ML18024A486

Forwards Monthly Operating Repts for Sept 1978

ML18024A486
Person / Time
Site:	Browns Ferry
Issue date:	10/10/1978
From:	Dewease J TENNESSEE VALLEY AUTHORITY
To:	NRC OFFICE OF INSPECTION & ENFORCEMENT (IE)
Shared Package
ML18024A487	List: ML18024A486 ML20058A099
References
NUDOCS 7810160106
Download: ML18024A486 (45)

Text

f j<

Qo<?e5 j

REGULATORY FORMATION DOCKET NBR:

~

g Cog RECIPIENT:

NOID ORIGINATOR:

DEWEASE J.G.

EUTTVA COMPANY NAMEZ'N VALLEY AUTH

SUBJECT:

DISTRIBUTION TEM DOC DATE:

781PlP ACCESSION NBR:

COPIES RECEIVED:

LTR 1

SIZE:

1+34 Forwards Monthl 0 er Re t for Se t 1978.

PISTRTBUT ION COPE)

AOOB DISTR I BUT IOh'ITLEt AtJhiUAI SEBI ANNUAL L MONTHLY OPERATING RPTS (OL STAGE)

ENCL?

FOR ACTION BR H

F R'Etr F

I E

MIPC HANAQFR DIRECTOR PDR AD FOR, SYS 8

PROJ ENGINFERING PR REACTOR SAFETY BR PLANT SYSTEMS BR EFB CORE PERFAR~1ANCE BR EFFLUENT TREAT SYS LPOR NATL I 48 TERA NSIC BROOKHA"EN ACRS 4t//.N NCL 8/2 FNCg

"'/2 E NCL V/ENCL W/ENCL

'H/ENCL N/ENCL W'/E NC L

~/ENCL

~/ENCL

>/ENCL

~/ENCL W/ENCL 4/ENCL I</ENCL

~'/ENCL

</ENCL

</15 ENCL B GRIMES ORBN3 BC R J CLARK ORBN3 LA TOTAL NUHBER OF COPIES REQUIREPt I

LTR ENCL NOTES:

a

Brovns Ferry Nuclear Plant P.

O. Box 2000

Decatur, Alabama 35602 OCT l0 )978 Nuclear Regulatory Commission Office of Hanagement Tnformation and Program Control Washington, DC 20555 Gentlemen:

Enclosed is the September 1978 lRnthly Operating Report for Browns Ferry Nuclear Plant Units 1, 2, and 3.

Very truly yours, TENNESSEE VALLEY AUTHORXTY J.

G. De+ease Plant Superintendent Enclosure cc:

Director, Region II Nuclear Regulatory Commission Office of Xnspection and Enforcement 230 Peachtree

Street, NW Suite 818

'w

Atlanta, GA 30303 {1 copy)

Director, Office of inspection and Enforcement, Nuclear Regulatory Commission Washin ton DC 20555 (10 co ies

TENNESSEE VALLEY AUTHORITY DIVISION OF POWER PRODUCTION BROWSES FERRY NUCLEAR PLANT MONTHLY OPERATING REPORT September 1,

1978 September 30, 1978 DOCKET NUMBERS 50-259, 50-260, and 50-296 LICENSE NUMBERS DPR-33, DPR-52, and DPR-68 Submitted by ant Superintendent

TABLE OF CONTENTS Operations Summary

~

~

~

Operational Data

~

~

~

Maintenance

~

~

~

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

Plant Maintenance Summary.

~

~

~

3

~

~

~

5

~

~

~

lQ

~

~

o

] 3

~

e

~

~

~

o l9 Unit 3 Refueling Outage Summary.

~

~

o 3l

0 erations Summar The following summary describes the significant operational activities during the reporting period.

Zn support of this summary, a chronological log of significant events is included in this report and begins on page 5

There were 6 Reportable Occurrences reported to the NRC during the month of September.

Unit 2 Significant operational events for unit 1 are tabulated by date and time beginning on page 5

The unit scrammed five times during the month of September.

The unit was manually scrammed on September 3 and 9 to investigate high drywell leakage.

On September ll the reactor scrammed on APRM high flux due to a recirculation flow spike caused by an unexplained sudden ramp in "B" recirculation pump speed.

The unit was manually scrammed on September 14 due to recirculation flow problems found to be caused by FCV 68-3.

On September 20 the unit scrammed with no generator load during turbine warming due to turbine first stage pressure exceeding the 30% power bypass for turbine stop valve closure trip.

From September 23 to September 29 power was limited to 50%.thermal power by the technical specifications, awaiting further analysis for single loop operation.

After September 29, power was administratively limited by 50% "B" recircula-tion pump speed, with "A" loop out of service.

A summary of maintenance work is shown on pages 19 through Unit 2 Significant operational events for unit 2 are tabulated by date and time beginning on page 7.

There was one scram during the month.

On September 29 the reactor was manually scrammed to investigate drywell leakage and to repair drywell equipment drain sump pumps.

~

)

~

0 era tions Summar (Con')

Unit 2 (Conht)

A summary of maintenance work is shown on pages 19 through 30.

Unit 3 Significant operational events for unit 3 are tabulated by date and time beginning on page 9.

The unit scrammed once during the month of September.

The reactor was manually scrammed on September 8 to accomodate the scheduled refueling outage.

A summary of maintenance work is shown on pages 19 through 31.

Common S stems On September 21, a head gasket failed on the radwaste waste filter.

The filter was repaired and returned to service within ~ 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

Approximately 8.1 E+5 gallons of waste liquid were discharged containing approximately 6.9 E-1 curies of activity. It is estimated that the use of auxiliary boiler steam during unit outages contributed 6.0 E+5 gallons of demineralized water to radwaste.

Cooling towers 1, 2, 3 (until September 18) and 6 were operational this 4

month for two lift pump operations.

Modifications by the tower vendor were begun on Tower 3 on September 18.

None of the towers had significant operational problems.

0 erational Data The average daily unit power level for units 1, 2, and 3 is shown on pages 10 through 12.

The operating data reports for all three units are shown on pages 13 h

through 15.

Unit shutdowns and power reductions for all three units are shown on pages 16 through 18.

-2a-Maintenance Major electrical, mechanical, and instrument maintenance activities during the month are described on pages 19 through 30.

Refueling outage activities for unit 3 are summarized on page 31.

Refuelin Information Unit 1 Unit 1 is scheduled for its second refueling beginning on November 10, 1978, with a restart date of December 20, 1978.

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 in August 1978.

This refueling will load additional 8 X 8R (retrofit) fuel assemblies into the core, replacing presently loaded 7 X 7 fuel and will involve installing a new recirculation pump trip (RPT) system.

There are 764 fuel assemblies in the core.

The spent fuel storage pool presently contains 168 spent fuel assemblies and 156 new fuel assemblies.

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 refueling later in 1978 would be the last refueling that could be discharged to the spent fuel storage pool without exceeding that capacity and maintaining full core discharge capability in the pool.

Unit 2 Unit 2 is scheduled for its second refueling beginning on April 22, 1979, with a restart date of July 1, 1979.

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

Present scheduling is to submit licensing information in support of these changes before the refueling.

This refueling will involve replacing some more 7 X 7 fuel

,assemblies with 8 X 8R (retrofit) assemblies.

There are 764 fuel assemblies in the core.

At the end of September there were 132 discharged cycle 1 fuel assemblies in the spent fuel storage pool.

There are presently 36 new 8 X 8 fuel assemblies in the spent fuel storage pool which were not loaded into the core. during this cycle.

The present storage capacity of

Refuelin Information (Con't)

Unit 2 (Con't) the spent fuel pool is 1080 assemblies.

Present planning is to increase that capacity to 3471 assemblies.

Pith 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 first refueling on September 8, 1978, with a scheduled restart date. of October 31, 1978.

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 in July, 1978.

This refueling involves replacing some of the present 8 X 8 fuel assemblies with 8 X 8R (retrofit) assemblies, modifying the main steam relief valves to increase simmer margin, and installing a new recirculation pump trip (RPT) system.

There are 764 cycle 1 fuel assemblies in the spent fuel storage pool.

There are 208 new 8 X 8R (retrofit) assemblies present in the spent fuel storage pool.

The present licensed storage capacity of the spent fuel pool is 1132 assemblies.

Si nificant 0 erational Events'ate Time Event 9/1 0000 Unit 1 Reactor thermal power at 86%,

sequence B, holding CPR limited.

2230 Reduced thermal power from 86% to 73% for removal of "B" recirculation pump MG set from service for brush replacement and turbine CV tests and SI's.

9/2 0015 Turbine C.V. tests and SI's completed, holding at 73% thermal power for "B" recirculation pump MG set brush replacement.

0115 "B" recirculation pump MG set brushes replaced and pump placed in service.

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

0250 "A" recirculation pump HG set brushes replaced and pump placed in service.

9/3 0255 1500 2200 Commenced power ascension from 73% thermal power.

Reactor thermal power at 85%,

CPR limited.

e Commenced reducing thermal power from 85% for removal of unit from service for drywell maintenance to valve FCV-69-1 (excessive drywell leakage).

2245 Reactor scram no.'7 (manual) from 40% thermal power to accomodate drywell maintenance to FCV-69-1.

9/5 2210 Maintenance to valve FCV-69-1 completed, commenced rod withdrawal.

2335 Reactor critical no.

109.

9/6 0200 Reactor made subcritical with RPV at 1000 psi, holding for drywell entry for leak checks.

0340 0355 0725 Leak checks completed, resumed startup.

Reactor critical no. 110.

Rolled T/G.

0757 Synchronized generator, commenced power ascension sequence "B".

Si nificant 0 erational Events Date Time Event Unit 1 (continued) 9/7 1230 Reduced thermal power from 72/ to 66% due to "B" recirculation pump trip during valve backseating operations.

1255 "B" recirculation pump returned to service commenced power ascension from 66% thermal power.

'/8 0930 Commenced PCIOHR from 75% thermal power.

9/9 1945 Commenced reducing ther'mal power from 86% for shutdown due to excessive drywell leakage.

FCV 68-77 leaking.

2115 Reactor scram no.

98 (manual) from 42% thermal power to accommodate maintenance.

9/10 1630 1759 1faintenance completed, commenced rod withdrawal.

Reactor critical no.

111.

2008 Rolled T/G.

2022 Sychronized generator, commenced power ascension, sequence "B".

9/11 0530 1226 1415 Commenced PCIOIK from 67/ thermal power.

Reactor scram no.

99 from 73% thermal power on (1)

APRM h'i hi flux:-, Recirculation pumps ramped up.

Commenced rod withdrawal.

1515 1702 Reactor critical no.

112.

Rolled T/G r

9/12 1725 0015 Synchronized generator, commenced power ascension sequence "B".

Commenced PCIOMR from 66% thermal power.

1703 Reduced thermal power from 90% to 80% due to "A" recirculation pump run back.

2332 Commenced reducing thermal power from 80% for shutdown due to flow problems on recirculation pump loop "A" (valve FCV 68-3 broken disc).

l

Si nificant 0 erational Events Date Time Event Unit 1 (continued) 9/14 0041 Reactor scram no.

100 (manual) from 40%

thermal power to accommodate maintenance.

2020 Unit at cold shutdown.

9/20 0545 Haintenance outage completed, commenced rod withdrawal.

0625 Reactor critical no. 113.

0700 0820 0835 1542 Reactor subcritical due to rod block.

Rod block cleared, commenced rod withdrawal.

Reactor critical no.

114.

Reactor scram no.

101 30% power/pressure setpoint (2) inadvertently reached during turbine steam chest warmup from 5% thermal power 9/21 1655 1740 0030 Commenced rod withdrawal.

Reactor critical no. 115.

Rolled T/G.

9/23 0102 1500 Synchronized generator, commenced power ascension.

a Reactor thermal power at 50%, holding due to "A" recirculation loop out of service (pump discharge valve 68-3 inoperable).

9/29 1825 Commenced power ascension from 50% thermal power with rods.

9/30 0900 Reactor thermal power at 56%.

2400 Reactor thermal power at 56%, holding due to "A" recirculation loop out of service.

Unit 2 9/1 0000 Reactor thermal power at 95% sequence "A" core flow limited.

2355 Reduced thermal power from 95% to 90% for turbine C.V.

tests and SI's.

Si nificant 0 erational Events Date Time Event Unit 2 (continued) 9/2 0100 Turbine C.V. tests and SI's completed, commenced power ascension.

0400 Reduced thermal power from 96% to 35% for brush replacement of both recirculation pump MG sets and control rod sequence exchange from "A" to "B".

0716 Brush replacement of both recirculation pump 1fG sets completed, holding for. control rod sequence exchange.

0800 Control rod sequence exchange from "A" to "B" completed, commenced power ascension.

1500 Commenced PCIOEK from 68% thermal power.

9/5 0600 Reactor thermal power at 97%, core flow limited.

9/6 9/7 1500 1500 Reactor thermal power at 96%, core flow limited.

Reactor thermal power at 96%%u, core flow limited.

9/11 1620 Reduced thermal power from 96%%u to 92/ due to one-half isolation on "B" main steam line while performing SI.

1640 One-half isolation on "B" main steam line cleared and

reset, commenced power ascension.

2300 Reactor thermal p'ower at 96% core flow limited.

2320 Reduced thermal power from 96% to 70% for turbine C.V. tests and SI's.

9/12 0144 Turbine C.V. tests and SI's completed commenced power ascension.

0255 Reactor thermal power at 96% core flow limited.

9/16 2325 r

Reduced thermal power from 96% to 70% for turbine C.V. tests and SI's.

9/17 0045 Turbine C.V. tests and SI's completed commenced power ascension from 70% thermal power.

0330 Commenced PCIO~R from 90/ thermal power.

2300 Reactor thermal power at 95%, core flow limited.

Si nificant 0 erational Events Date Ttme Event 9/22 2235 Unit 2 (continued)

Reduced thermal power from 95% to 90% for turbine C.V. tests and SI's.

9/23 0100 Turbine C.V. tests and SI's completed, commenced PCIOMR from 90% thermal power.

1800 Reactor thermal power at 97% core flow limited.

9/24 1350 Reduced thermal power from 97% to 90% for removal of "B" string high pressure feedwater heaters from service for leak checks.

9/25 2/20 Leak checks completed on "B" string high pressure heaters.

9/26 2130 1645 Commenced PCIONR from 90% thermal power.

Reactor thermal power at 97% core flow limited.

9/29 2100 Commenced reducing thermal power from 97% for scheduled outage.

2315 Reactor scram no.

71 (manual) from 40% thermal power for scheduled outage.

9/30

'400 Reactor shutdown in hot standby mode.

9/1 0000 Unit 3 Reactor thermal power at 67%, administrative hold due to vacuum switch grounding problems. of T/G.

9/7 0545 Commenced power ascension from 67% thermal power.

1500 Reactor thermal power at 77%.

9/8 2200 Commenced reducing thermal power for shutdown for refueling outage.

.2300 Reactor scram no.

65 (manual) from 40% thermal power to accommodate refueling outage.

9/14 1945 Commenced removing fuel assemblies from reactor vessel to fuel pool storage.

9/25 1400 Completed removing fuel from reactor vessel to fuel pool storage.

9/30 2400 Refueling outage in progress with all fuel assemblies in the fuel pool storage.

(1)

Equipment malfunction.

(2)

Operator error.

~

~

~

~

. "AVERAGE DAlLYUNITPOWER LEVEL DOCKET NO.

DATE COMPLETED BY Browns Ferry I

'0/5/78 TELEpHONF 205/729-6846 MONTH DAY AVERAGE DAILYPOWER LEVEL (MWe-Net) 894 801 821 DAY AVERAGE DAILYPOWER LEVEL (MWe.Net )

-8 17 18 19 4

10 12 13 14 IS 16

-13 237 653 772 744 43 464 763 859 20 21 22 23 24 25 26 27 28 29 30 31

.10 465 468 477 477 473 487 503 549 INSTRUCTIONS On this format, list the avcragc daily unit popover Icvcl in hIIVc-Nct for each day in the rcportinp nuinth. Compute to

'he nearest whole ntc+a'o'alt.

(')t77l

0

~

AVERAGE DAILYUNIT POWER LEVEL DOCKET NO.

50-260

~

Browns Ferry IT.

DATE COMPLETED BY TELEPHONE 205/729-6846 hjONTH S

DAY AVERAGE DAILYPOWER LEVEL (MWe-Net }

I 1031 681 17 IS 1032 DAY AVERAGE DAILYPOWER LEVEL (hiWe Net) 1030 3

4 S

9 10 12 13 14 15 16 829 991 1003 1020 1041 1012 1031 1043

, 1010 1005 1011 1016 1028 1010

)9 20 21 22 23 24 25 26 27 28 30 31 1024 1019 1013 1037 1008 1002 961 1030 1058 1055 991

-10

i. ~

INSTRUCT(ONS On this format. !ist thc average daily unit power Icvcl in hive.Yet for each dayiit tltc rcportinc ltlontll.Cr)tnputc to

'"the nearest whole ntcjawat t.

(')(77 I AVERAGE DAlLYUNITPOWER LEVEL DOCKET NO.

UNIT Brovns 1erry gpss DATE 10/5/78 COMPLETED BY TELEPHONE Don Green Se tember 1978 DAY AVERAGE DAILYPOWER LEVEL (MWe-Net)

I 673 684 DAY AVERAGE DAlLYPOWER LEVEL (MWe-Net) 17 18 3

10 12 13 14 15 678 685 685 659 742 772

-10 19 20 21 22 23 24 25 26 27

.28 29 30 31

-6

-3 INSTRUCTIONS On this format.!ist the tveragc dail)'ttlt Intiver Iei'cl in MIVe-Net for eaelt day itt the repnrtin i tnontlt. Compote to the nearest whole megawatt.

(')/77 l OPERATING DATAREPORT OPERATING STATUS

1. Unit Name Bro~rts Ferry I p

d September 197

2. Reporting Period:

3. Licensed Thermal Power (hIWt):

4. Nameplate Rating (Gross hilVe):

5. Design Electrical Rating (Net MWe):

1065

6. hlaximum Dependable Capacity (Gross hllVe): 10. 8 Notes DOCKET KO.

DATB 10 5

7 COMBLBTBD BY Dnn Green-TELEPHONE ~LZ2~-6846

7. hl'aximum Dependable Capacity (Net hIWe):

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

9,-Power Le'vel To lVhich Restricted. IfAny (Net hllVe):

10. Reasons For Restrictions, lfAny:

This hionth Yr.-to-Date Cumulative

'l.

12.

13.

~

14.

.... 15.

16.

17.

18.

19.

20.

21.

22.

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 Ener y Generated (M'lVH)

Gross Electrical Energy Generated (M)VH)

Net Electrical Energy Generated (hI)VH)

Unit Service Factor Unit AvaihbilityFactor Unit Capacity Factor (Usi>>g hlDC Net)

Unit Capacity Factor (Using DER Net)

Unit Forced Outa e Rate Shutdowns Scheduled Over Next 6 hlonths (Type.

Refuel.outage

November, 1978.

720 492.42 225.76 6551 5885. 83 352. 33 0

0 944 359 15 778,415 t

280 607 5 t)12 892 64.8 86.7

86. 7 64.8 36.6 71.9 36.6 71.9 7.4 35.2 Date. and ()uration of Each):

466.35

'649.33 36529 18865.71 4;399.13'

~

48,151,644 15,501,239 50.?

50e2 3o.8 41.9 25.. IfShut Down At End Of Report Period. Estimated Date of Startup:

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

Forecast Achieved INITIAL CRIT ICALITY QNITIAL ELECTRICITY COhlh)ERCIAL Ol'ERATION

(')/77)

OPERATING DATAREPORT DOCKET NO.

DATE 10 00MELEyED Dy ~Don rneeen ELEPHOqE ~)f~-6846 OPERATING STATUS Notes Unit Name Broterns Fer II

2. Reporting Period:

Se t:ember 1978

3. Licensed Thermal Power (hIWt):

4. Nameplate Rating (Gross hlWe):

5. Design Electrical Rating (Net hIIVe):

6. Maximum Dependable Capacity (Gross sbllVe):

7. Maximum De cndableCa acit Net s~OVe:

1098 1065 p

p

)(

)

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

9,-Power Level To IVhich Restricted, IfAny (Net MN'e):

10.'Reasons For Restrictions, IfAny:

Il 12.

13.

14.

.. IS.

16.

17.

18.

19.

20.

21.

22.

23.

24.

This Month Yr.-to-Date 213.22 0

3 500,060 3,388,119

48. 6 Hours In Reporting Period Number Of Hours Reactor Was Critical Reactor Reserve Shutdown Hours Hours Generator On-Line 695.25 3900.55 Unit Reserve Shutdown Hours 0

Gross Thermal Energy Generated(hllVH) 143 937 10 737 187 Gross EleetrlealEner y Generated pttVH)

'~715 420 Net Electrical Energy Generated (MNH) 696,458 Unit Service Factor Unit AvailabilityFactor

96. 6 Unit Capacity Factor (Using hlDC Net)

90. 8 Unit Capacity Factor (Using DER Net)

90. 8 Unit Forced Outage Rate Shutdowns Scheduled Over Neit 6 hlonths (Type. Date.'and duration of Each):

Cumulative

33. 440 14,573.01

.:H,4T2. t39 0-36,910,324 12,097,010 35.0 25:. IfShut Down At End Of Report Period. Estimated Date of Startup.'6.-

Units In Test Status (Prior to Commercial Operation):

Forecast Achieved INITIAL CR IT I CA LITY

,)NITIAL ELECTRICITY COhlhlERCIAL OPERATION (tl/77)

~

i

~

1

'i' OPERATING DATAREPORT DOCKET NO.

DATE COhIPLETED BY TELEPHONE OPERATPNG STATUS Notes

1. Unit Name' w

F ITI

2. Reporting Period:

Sent-ember 1978

3. Licensed Thermal Power (MWt):

4. Nameplate Rating (Gross hIIVe):

5. Design Electrical Rating (Net hIWe):

6. hlaximum Dependable Capacity (Gross hIWe): 109 De endable a acit Net hIWe:

7. hlaztmum p

C p y (

)

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

'. Power Level To Which Restricted, lfAny (Net MWe):

10. Reasons For Restrictions, IfAny:

ll 12 13 14 15.

16.

17.

18.

19.

20.

21,

~ 20 23.

. 24.

This Month Yr:to-Date 6551 ".

5,503.25 S415.34 15,421,038 5,044,43D 4 886 896 82.7 82.7 70.0

.0 9.5 Hours In Reporting Period Number Of Hour>> Reactor Was Critical 191.0 Reactor Reserve Shutdown Hours Hours Generator On-Line Unit Reserve Shutdown Ilours. --

Gross Thermal Energy Generated (hIWH)

Gross Electrical Energy Generated (hIWH)

Net Electrical Energy Generated (MWH)

Unit Service Factor Unit AvailabilityFactor Unit Capacity Factor (Using MDC Net)

Unit Capacity Factor (Using DER Net)

Unit Forced Outage Rate Shutdowtts Scheduled Over Neit 6 htonths (Type, Date, and ()uration of Each):

Cumulative 13,895 12,198.92 11914; 65 0

34,062,732 11,078,300 10,737,802 85.7 85.7

72. 6 9.

n

25. IfShut Down At End Of Report Period. E>>timated Date of Startup:

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

Forecast Achieved INITIAL CRITICALITY

,$ NIT I A L ELECTRICITY COMhIERCIAL OPER:KTION

( t/77)

/

I I.

I UNITSHUTDOWNS AND POWER REDUCTIONS I

DOCKET NO.

UNITNAME DATE COMPLETED BY TELEPI IONE 5n-25o ln 5 Don t'reen n

)8 Datlr L

tS O

J g cc PI V)

Liccnscc

~

Eve n't Rcport ¹ c~

o ~O C Q 0

Cr Cause A Corrective Action to Prevent Rccurrcnce 50 780903 57.2 A

2 Maintenance Outage to repair FCV-69-1 and identify leakage of FCV-68-77.

52 l

53 I

780911 780914 51 780909 23.12 4.98 159.02 A

2 A

3 A

Maintenance Outage to identify leakage into drywell (FCV-68-77).

Rx scram due to hi hi APRM flux.

Recirc. flow problems due to trouble with FCV-68-3.

54 780920 9.33 Rx scram on turbine stop valve closu're signal (pressure setpoint inadvertently reached during turbine chest warming).

F: Forced S: Scheduled

('>/77)

Reason:

A-Equipmcnt Failure (Explain)

'B.Maintenance or Test C-Rcfucling D.Regulatory Restriction E.Operator Training &, Uccnsc Examination F-Adlnlnistrat tvc G.Operational Error'(Explain)

I I Other (Explain) 3 Method:

I-Manual 2-Manual Scram.

3-Automatic Scram.

4.Other (Explain) 5 Exhibit G - Instructions for Preparation of Data Entry Sheets lor Licensee Event Report (LER) File (NUREG.

OI6l )

Exhibit I - Satne Source

I

'h

UNITSHUTDOWNS AND POWER REDUCTIONS I

I DOCKET NO.

UNITNAME DATE COMPLETED BY TELEPIIONE 50-260 Brovns Ferrv TE 10-5-7A 905 o-6Al Datl.

L + ~J

- 6C

~ Ch r Licenscc

~

Event Report >

~Ill Cp T7 E~

O Cause A. Corrective Action to Prevent Rccurrcncc 61 780902 S

Derated for control rod sequence'xchange from A to B.

62 l'3 780911 780916 S

Derated for turbine control valve test and SZ's.

Derated for turbine control valve test and SI's.

64 780929 F

24.75 A

Investigation of unidentified leak-age into drywell and repair to drywel equipment drain sump pump.

I',

F: Forced S: Scheduled

(')/77)

I I

L Rea sun:

A-Equipment Failure (Explain)

B Maintenance or Test C-Rel'ueling D Regulatory Restriction 8 Operator Training 8; Liccnsc Examination F-Admrnistrativc G.Opcralronal Error'(Explain)

I I.Othc r (L'xpiain) 3 Method:

I Manual 2 Manual Scram.

3-Automatrc Scram.

4.Other (Explain)

Exhibit G - Instructions for Preparation of Data Entry Sheets for Li<<cnsee Event Rcport (LER) File (NVREC-OI6I) 5 Exhibit I - Satnc Source

UNITSIIUTDOWNS AND POWER REDUCTIONS DOCKETNO.

UNITNAME DATE.

. COMPLETED BY TELEPI{ONE st)-296.

Hrotrns Ferr XII 2rt5-72rt RRI

{fate I

0 A.J

~ Vl Licensec

~

Event Report 4 C0 Eu o

Cause & Correitivc Action to Prevent Recurrence 780908 S

529 C

F: Forced S: Scheduled

{9/77)

Reason:

A.Equipment Failure (Explain) 8 Maintenance or Test C.Refueling D Regulatory Restriction F..Operator Training &, Liccnsc Examination I -Adn>inistrative G-Opi:rational Error {Explain)

I I Other {Explain) 3 Method:

I.Manual 24{anuai Scram.

3-Automatic Scram.

4.0tl>cr (Explain) 4 Exhibit G - Instructions for Preparation of Data Entry Sheets for Licensee Event Report {LLR)File {NUREG.

Ol 6I )

5 Exhibit I - Sa*ntc Source

CSSC E UIPMENT BROWNS FERRY NUCLEAR PLANT UNIT COMMON MEQMNICAL MAINTENANCE SULTRY Eof the EPgfh of SEPXENBER 19 78 8

II SYSTEM COMPONENT EFFECT ON SAFE NATURE OF OPERATION OF MAINTENANCE THE REACTOR CAUSE OF MALFUNCTION RESULTS OF MALFUNCTION ACTION TAKEN TO PRECLUDE

'RECURRENCE

'8-78 78 Fuel pool cooling deminiliz-in s stem Fuel pool cooling deminiliz-ing system Air motors uni one "C" fuel pool.

demin.

Air motor slo operating Blow head

gasket, man-way gasket leaks on pipe flange under-neath vessel None None Unknown Unknown None None Cleaned air motor H.P. survey, replaced lead gasket, manw~

inspect, hole gaskets and pipe flange gasket.

inspect with 40 PSI.

No leaks at 40 PSI. 78 RHR servic water sys.

Air relief valve on Cl RHRSW um Float and seat None was bad Unknown None Installed new air relief valve 78 RHR servic water s s.

D-3 RHRSW um Packing leak None Unknown None Repaired and adjust ackin

-25 78 7 RHR servic'ater s s.

Diesel gen sys A-1 RHRSW um "B" air. com-presSor on 3A diesel Packing leak Head gasket blown None None Unknown Operation None None Replaced packing Replaced head gas

BROWNS FERRY NUCLEAR P>DNi UNlT 1

>KQIANICALMAINTENANCE SU1BIARY For the Hoot h of SEFXEHEER 1978 DATE SYS TEM COMPONENT NATURE OF MAINTENANCE EFFECT ON SAFE OPERATION OF THE REACTOR CAUSE OF MALFUNCTION RESULTS OF MALFUNCTION ACTION TAKEN TO PRECLUDE RECURRENCE

'5-78 78

-'5-78 Station Drainage High pres-sure fire protection s stem Reactor bldg vent s stem Drywell floor drain sump um "B"

FCV 1-26-79N FCO 64-9 Pump bearings bad Deluge valve open Diaphragm leaking None None None Operation Unknown Unknown None Would not reset valve None Replaced pump bearings Reset deluge valve Installed rebuilt air cylinder 78 78 Elevators system s

s no 203-Elevator system sys no 203 Drywell doors Equipment access door 2

Doors will not pass air test Patch leaking None None Unknown I

Unkhown None None Replaced 0-rings Installed new patch on 2 door air seal equipment tunnel Rx buildin 78 Control ro s stem Scram dischar-ge Valves were leakin throu None Unknown None Ad)usted stroke o

valve 78 Standby SLC lA pump liquid control s s

Intake

& dis-charge valve leakin None Unknown None Machined and lapped valves

CSSC E UIBKNT BROWNS FERRY NUCLEAR PLANT UNIT 1

MECHANICAL MAINTENANCE

SUMMARY

For the Month of SEPTEMBER T97E DATE SYSTEM COMPONENT NATURE OF MAINTENANCE EFFECT ON SAFE OPERATION OF THE REACTOR CAUSE OF MALFUNCTION RESULTS OF MALFUNCTION ACTION TAKEN TO PRECLUDE RECURRENCE 78 Control CRD Accum.

rod drive 42-43 system Accumulator leaking None Unknown None Replaced accumulator 78 Standby liquid control system Valve 63-518 Packing gland loose None Operation None Tightened packing gland 78 Reactor water recirc.

system Equalizing valves FCV-68-33 FCV-68-35 Packing leak None Unknown None Replaced valves 78 Reactor water recir'c.

system FCV-68-77 FCV-68-79 Bad packing leak None Unknown None Repacked valves, 78 RWR system 68-3

& 68-1 Loose packing'8-33 None Unknown None Tightened packing installed lamp on~

68-1

& 68-33 78 Control Valve rod drive l/2-85-539B system'acking leak None Unknown None Tightened packing nuts 78 Control FCV-85-8 rod drive system Packing gland too tight &

pulled crooked None Packing too tight Bent packing gland Straightened packing gland

CSSC E UIPMENT BROMNS FERRY NUCLEAR PLANT UNIT 2

MECHANICAL MAINTENANCE

SUMMARY

For the Month of SEPTEMBER 1978

)-1-78 SYSTEM Fuel> pool cooling system COMPONENT 2A fuel pool cooling pump EFFECT ON SAFE NATURE OF OPERATION OF MAINTENANCE THE REACTOR Packing leak None CAUSE OF MALFUNCTION Operation

\\

RESULTS OF MALFUNCTION None ACTION TAKEN TO PRECLUDE RECURRENCE Adjusted packing

)-7-78 Control rod drive system CRD pump motor IIAII 1/4 nipple broke off None Unknown None Replaced 1/4 nipple with new one

)-13-78 HPCI syste HPCI steam exhaust Collar out of adjustment None Operation None Collar adjusted 3-15-78 HPCI syste Valve 73-16 Packing leak None Unknown None Tightened packing 3-15-78 RHR servic water system RHRSN outlet valve 46B Packing blown out None Operation None Repacked valve I

9-21-78 Fire protection system 2-26-2119 F.P.

header Packing leak 'one Unknown None Tightened packing 9~21=78 Control rod drive

-system..

A-CRD pump Dirty filters None Operation None Changed filters

BROGANS FERRY NUCLEAR PLANT UNIT MECHANICAL MAINTENANCE

SUMMARY

For the Month oF SEPTEMBER 1978 DATE SYSTEM 9-26-7 COMPONENT Air Con. in "C" shutdown room NATURE OF MAINTENANCE Line stopped up EFFECT ON SAFE OPERATION OF THE REACTOR None CAUSE OF MALFUNCTION Unknown RESULTS OF MALFUNCTION Pater dripping on shutdown board ACTION TAKEN TO PRECLUDE RECURRENCE

'Used nitrogen to unstop drain. 78 Station 2A drywell Drainage equip. drain sump pump Pump no good None Operation Pump would not pump Rebuilt pump completely 78 Station Drywell FDSP Drainage Coupling spider worn out on "A" pump None Operation None Installed new spider

& adjusted impeller 78 Station Drywell equip.

Drainage drain sump pump Coupling spider worn out None Operation None Installed new spider, impeller, brushing,

coupling,

& bearing.'

BROGANS FERRY NUCLEAR PLANT UN1T 3

MECHANICAL MAINTENANCE

SUMMARY

DATE SYSTEM COMPONENT EFFECT ON SAPE NATURE OF OPERATION OP MAINTENANCE THE REACTOR CAUSE OF MALFUNCTION RESULTS OF MALFUNCTION ACTION TAKEN TO PRECLUDE RECURRENCE

)-8-78 Vent. syst.

Control bay Dirty filters None Operation.'one

'Changed filters

)-15-78 Control rod drive system 3A CRD suction filter Suction filter need changing None Operation None Changed filters

)-19-78 Rx water recirc.

system FT 68-10 Line stopped

,Up None Operation None Unstopped line

~ ~

~

~

~

~

~ II ~ ~

~

~

~

~

~

I

~

~

~

~

I

~

~

~

~

~

~

~

~

~

I

~

~

~

~ ~

~

~

~

~

~

~

~

~

~

~

I

~

~

~

~

~

~

~

~

~

~

~

I I

~ ~

~

~

~

~ '

~

~

0 II

~

~

~

0

~

~

~

~

~

~

~

4

~

~

~

~

~

~

I

~

~

~

~

~

~

I

~

~

~

~

~

~

~

~

I

~

~

~ ~

~

l1

~

~

~

~

~,

~

~

~

~

I

~

I ~

~

~

~

t!

~

I

~

~

~ ~

~

~

~

~

~

~

~

~

~

~

~

~

~ ~

IL.

~

~

~

~

~

I

~

~

'I

BRONNS FERRX NUCLEAR PLANT UNTT L

ELECTRICAL MAINTENANCE SUGARY For the i'fonth of PAGE 2 of 2 Date System Component Nature of Haintenancc E

ect on a e Operation of The Reactor Cause of Malfunction Results of i~falfunction Action Taken To Preclude Recurrence 9/19 Recirc FCV 68-35

-No indicating lights None Coil burned up in relay No indicating lights Replaced coil, tested o.k.

TR 105221 9/19 Raw Ser-

.vice water PA 25-31 Alarm wouldn' clear None Level switch out of adjustment Alarm wouldn't clear Tank periodically running over and 2A RSM pump not shuttin off Adjusted level sw~.

Verified proper o~

,'tion.

TR 105225 l

I

f

~

~

II ~

~ II ~ ~

I ~

~

~

~

~

~

~

~

~

~

~

~

~

~

~

I

~

~

~

~ ~

~

~

~

~

I

~

~

L

~

~

~

~

~

~

~

~

~

~

~

~

I

~

~

~

~

~

~

~

~

~

~ I

~

~

~

I

~

~

I I..

~

~

I

~

~

~

~

~

~

~ I

~

~

~

~ ~

I ~

~

~ g

~

~

~

~

~

~

~

'I I

I

~

~

~

~

~

~

~

~

I II

~

~

~

~

~

~

~

~

~

~

~

~

~

~

~

~

I

~

~

~ I I

~

I

~

~

~

~

~ I

~

~

~

~

~

~

~

~

~

~

I ~

~

~

~

I

~ I

~

~

~

~

~

~

~

~

~

~

~

I ~

~

~

I

~

J

~

Il ~

~ II ~ ~

~

~

~

~

I

~

~

~

~

~

~

~

~

~

~

~

~

I

~

I

~

~

~

~

~

~

~

~

~

~

~ ~

~

~

~

~

~

~

~

~

~ ~ I 4

I

~

~ ~

I

~

~

I

~

0

~

~

~

~

~

~

~

~

~

~

~

~

~

0

~

~

~

~

~

~

l-

~

0

~

~

~

~

~

~

4

~

~

~

~

~

I

~

~

~

~ ~

~

~

0

~

0

~

~

~

~

~

~

~

~

~ ~

N

~

CSSC EQUIPHENT BROWNE FERRY NOCLFAR PLANT NETT 1&2 INSTRPifENT IIAINTENANCE SUtRMIY I

FOR TIIE HONTH OF SFPT.,

1978 EN Date System Component.'.,

Nature of Haintenance'ffect on Safe.

Operation of the reactor...

Cause of

Halfunction...

I Results

-'o5

...Halfunction..

Action Taken to preclude recurrence nit 1

t. 5 I-15 I

-15 Reci.rc flow control

.ecirc ecirc flow ontrol eedwater ontro1 SC-90-3A FYi-68-49B SC-96-3B PIC-96-1 SC-46-8A,9A,l'OA Repair Repair Repaii Repair None one one I'I Faulty manual control potentiometer Capicitor'shorted to teiminal strip Faulty manual control potentiometer

~

II lt It Erratia Total than a

Frrati, Control!

ore flow less tual Control II II Periodic ~

replaceme~

None Periodic replacement nit 2

)-15 N.H.S Feedwater Control IRH B SC-46-8A,9A,10A Repair Periodic Replacement one one iQty contacts aglty manual control ot:cntiometer 'rrati Errati Indication control one eriodic eplacement

)-22

)-30 Recirc Flow Control RWCU RPIG Radwaste I

SC-96-3A,3B PIC-96-1 TS-69-30E-.

l' Probe 10-23 FS-77-14 II II II'placement None None None

~

~

au1ty switch

~

~

gd: probe buffer card a

efective Level swi,tch High a clear arm would not None None IIone t

Super imposed 0> in units

.W. equipment drain ump pump would not star

SC EJUIPHENT EROMNS FERRY NUCLEAR PLANT UNTT 3

INSTRUHENT 1 fAINTEHANCE SMEARY FOR TllE 110NTH OF Sept ate tnit 9>>'1

'9-1 System Primary containmen Rad.

monitor Component..

LI-64-54B Rf-90-133B Nature of Maintenance Calibration Repair" Effect on Safe Operation of the react'or'".."."'.

None None I

Cause,'f i

....Halfunction.:.

I 7exd Shift

~

I

~

r

• l Bad Detector; Indica ion did agree not re~

High r diation I

Indica ion Results 'of

.Halfunction'!..

Action Taken to preclude recurrence None None 0..19 PDIS-71-1B Calibration'one

~

I Xnstgument

~

~

Drift Indica ed flod. with unit sl utdown I

Bone r

~

~

~

~

~

p

~

~

r I

~

I

~

~

~

~

~

~

~

~

I

~ r Outage Summary (BFNP Unit 3)

September 1978 The dxywell and reactor pressure vessel have been disassembled in order to allow unloading of fuel fox remaining RPV vibration instrumentation and conducting a major inspection and repair of the CRD nozzle.

The CPJ) return to the vessel will be capped and rerouted to the reactor water cleanup system return.

The fuel was unloaded in eight days instead of the scheduled nine days.

Neutron sources and holders have been

xemoved, and 43 local power range monitors are being replaced with longer-life models.

Other major work included leak check and r

eddy current testing of the Eeedwater heaters and condenser water boxes.

The major containment isolation valve testing has shown an initial testing failure rate of approximately 50 percent, including six of eight main steam isolation valves requiring repair.

Major motor testing was completed with one drywell blower motor failing the inspection.

Cleanup and inspection of electrical boards is approximately 50 percent

complete, and the contact retainer arms are being changed out on CSSC system breakers.

The inspection and testing of mechanical and hydraulic snubbers is complete.

To date four control rod drives have been changed out and will r,

continue for two additional drives after IPRM work is complete.

Prefabrication and piping work on the CRD reroute and scram discharge header are underway.

There are several major modifications requiring electricians, including the off-line radiation monitoxing, diesel driven fire pump, recirculation pump trip modification and standby gas treatment modifications.

The main steam relief valves have been sent to the service shop for bore modification, while the valve base assemblies wexe rebuilt onsite.

The major turbine inspection of the low pressure "A" turbine, all reactor feed pump turbines and intercept and control valves were completed.

r'f i,