ML18024B055

Monthly Operating Repts for Sept 1979

ML18024B055
Person / Time
Site:	Browns Ferry
Issue date:	10/02/1979
From:	Thom T TENNESSEE VALLEY AUTHORITY
To:
Shared Package
ML18024B054	List: ML18024B053 ML18024B055
References
NUDOCS 7910160369
Download: ML18024B055 (31)

Text

TENNESSEE VALLEY AUTHORITY DIVISION OF POMER PRODUCTION BROWSES FERRY NUCLEAR PLANT MONTHLY OPERATING REPORT September 1, 1979 September 30, 1979 DOCKET NUMBERS 50-259, 50-260, AND 50-296 LICENSE NUMBERS DPR-33, DPR-52, AND DPR-68 Submitted By:

g'lant Superintendent

TABLE OF CONTENTS Operations Summary 0

~

~

~

~

~

~

~

~

Refueling Information

~

~

Significant Operational Events Average Daily Unit Power Level 10 Operating Data Reports Unit Shutdowns and Power Reductions.

13 16 Plant Maintenance Outage Section Monthly Report'.

26

\\

0'er'ations 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 reported to the NRC during the month of September.

Unit 1

The unit scrammed, twice during the month.

On September 1, the reactor was manually scrammed to investigate oil level alarms on both recirculation pump motors.

The reactor was manually scrammed on September 26 to accommodate maintenance on main steam high temperature switches in the steam tunnel.

Unit 2 The uni,t scrammed once during the month.

On September 17, the reactor scrammed due to'MSIV closure caused by personnel error during surveillance testing.

Unit 3 The unit was down for refueling the entire month.

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

'Location

'Un2t 1

'Untt 2

'Unit 3 Shell at water line, Feedwater nozzle Closure studs 0.00415

0. 19815 0.17510 0.00301 0.12879 0.11238 0.00261 0.10293 0.07865 Note:

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

Common S stems Approximately 1.14E+06 gallons of waste liquid were discharged containing 8.61E-Ol curies of activity.

Refuelin Information Unit 1

Unit 1 is scheduled for its third refueling, beginning on or about November 29, 1979, with a restart date of January 16, 1980; This refueling will involve loading additional 8 x 8 R (retrofit) fuel assemblies into the core replacing presently loaded 7 x 7 fuel, and LPCI modifications.

There are 764 fuel assemblies in the reactor vessel.

The spent fuel storage pool presently contains 322 spent 7 x 7 fuel assemblies, two 8 x 8 R fuel assemblies, and 252 new fuel assemblies.

Because of modification work to increase spent fuel pool capactity to 3471 assemblies, present capacity is limited to 720 assemblies.

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

Unit 2 is scheduled for its third refueling beginning on September 1,

1980, with a scheduled restart date of October 7, 1980.

Resumption of operation on that date will require a change in technical specifications pertaining to the core, thermal limits.

Licensing information in support of these changes will be submitted to the NRC before the outage.

This refueling involves replacing some more 7 x 7 feul assemblies with 8 x 8 R (retrofit) assemblies.

There are 764 fuel assemblies in the reactor vessel.

At the end of the month, there were 132 discharged cycle 1 fuel assemblies and 268 discharged cycle 2 feul assemblies in the spent fuel storage pool.

The present storage capacity of the spent fuel pool is 1080 assemblies.

WH.th 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.

Unit 3 Unit 3 began its second refuel outage on August'4, 1979, with a scheduled restart date of November 21, 1979.

This refueling involves loading additional 8 x 8 R (retrofit) assemblies into the core, MSRV tailpipe routing, core spray piping modifications, 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 changes has been previously submitted.

Ther are NO fuel assemblies presently in the reactor vessel.

There are

'64 assemblies from the cycle 2 core, 208 discharged cycle 1 fuel assemblies and 144 new fuel assemblies in the spent fuel storage pool.

The present

4'torage capacity of the spent fuel pool is 1528 assemblies.

With present

capacity, the 1980 refueling would be the last refueling that could be

/

discharged to the spent fuel pool without exceeding that capacity and maintaining full core discharge capability in the pool.

Si nificant 0 erational Events Unit 1

Data Tfma Event 9/01/79 0001 2115 2246 Reactor thermal.power at 97%,

sequence "B"; CPR limited Commenced reducing thermal'ower for shutdown due to EHC

.oil leak Reactor scram no.

113 (manual) from 35% thermal power to accommodate EHC maintenance 9/03/79 0745 0910 1145 1207 2145 2204 EHC maintenance completed, commenced rod withdrawal Stopped rod withdrawal due to recirculation pump problems Resumed rod withdrawal Reactor critical no.

130 Rolled T/G Synchronized generator, commenced power ascension 9/04/79 1515 1551 1730 Reactor thermal power at 50%; holding for "control rod pattern adjustment Control rod pattern adjustment completed, resumed power ascension Commenced PCIOMR from 60% thermal power 9/05/79 2230 2340 Reduced thermal po~er from 78% to 60% due to two strings

.of high pressure heaters being out of service

("B" and "C" strings) for valve maintenance Reduced thermal power from 60% to 45% for control rod pattern adjustment 9/06/79 0010 0300 1520 1955 Control rod pattern adjustment completed, commenced

'power ascension Commenced PCIOMR from 60% thermal power Reactor thermal power at 68%, holding for SI's and flux shaping Resumed PCIOMR from 68% thermal power 9/07/79 1230 2330 Reactor thermal power at 90%, holding due to "C" string high pressure heaters being out of service for valve maintenance Commenced turbine C.V. tests and SI's from 90% thermal power 9/08/79 0010 Turbine C.V. tests and SI's completed, holding at 90%

thermal power for "C" string high pressure heaters maintenance 9/12/79 1435 2100 "C" string high pressure heaters in service, holding fear heater performance checks Commenced PCIOMR from 90% thermal power 9/13/79 2300 Reactor thermal pcwer at 93%,

CPR limited (max. flow)

Si nificant.O erational Events Unit 1 Date Time 9/15/79 2135 2235 Event Reduced thermal power from 93% to 50% for control rod pattern adjustment and turbine CV tests and SI's Turbine CV tests and SI's completed, holding for control rod pattern adjustment 9/16/79 0045 0305 Control rod pattern adjustment completed, commenced power ascension Commenced PCIOHR from 60% thermal power, sequence "B"

9/17/79 1500 9/21/79 2330 Reactor thermal power at 99%, steady state Reduced thermal power from 99% to 90% for turbine CV tests and SI's 9/22/79 0005 0100 0405 Turbine CV tests and SI's completed, commenced power ascension Commenced PCIOMR from 93% thermal power Reactor thermal power at 98%,

CPR limited (max flow) 9/24/79 0700 1010 1500 Reactor thermal power at 97%,

CPR limited (max flow)

Commenced power ascension after calibration of core flow instrumentation Reactor thermal power at 99%, steady state 9/26/79 1222 1250 1305 1345 1859 Reduced thermal power from 99% to 30% due to both recirculation pumps trip during Sl "A" recirculation pump placed in service, commenced power ascension "B" recirculation pump placed in service Reactor thermal power at 50%, holding for maintenance to high temperature switch in main steam tunnel on channel B2 logic Reactor scram no.

114 (manual) from 50% thermal power to accommodate maintenance to main steam high temperature switch in steam tunnel 9/28/79 1712 1726 2140 2210 Commenced rod withdrawal Reactor critical no.

131 Rolled T/G Synchronized generator, commenced power ascension 9/29/79 1500 9/30/79 2015 2130 2400 Commenced PC -OtR from Reduced thc;;mal power "A" reactor feedwater vibration Reduced thermal power pattern adjustment Reactor thermal power pattern adjustment 75% thermal power from 90% to 80% for removal of pump from service due to excessive from 80% to 58% for control rod at 58% holding for control rod

Si nificant 0 erational Events-Unit 2

Date Time Event 9/01/79 uOA1 0308 0516 0800 0825 2300 Reactor shutdown for EHC maintenance EHC maintenance completed, commenced rod withdrawal Reactor critical no.

96 Rolled T/G"'ynchronized generator, commenced power ascension Commenced PCIOMR from 80% thermal power 9/03/79 1500 9/04/79 0020 0103 0115 0700 Reactor thermal power at 99%, steady state Reduced thermal power from 99% to 85% for turbine CV tests and SI's Turbine CV tests and SI's completed, commenced power ascension Commenced PCIOMR from 95% thermal power Reactor thermal power at 99%,'steady state 9/06/79 1500 9/07/79 2310 Reactor thermal power at 100%, steady state Reduced thermal power from 100% to 70% for turbine CV tests and SI's 9/08/79 0101 0700 Turbine CV tests and SI's completed, commenced power ascension Reactor thermal power at 100%, steady state 9/14/79 2100 2303 Reduced thermal power ~m 100% to 45% for turbine CV

tests, SI's and control rod sequence exchange from "B" to "A" sequence Turbine CV tests and ST.'s completed, holding for control rod sequence exchange 9/15/79 0414 1100 1500 2150 2200 Contxol rod sequence exchange completed, commenced power ascension

'ommenced PCIOHR from 65% thermal power Reactor thermal power at 75%, holding for removal of "B" reactor feedwater pump from service for vibration detector maintenance Vibration detector maintenance completed, "B" reactor feedwater pump placed in service Resumed PCIOEK from 75% thermal power 9/16/79 1110 1335 Reduced thermal power from 85% to 72% for removal of "B" reactor feedwater pump from service due to erratic vibration detector "B" reactor feedwater pump placed in service, resumed PCIOi~iR from 72% thermal power

Si nificant 0 erational Events Unit 2 Date Time 9/17/79 0947 1500 1635 1848 1916 Event Reactor scram no.

85 (Mom 85% thermal power)

(1) during SI 4.2.A.3 Commenced rod withdrawal Reactor critical no.

97 Rolled T/G Synchronized generator, commenced power ascension 9/18/79 1418 9/20/79 2300 Commenced PC101K from 68% thermal power Reactor thermal power at 90%, holding due to "C" high pressure feedwater heaters being out of service 9/21/79 1120 2020 2050 2130 "C" high pressure feedwater heaters placed in service, holding for "J" condensate demineralizers problems (radwaste capacity prevents precoat.

and backwash)

Reduced thermal power from 90% to 85% for turbine CV tests and SI's Turbine CV tests and SI's completed, commenced power ascension "J" condensate demineralizer placed in service, commenced PCIOMR from 90% thermal power 9/22/79 0738 9/23/79

. 0030 0550 0830 1500 Reduced thermal power from 95% to 85% for removal of "C" string high pressure feedwater heaters from service for maintenance (leaks)

I Commenced PCIOHR from 85% thermal power "C" string high pressure feedwater heaters placed in service Resumed PCIOMR from 88% thermal power Reactor thermal power at 93% - holding (condensate demineralizer flow limited) 9/24/79 1230 9/25/79 0830 9/29/79 0015 0300 1500 Condensate demineralizer problems resolved (instrumentation calibration),

commenced PCIOIK from 93% thermal power Reactor thermal power at 99%, steady state Reduced thermal power from 99% to 85% for turbine CV tests and SI's Turbine CV :.csts and SI's completed, commenced power ascension Reactor the;mal power at 99%, steady state 9/30/79 2400 Reactor thi.rmal power at 99%, steady state

Si nificant 0 erational Events Unit 3 Date Time Event 9/01/79 0001 Unit shutdown with refueling operation for cycle 3

fuel in progress.

9/10/79 2230 9/30/79 2400 Core completely unloaded Refuel outage continues (1) Personnel error

10 AVERAGE DAILYUNITPOWER LEVEL DATE COhiPLETED BY Ted Thorn TELEPHONE 205/729-68 t6 DOCKET NO.

Br~5wns Ferry 1

10)'02/79 MONTH September 1979 DAY AVERAGE DAILYPOWER LEVEL (hIWe-Net)

I 931 17 DAY AVERAGE DAILYPO>VER LEVEL (hiWe-Net) 1000 10 12 13 14 15 16 10 517 674 879 916 914 923 937 869 987 1004 922 757 18 19 20 21 22 23 24 25 26 27 28 29 30 31 1046 1024 1049 1030 1024

'031 1045 1051 673

-12 0

623 853 INSTRUCTIONS On this I'ormat. list the average daily unit p wer icvel'n hl'6'c.Net for each day in thc reportin8 ntiinth. Compute to the nearest whole mcgawat t.

(9l77 l

11 AVERAGE DAILYUNITPOWER LEVEL DOCKET NO.

UNIT Brbtms Ferry 2

DATE

~ 10-'02-79 COMPLETED BY TELEPHOiiE 205/729-6846 hIONTH Se tember'979 DAY AVERAGE DAILYPOWER LEVEL (hI We-Net)

I 417 DAY AVERAGE DAlLYPOWER LEVEL (hIWe-Net)

~

455 17 3

7-10 12 13 14 15 16 939 1042 1043 1061 1065 1063 1024 1064 1061 1050 1063 1079 1038 676 836 18 19 20 21 22 23 24 25 26 27 28 29 30 31 701 913 1045 955 942 973 1023 1062 1083 1054.

1065 1058 1040 INSTRUCTIONS On this format,!Ist the average daily tu>it

>wer level in hive.Net for each day in the rept>rring n>>>nth. Ci>inputc to the nearest whole ntegawat t.

(')/77)

AVERAGE DAILYUNITPOWER LEVEL DOCKET NO.

50-296 DATE 10-'.2-79 COMPLETED IIY Ted Thorn TELEPHONE 205/729-6846 MONTH Se member 1979 DAY AVERAGE DAILYPOWER LEVEL (MWe-Net) 7

-7 10 DAY AVERAGE DAlLYPOWER LEVEL (i>IWe-Net)

-5 17 18 19 20 21 22 23 24 25 26 27 12 13 14 IS 16 28 29 30 31

-5 INSTRUCTI0>>IS On this format.!ist the avera8c daily unit I

> wer level'in >>IKVe Net for each day in the repi>rting utontlt. Ci>rnl>ute ti>

the nearest whole me8awat t.

(<)/771

13 OPERATING DATAREPORT a

DOCKET iNO.

DATE 10/002 79 COhIPLETED BY Doh Green TELEPHO//E 2005729 AEA6 OPERATli"IG STATUS

1. Unit iName:

Browns Perr 1

2. Reporting Period:

Se t.

1979

3. Licensed Thermal Power (hIIVt):

4. Nameplate Rating (Gross MWe):

5. Design Electrical Rating (Net IgIWe):

6. Igaximum Dependable Capacity (Gross siIWe):

7. IMaximum Dependable Capacity (Net III'IVe):

1098.4 1065 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 hIWe):

10. Reasons For Restrictions, IfAny:

N/A This hlonth Yr:to.Date Cumulative

'45. 289 5 868.29 26 099.88 258.88

~

4,658.01 25 441.'70 0

68,048,221 5 685 330 ~22. 03~330

'1 839 591 56.2 87.8 56.2 87.8

79. 3 45.3 "45.3 5.4 34.8 s

11. Hours In Reporting Period 720 6 551

12. Number Of Hours Reactor IVas Critical

13. Reactor Reserve Shutdown Hours 83.80

14. Hours Generator On-Line 621.52

~

5.750.36

15. Unit Reserve Shutdown Flours 0

16. Gross Thermal Energy Generated (hIWH) 1,766,350 17,275,549 l7. Gross Electrical Energy Generated (IIIVH)

18. Net Electrical Energy Generated (MWH)

19. Unit Service Factor 86.3

20. Unit Availability Factor

21. Unit Capacity Factor (Using MDC Net)

22. Unit Capacity Factor IUsing DER Net)

23. Unit Forced Outage Rate 13.7-

24. Shutdowns Scheduled Over Next 6 hlonths IType, Date. and Duration of Each):

Refuel Outa e November 1979

25. IfShut Down At End Of Report Period. Es(iuiated Date of Startup:

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

Forecast Achieved INITIAL CRITICALITY INITIAL ELECTRICITY COhlhl ERCIAL OPERATION e

(o/77)

14 OPERATING DATAREPORT i

DOCKET NO 0,1TP ~1-02-79 COtijPLETED BY Doh Green TELPPIIOiVE ~205 729-6846 OPERATING STATUS Notes

1. Unit 14me:

B t

F

2. Reporting Period:

Se tember 1979

3. Licensed Thermal Power (IIWt):

3293

4. Nameplate Rating (Gross 454(tVe):

5. Design Electrical Rating (Net 41IWe):

6. Maximum Dependable Capacity (Gross 41I)Ve):

e da le a acit Net i54I)Ve:

2 1098. 4 1065

7. Maximum Dep n b

C p y(

)

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

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

10. Reasons For Restrictions, IfAny:

N/A 11.

12.

13.

14.

15.

16.

17.

18.

19.

20.

21.

23:

24

~

Hours In Reporting Period Number Of Hours Reactor EVas Critical Reactor Reserve Shutdown Hours Hours Generator On-Line Unit Reserve Shutdown Hours Gross Thermal Energy Genented (ilBVH)

Gross Electrical Energy Generated (14I'LVH)

Net Electrical Energy Generated (MPH)

Unit Service Factor Unit Availability Factor Unit Capacity Factor (Using 194(DC Net)

Unit Capacity Factor (Usin DFR Net)

Unit Forced Outage Rate Shutdowns Scheduled Over Next 6 Months This 4~(onth 720 707.93

12. 07 Yr.-to.Date

,6 551 5 760.58 94.84 702. 10 5 639.64' 2,135 '510 16 0

,850,190 672,260 526 942 86;1 86.1 79.2 79.2 1.6 710,420 5

693 414 5

97.5 97.5 90.4 90.4

- 2.5-(Type, Date. and Duration of Each):

Cumulative

/40 200

- 22 478. 87 11,571.55

'21 707'6.50 0

60,301,978 19 986,048 19 417 106

'54. 0 54.0 45.4 45.4 38.6

25. IfShut Down At End Of Report Period. EE<<niated Date uf Startup:

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

Forecast Achieved INITIAL CRITICALITY INITIAL ELECTRICITY COiDIERCIAL OPERATION (o/77)

~f OPERATING DATAREPORT At DOCKET NO.

~ 0-2 6

DATE ~1-2-7 COhlPLETED BY Doh Green, TELF PHONE 20~572~6846 OPERATING STATUS Notes

1. Unit Name:

Brot~s Fer 3

3. Licensed Thermal Power (MIVt):

4. Nameplate Rating (Gross M'IVe):

5. Design<Electrical Rating (Net hive):

6. Maximum Dependable Capacity (Gross M>Ve):

a le a

t Net hive:

3293 1152 1065 1098.4 1065

7. Maxmtum Depend b

C pact y(

)

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

9. Power Level To which Restricted, lfAny (Net Mme):

10. Reasons For Restrictions. IfAny:

N/A 11.

~- '12.

13.

14.

15.

16.

17.

18.

19.

20.

21.

23.

24.

Hours In Reporting Period Number Of Hours Reactor Was Critical Reactor Reserve Shutdown Hours Hours Generator On-Line Unit Reserve Shutdown Hours Gross Thermal Energy Generated (M1VH)

Gross Electrical Energy Generated (hI'LVH)

Net Electrical Energy Generated (hkIVH)

Unit Service Factor Unit Availability Factor Unit Capacity Factor (Using hIDC Net)

Unit Capacity Factor (Using DFR Net)

Unit Forced Outa< c Rate Shutdowns Scheduled Over Next 6 hlonths This hlonth 720 Yr.-to.Date 6.551 Cumuhtive 22.655 0

5 224.60

~18 315.80 0

0 0

421.40

~5 174.05 0

1~"526. 81

.U,.M)4 Q3 0

0 0

0 0

g'f31,290

~5 "091~ 972 79.0 16 998 790 16 497 160 79'. 0 0

0 0

(Type. Date. and Duration of Each):

79.0

73. 0 73.0 8.4 79.0 68.4

68. 4 9.2 15,724f989 51 876 371

25. IfSltut Down At End Of Report Period. Estnuated Date of Startup.'6.

Units ln Test Status (Prior to Commercial Operationl:

November 21, 1979 Achieved forecast hVITIAL CRITICALITY INITIALELECTRICITY COhthIERCIAL OPERATION (o/77)

VNITSHVTDOWNS AND POWER REDUCTIONS REPORT MONTH~S-Eterither Browns Ferr 1

DATE 7

COMPLETED IIY TELFPIIONF 205/729-6846 No.

Dale Cr, n

CJ V) $

Licenscc Event

. Rcport 0

~

P CI Clo EA rn 6 Cl~

0Q Cl 0

Cause A, Corrective Action to Prevent Rc<<urrcnce 92 790901

32. 98 EHC (Turbine Control) Leak, 93 790903 i

F 14.32 Recirc Pump Problems, 94 790905 95 790915 96 790926 97 790926 98 790930 S

51.18 H

A A

2 Derated for control rod Pattern Ad'ustment.

I I

Derated for control 1;orl pattern ad]ustment and turbine ccc. rest and SX'S.

Derated when both recirc pumps isolated.

Main steam line temp switch malfunction.

Derated for control rod pattern ad ustment'c F: Fore<<d S: Schcdulcd

(')177)

Reason:

A Equipment Failure (Explain)

II hiainlenance or Test C.Refueling D Regulatory Restriction Ii Operator Trainingk Uccnsc Examination F.Adminis t ra t ive G Opera ill)nal Lrfof(Explatn)

I I Other (Explain) 3 hiethod:

I -hlanual 2-hianual Scram.

3.Autonlatic Scram.

4.Other (Explain)

Exhibit G - Instructions for Preparation oi'ata Entry Sheets for Licensee Event Report (LER) Pile (NOREG-OI 6 I )

5 Exhibit I - Salnc Source

UNITSIIUTDO'IVNSAND POPOVER REDUCTIONS DOCKET NO.

50-260 Ilrowns F~exr 2

DATp 10-2-79 COMpLETED II@

Don Green TpLppllONF 205/729-6846 No.

Date gw A

g -lY c/)

Licenscc Fvcnt Report Cause

&c Corrective Action to Prcvcnt Rccurrcncc 99 790901 8.42 B

1 Repair EHC oil leak.

100 790907 Derated for turbine control valve test and SI'S.

101 790914 S

H Derated for control rqd sequence exchange.

102 790917 9.48 G

3 Personnel error during performance of RX low-low water level SI F: Forced S: Schedule<I Reason:

A.Equipment Failure (Explain)

II.Illaintcnarlce or Test

'-I<et ucling D-Regulatory Restriction

- I!.Ot)erator Training &; License Examination F-Administrative G Operational Lrror (Explain)

I I.Other (I:xplaln) 3 Method:

I.Manual 2.Manual Scram.

3-Autolnatic Scram.

4.Other (Explain) 4 Exhibit G - Instructions for Prep'lratil)n or Data Entry Sheets Ior Liccnsce Event Rcport (LER) Fll~(NUREG-016I)

Exhibit I - Same Source

UNITSIIUTDOWNS ANDPOWER REDUCTIONS DOCKET NO.

UNITNAMF Brovns Ferr 3

DATE COhlPLETED IN Date V!

C7 A

rl Vlj Py

~V c

L Cl Lh:enscc Event Rcport ~

Cl~

O 2 ~

Q Cause 8. Corrective Action to Prevent Rccurrcnce 109 790901 S'20 Refueling F: Forced S: Scheduled

(')/77)

Reason:

A.l:quipment Failure (Explain)

D.hlaintcnance or Test C-Refueling D-Regulatory Restriction I!.Operator Training k, Liccnsc Examination F.Administrative G.Operational Error (Explain)

I I.Other (Explain)

Method:

I.hlanual 2 hhnual Scram.

3.Autoinat ic Scram.

4-Other (Explain)

Exhibit G - Instructions for Preparation of Data Entry Sheets I'or Licensee Event Rcpof t (LLrRL Filo(NOREG-Ol 6I )

5'xhibit I - Sante Source

BROWNS FERRY NUCLEAR PLANT UNIT 1

MECHANICAL MAINTENANCE

SUMMARY

DATE SYSTEM COMPONENT NATURE OF MAINTENANCE EFFECT ON SAFE OPERATION OF TfIE REACTOR CAUSE OF MALFUNCTION RESULTS OF MALFUNCTION ACTION TAKEN TO PRECLUDE RECURRENCE 9/4 Diesel Generator Diesel Gen.

B Oil low None Operation None Added oil I

9/18 Fire-Protectio Valve 1-26-956 Gearbox in wrong positioi I

None

,'nknown None Placed gearbox i correct position

CSSC E UIPMENT BROWS FERRY NUCLEAR PLANT UNIT 2

MECHANICAL MAINTENANCE SUGARY 9/4 SYSTEM RCIC COMPONENT RCIC Turbine NATURE OF MAINTENANCE Wheel nut stripped and wheel out of center posi-t/on EFFECT ON SAFE OPERATION OF TflE REACTOR None CAUSE OF MALFUNCTION Operation RESULTS OF MALFUNCTION None ACTION TAKEN TO PRECLUDE RECURRENCE Repositioned turbinr wheel and replaced carbon shaft seals and stripped nut.

Changed oil in turbine.

CSSC E UIPMENT EROMNS FERRY NUCLEAR PLANT UNIT 3

1'KQUDICAL MAINTENANCE

SUMMARY

DATE SYS TEM 9/1 RNRSW 9/6 ')eat and Vent COMPONENT D3 RHRSM pump 38 control bay chiller NATURE OF MAINTENANCE Pull and inspect pump TCV, outlet valve on line off of chiller EFFECT ON SAFE OPERATION OF THE REACTOR None None CAUSE OF MALFUNCTION None Unknown RESULTS OF MALFUNCTION None None ACTION TAKEN TO PRECLUDE RECURRENCE Inspected

pump, greased bottom bea"ing housing Adjusted valve 9/16 CRD CRD accum.

46-27 Diaphragm flange leak None Operation None Tightened flange 9/16 CRD CRD accum.

50-23 Diaphragm flange leak None Operation None Tightened flange

BROWSE PERRY NUCLEAR PLANT UNIT 1

.'LECTRICAL MAINTENANCE SIMiARY For the Month of Sep ember 19 79 Date System Component Nature of Maintenance E

ect on a e Operation of The Reactor Cause of Malfunction Results of Malfunction Action Taken To Preclude Recurrence 9-2-79 Reactor Core isola tion cooling 1 FGV 71-3'teamsupply isolation valve motor Will not close Not applicable from hand switch Failed motor Valve inoperable Replaced motor, performed EMI 18, tested OK.

TR 1358 LER BFRO 50-259/792 9-6-79 250V DC Battery board Ijl 250V ground indicated Not applicable Broken connec-tion on RCIC

'turbine speed pickup for elec-tronic overspeed (SE 71-42B)

Ground Replaced connector, cleared

ground, checked OK.

TR 13582 9-10-79 Fire protection Power supply.

transformer for system annunciator (XA-55-8E)

Transformer burned up Not applicable-Trans former burned up and 3 failed resis-tors Annunciator inoper-able Replaced power supply and 3 resis-

tors, checked OK.

TR's 122495, 111778.

and BFRO 50-259/7922 9-12-79 Air con-ditioning Emergency 'con-trol bay chiller Broken oil Not applicable line Broken line from chiller to oil filter Leaking oil Replaced line, checked OK.

TR 125579 9-13-79 Air con-ditioning 1B control bay chiller Will not time properly Not applicable Failed recycle timer Chiller will not operate properly Replaced timer, checked OK.. TR 125569

CSSC E UIEMNT ERURRS FERRY NUCLEAR PLAIT URXT 2

ELECTRICS MAINTENANCE S l&1MARY For the Month of 1979 System Component Nature of Maintenance ect on a e Operation of The Reactor.

'ause of Malfunction Results of Malfunction Action Taken To Preclude Rocurrence Control rod drive HS-85-48 Switch. failed Not applicable Broken stop-plate Switch inoperable Replaced stop-plate,'ested OK.

TR 122368

CSSC E UIEMNT EROt'NE FERRY NUCLEAR PLANT UNIT ELECTRICAL MAINTENANCE Slk&fARY For the Month of September 19 79 Date System Component Nature of Maintenance ect on a

e Operation of The Reactor Cause of Malfunction Results of Malfunction Action Taken To Preclude Recurrence 9-17-79 Standby liquid con trol TC-63-5A SLC suction line thermostat Failed thermo-Not applicyble stat Thermostat out of calibration Thermostat would not control temperature properly Replaced thermostat calibrated by IM's, checked OK.

TR 140554 9-18-79 Primary contain-ment 64-8 damper motor Damper would.

not operate properly Not applicable Failed damper motor Damper would not operate properly Replaced motor, tested OK.

TR 123267 9-19-79 Ventila-tion Shutdown board emergency supply fan 3B Fan inoperable Not applicable Motor pulled due

'to upper guide bearing damage Fan inoperable Motor removed on; 8/24/79 and sent to service shop for.

repairs.

Repaired and returned.

Re-installed on 9/24/79 and returned to ser-.

vice, checked OK.

TR 122999 9-20-79 Control rod drive 3 FSV-85-39A (CRD scram pilot valve)

Failed coil Not applicable Solenoid burned'p Pilot valve inopera-Replaced coil, tive tested valve OK.

TR 142319 9-22-79 Reactor water cleanup 3 FCV-69-2, Replace torque Not applicable switch Failed torque switch Valve would not operate properly dur ing LLRT Replaced torque switch, performed EMI 18, checked OK.

TR 135166 9-26-79 Diesel generators 3ED D/G air compressor "B"

Compressor inoperable ot applicable Loose coil wire Compressor would not Tightened coil wire,-'

start checked OK.

TR 124642

BROWNS FERRY NUCLEAR PLANT ~ UNIT~

OHHON INSTRKKNT MAINTENANCE SUGARY DATE SYSTEM COHPONENT-NATURE OF MAINTENANCE EFFECT ON SAFE OPERATION OF TIIE REACTOR CAUSE OF MALFUNCTION RESULTS OF ILQ.FUNCTION ACTION TAKEN TO PRECLUDE RECURRENCE Unit "ommon Unit 2 9-11 MR Service Water

.Control Rod Drive PI-23-4 PI-23-18 PI-85-14 Pl-85-26 Calibration Repair None None Instrument drift Vibration Did not agree with redundant indicator Pointers bent, one fell off None None E

9-12 9-20 Radiation RH-90-251

=Honitoring Radiation Rf-90-251 Honitoring Repair Repair None None Broken lead on drive source motor (particu-late) broken string on gas source drive Bad alarm card Could not source check Alarm light would not clear None None Unit 3 9-30 Radiation Monitoring RH-90-250 Repair None Loose source drive cord Would not source check satisfactorily None

26 OUTAGE SECTION MONTHLY REPORT (Continued)

September 1979 Core spray piping changeout from stainless steel to carbon steel started September 14.

The changeout will remove stainless steel down to"the first check valve within the drywell.

Several indications were found on the safe end and a weld downstream of the core spray check valve.

These are being investigated to determine if they are stress corrosion cracks.

This work is presently projected to be very close to critical path.

Relief valve tailpipe for subsequent installation of relief valves is being installed this outage.

Two tailpipes will be routed from the main steam line header down to the end of the vent header.

,This will allow installation of tailpipe in the torus during the next torus work outage.

This work was approximately 40 percent complete at the end of the month.

The primary containment leak rate testing is complete and repairs complete on all but about 10 valves.

The main steam isolation valves were done in approximately 19 days.

Of the 129 primary containment leak rate test valves, approximately 30 percent failed the initial leak test criteria and required repair work.

The "B" feedwater line valve and associated RWCU valves required extensive repair work.

In order to test and repair the "B" feedwater line with the reactor water cleanup system in service a crosstie from the RWCU to the "A" feedwater line is being installed this outage.

An additional crosstie valve betw en RHR loop I and II has been started.

The crosstie will allow doing ma'ntenance on the other crosstie valves and still preserve loop integrity.

27 OUTAGE SECTION MONTHLY REPORT September 1979 At the end of September, the Unit 3 refueling outage was 38 days old and the critical path was approximately 8 days behind schedule.

The feed-water sparger modification work being done by General Electric and TVA personnel was started September 14, 1979. 'his work is projected to be completed approximately October 20, 1979.

The bulk of the inspection and repair work on the low pressure turbine sections B and C were completed.

The "B" contxol, intercept and stop valves were pulled for maintenance.

The number an 4

5 6

7 8

d 9 by ass valves were disassembled and reassembled.

P Investigation of cavitation problems on the Unit 3 feedpumps xevealed major cavitation damage to each feedpump's impeller {'outboaxd).

The "B" reactor feedpump was disassembled, inspected, and reassembled.

{See Mechanical Maintenance Report Section.)

The main generator rotor was removed this refueling outage fox inspection and testing.

A stator coolant leak was detected and repaired.

.. The majority of the feedwater heater and condensex leak checks have been completed and leaks repaired.

Vacuum leak checks and eddy current inspections were ma e o de f high and low pressure

heaters, condenser water

boxes, RHR heat exchanger "D", offgas condenser, main turbine oil tank X

~

e l>A4<t cooler and EHC cooler.

Modifications to the subcooling zone xn the and "B4" heaters was started.

Most of the raw cooling water coolers were also cleaned.

Inspections on the CCW pump pits did not reveal an extensive built'~ p of clams nor were any unusual circumstances foun

.d.

The "A" it p

circulating water pump motor was repaired at, the service shop and xeinstalled.

e 28 OUTAGE SECTION MONTHLY REPORT (Continued)

September 1979 LPCI logic changes were star'ted..

The LPCI modification installs a

battery room for unit 3 and installs LPCI logic similar to that in Units 1 and 2.

New reactor motor operated valve boards are being installed and eventually motor generator sets will be installed.

The LPCI logic work is expected to be complete by the middle of October and surveillance testing requirements will add another two to three weeks to this work.

Three General Electric transformers have been removed from their installation pad and ASEA transformers pulled in their place.

Vacuum was being pulled on the "A" phase ASEA transformer at the end of the month.

The General Electric transformers are bound for Hartsville.

Electrical board maintenance is approximately 80 percent complete at the end of the month and all the ma)or motor testing was completed.

The inspection of the recirculation MG sets and recirculation pump motors "A" and "B" was completed.

General Electric xechnical assistance was r

available during this maintenance work.

Re'actor protection system motor-generator maintenance was started and cable inspection on the EHC system was completed.

Modification work, both inside and outside the reactor building, is underway.

The hypochlorite plant installation and security modifications are the most significant outside modifications underway.

TIP indexer and drive maintenance is well underway and should be complete in early October.