit 2 refueling outage. The magnetic switch and conduit pull to the control room for the security modification was underway along with the installation of the 480V reactor MOV boards .for the LPCI modification.

The excavation for the hypochlorite building was underway and is also continu'ng. The trip logic and cable terminations are almost complete on the cooling towers, with testing underway.