ML18033B742

Monthly Operating Repts for Jul 1988 for Sequoyah, Units 1 & 2

ML18033B742
Person / Time
Site:	Sequoyah
Issue date:	07/31/1988
From:	Shawn Smith TENNESSEE VALLEY AUTHORITY
To:	NRC OFFICE OF ADMINISTRATION & RESOURCES MANAGEMENT (ARM)
References
NUDOCS 8808220008
Download: ML18033B742 (96)

Text

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( 85 gg7 880811 86 TENNESSEE VALLEY AUTHORlTY Sequoyah Nuclear Plant PE 0. Box 2000 Soddy-Daisy, Tennessee 37379 AUG 11 1988 Nuclear Regulatory Commission Office of Management Information and Program Control Washington, DC 20555 Gentlemen:

Enclosed is the July 1988 Monthly Operating Report to NRC for Sequoyah Nuclear Plant.

Very truly yours, TENNESSEE VALLEY AUTHORITY S. J.

Smith Plant Manager Enclosure cc (Enclosure):

Director, Region II Nuclear Regulatory Commission Office of Inspection and Enforcement Suite 3100 101 Marietta Street Atlanta, Georgia 30323 (1 copy)

Director, Office of Inspection and Enforcement Nuclear Regulatory Commission Washington, DC 20555 (12 copies)

INPO Records Center Suite 1500 1100 Circle 75 Parkway Atlanta, Georgia 30339 (1 copy)

Mr. K. M. Jenison Resident NRC Inspector OOPS-2, Sequoyah Nuclear Plant Director Office of Special Projects 4350 East West Highway, EWW 322

Bethesda, Maryland 10814 (10 copies)

Mr. T. Marston Electric Power Research Institute P. 0. Box 10412 Palo Alto, California 94304 (1 copy)

M pp

'n Equal Opportunity Employer I

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Nuclear Re ory Commission AU I $88 cc (Enclosure):

RIMS, MR 4N 72A-C J.

R. Bynum, LP 6N 38A-C J.

P. Darling, Site Director, BLN C. H. Fox, Jr.,

LP 6N 38A-C R. L. Gridley, LP 5N 157B-C W. H. Hannum, BR 1N 77B-C R. J. Johnson, MBC 01 DS-PTC N. C. Kazanas, LP 4N 45A-C J. A. Kirkebo, W12 A12 C-K W. R. Lagergren, LP 6N 38A-C J. T. LaPoint, 0&PS-4, Sequoyah C. C. Mason, LP 6N 38A-C R. U. Mathieson, Westinghouse, SQN J. L. McAnally, LP 5S 83E-C B. R. McCullough, 9-167 SB-K G. R. Mullee, BR 5S 168A-C R. A. Pedde, Site Director, WBN H. P.

Pomrehn, Site Director, BFN R. A. Remington, 0&PS-4, SQN Vwe Zitzow, LP 5S 98E-C Nuclear Site Representative, BFN Nuclear Site Representative, WBN This was prepared principally by D.

C. Dupree.

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TENNESSEE VALLEY AUTHORITY NUCLEAR POWER GROUP (FORMERLY OFFICE OF NUCLEAR POWER)

SEQUOYAH NUCLEAR PLANT MONTHLY OPERATING REPORT TO THE NUCLEAR REGULATORY COHMISSION JULY 1988 UNIT l DOCKET NUMBER 50-327 LICENSE NUMBER DPR-77 UNIT 2 DOCKET NUMBER 50-328 LICENSE NUMBER DPR-79 Submitted by:

I S. J. Smith, Plant Manager

TABLE OF CONTENTS Page I.

Operational Summary Performance Summary Significant Operational Events Fuel Performance and Spent Fuel Storage Capabilities Miscellaneous PORVs and Safety Valves Summary Special Reports Licensee Events Radwaste Summary Offsite Dose Calculation Manual Changes 1

1-3 4

4 4

5 5-10 11 11 II.

Operating Statistics A.

NRC Reports Unit One Statistics Unit Two Statistics 12-14 15-17 B.

TVA Reports Nuclear Plant Operating Statistics Unit Outage and Availabil~ty Reactor Histogram III.

Maintenance Summary 18 19-20 21-23 Electrical Maintenance Instrument Maintenance Mechanical Maintenance Modifications 24 25-26 27-30 31-38 IV.

Corrections 39-40 0288f/dlr

OPERATIONAL

SUMMARY

PFRFORMANCE

SUMMARY

~Jul 1888 The following summary describes the significant operational activities for the month of July.

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

Unit 1 remained in an administrative shutdown the entire month because of design control review, configuration control updating, and resolut:on of significant employee concerns.

Outage-re'c' d maintenance and modi.ficatic s are being performed in preparation or restart.

Unit 1 has been off line 1,074 days.

Unit 2 entered the month of July at 70 percent power, producing 770 MWe and was online the entire month.

On July 17, 1988, the unit reached 98 percent reactor power.

On July 24, 1988, unit two had produced over 1,000,000 megawatt hours (1,025,474 MWhs) of power since restart and has been in continuous operation for 39 days.

The capacity factor for the month was 77.60 percent.

SIGNIFICANT OPERATIONAT EVENTS Unit 1 Date Time Event 07/01/88 0001E The reactor was in mode 5.

The administrative shutdown due to design control review, configuration control

updating, and resolution of significant employee concerns continues.

07/31/88 2400E The reactor wa". in mode 5.

The administrative shutdown due to design control review, configuration control

updating, and resolution of significant employee concerns continues.

Unit 2 Date Time Event 07/01/88 0001E Reactor at 70 percent, 770 MWe.

Holding for core life extension.

07/16/88 0300E Began load reduction to 55 percent for maintenance on 2A-A and 2B-B main feed pumps (MFP).

0700E 0814E Reactor at 55 percent, 606 MWe.

Began removing 2A-A from service.

l

SIGNIFICANT OPERATIONAL EVENTS Unit 2 Continued Date Time Event 07/16/88 1418E (cont.)

Returned 2A-A to service.

2B-B removed for maintenance.

1552E 2047E 2049E 07/17/88 0200E Reactor at 55,percent, 600 MWe.

Returned 2B-B to service.

Began load increase.

Unit holding at 72 percent, 833 MWe.

The pressure control valve on the H~O injection supply line to 3C heater drain tank pump failed to fully open.

0543E 0717E 1225E Began power increase, repairs complete.

Reactor at 77 percent.

Holding for calimetric performance and.power range adjustment.

Reactor at 90 percent, 990 MWe.

1340E 1620E 1704E 1751E 07/18/88 0300E Adjustments

complete, power ascension resumes.

Reactor at 96 percent.

Reactor at 98 percent.

Diluting the RCS to maintain 98 percent power.

Reactor at 98 percent power, llll MWe, holding because of high steam flow alarm initiating.

07/20/88 0800E Reactor at 98 percent

power, 1122 MWe.

7/21/88 0125E Began load decrease.

Received a high bus duct temp alarm.

0130E Stopped reduction.

2A bus duct cooling water discharge line was crimped.

Corrections made and alarm cleared.

Reactor at 93 percent, 1095 MWe.

0140E 0200E 0600E Returning to 98 percent.

Reactor at 98 percent.

Reactor at 98 percent, 1120 HWe.

SIGNIFICANT OPERATIONAL EVFNTS Unit 2 Continued Date Time Event 07/26/88 0141E Received high steam flow alarm on loop No.

1.

Reduced turbine load.

Reactor at 98 percent, 1120 HWe.

7/30/88 0800E 0030E Reactor at 98 percent, 1120 MWe.

Began power reduction to 55 percent for repair of speedchanger on 2A-A main feed pump (MFP).

0320E 0610E 0815E 0842E 1230E Reactor at 55 percent, 605 MWe.

2A-A out of service.

Maintenance begins.

2A-A returned to service.

Decision made to remove 2B-B from service for maintenance on speedchanger.

1406E 1711E 2B-B returned to service.

2A-A removed from service for maintenance on speedchanger.

1730E 1817E 2130E 2A-A return to service.

Begin power increase.

Molding at /5 percent, 900 MWe.

Oil leak on 2A condensate booster pump.

7/31/88 0627E 0746E Began power increase to 98 percent.

Reactor at 80 percent, 930 MWe. Oil leak on 2A conden ate booster pump.

1045E Began load reduction to 75 percent for maintenance on 2A condensate booster pump.

1119E 2400E Reactor at 75 percent, 865 MWe.

Reactor at 75 percent, 865 MWe.

Maintenance continues on ?A condensate booster pump.

4 t

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FUEL PERFORMANCE Unit 1 The core average fuel exposure accumulated during July was 0 MMD/MTU with the total accumulated core average fuel exposure of 0 MMD/MTU.

Unit 2 The core average fuel exposure accumulated during July was 961.75 MWD/MTU with the total accumulated core average fuel exposure of 9810.33 MMD/MTU.

SPENT FUEL PIT STORAGE CAPABILITIES The total storage capability in the SFP is 1,386.

Howevex', there are five cell locations which are incapable of storing spent fuel.

Four locations (A10, A11, A24, and A25) are unavailable due to a suction strainer conflict, and one location (A16) is unavailable due to an instrumentation conflict.

Presently, thexe is a total of 348 "pent fuel bundles stored in the SFP.

Thus, the remaining storage capacity is 1,033.

HISCELLANEOUS Special Nuclear Material (SNH) Annual Physical Inventory The annual physical inventox'y of all SNM (exempting Item Control Areas,

ICA, whexe utilization of full pxotective clothing is required) was performed on July 28, 1988.

The inventory was coordinated in conjunction with the semiannual system review by Nuclear Fuel, DNE, Chattanooga.

In addition, representatives from Coopers 6 Lybrand and Comptrollers Office were present.

The ICAs wex'e inventoried:

ICA New Fuel Stoxage Vault Contents Unit 2 (cycle 4),

80 unirxadiated fuel assemblies.

Lead Shield Pig 15 spent incore detector tips (only verified tampex-indicating seal number).

Radiological Control Labs 4 plutonium sources Radioactive Material Cage 21 incore flux detector 1 plutonium source There wexe no discxepancie" observed in these areas.

A furthex system review on all SNH records is scheduled to be conducted on August 3-5, 1988.

PORVs AND SAFETY VALVES

SUMMARY

No PORV" ox'afety valves were challenged in July. <<<<<<<<<<

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SPECIAL REPORTS There were no special reports submitted to the NRC for the month of July.

LICENSEE EVENT REPORT S

The following licensee event x'eports (LERs) were tx'ansmitted to the Nucleax'egulatory Commission in July 1988.

LER

~De"cubi t,ion of L<<<<en'.

1-880 24 On June 15, 1988, at 1512E with unit 1 in mode 5, an unplanned reactor tx'ip signal was generated during the replacement of timer relays associated with the RCP undervoltage (UV) relays.

The timer relays for RCP UV relays were being replaced in accordance with WP 12699 to convert the control circuit from 125V DC to 120V AC.

One of the nineteen reactor trip signals at SQN is generated when an UV condition is sensed on the power feeders to at least two out of the four RCPs and the unit power is gxeater than 10 percent.

Permissive P-7 unblocks "at-power" tx'ip signals when either permissive P-10 or P-13 is made up.

Before this event on May 25, 1988, the performance of IHI-99CC10.4B, "Channel Calibration of Turbine Impulse Pressure Channel II," was initiated.

This IMI requires that several bistables be tripped resulting in making up permissive P-13 and subsequently permissive P-7.

Deficiencies discovered during the performance resulted in desistance of work; however, it was agreed to allow the equipment to x'emain in that configuration until performance of the IMI could be continued.

On June 15, 1988, when the wires on the RCP UV timers were disconnected, an UV condition was simulated causing a reactor trip signal.

The cause of allowing WP 12699 to be performed while this condition, P-7, existed, resulted from an inadequate impact evaluation performed by the Woxk Control Group of plant activities and plant conditions for unit 1.

This can be attributed to the fact that the Work Control Group is still in a learning process.

To minimize the number of events caused by inadequate impact evaluations of plant conditions and plant activities, SQN has restructured the Work Control Group.

This restructuring, should provide for bettex'ontxol of work activities and awareness of current plant conditions.

(p-7, -10, -13 are special conditions that must exist befoxe certain safety features are actuated.)

1-88025 On Juno 17, 1988, unit 1 in mode 5, two spur'ious S/G No.

3 high-high level turbine txip first out annunciations were received.

A subsequent investigation for these two events found that both tx'ip signals resulted from maintenance being performed on loop No.

3 S/G during testing for S/G tube leaks.

The trip signals were initiated as a xe ult of two out of three lovel txansmitters generating high-high level signals when the pressure was changed in the S/G fox tube leak testing.

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LER Descxi tion of Event 1-88025 (cont.)

For immediate corrective action, operators acknowledged that an actual high-high level did not occur in loop No.

3 S/G since the generator was drained, and it was known that it was being pxessurized/depressuxized for tube leak testing.

The bistables for the level transmitter were tripped and the root valves opened to ensure that anothex spux'ious trip signal was not generated.

For long-tean corrective action to prevent recurrence of this event during S/G pressurization, TVA will add a precaution in Special Maintenance Instruction (SHI) 0-68-2, "Special Test Helium Leak Testing of Steam Generator," to state that Operations will be notified that a turbine trip may occur as a result of pressurization of the secondary side of a S/G.

1-88026 At approximately

2259E, June 29, 1988, unit 1 was in mode 5 and unit 2 at 70 percent power, all four standby D/Gs received an emergency start signal.

All four D/Gs started as designed, D/G 1B-B was loaded to the system.

The immediate cause was an undervoltage condition on 6.9 kV shutdown board 1B-B that resulted from a short circuit during the performance of a MR on a breaker indicating light.

The short circuit tripped feeder breaker 1722 and created a loss of power condition to 6.9 Shutdown board 1B-B.

The root cause of this event was unclear MR planning.

Although the WR contained instructions fox'ifting the wires associated with the indicating light assembly before initiating the repair, these instructions wore not interpreted by the craft personnel as being a

requirement.

Hence, the work was initiated without lifting the wires.

To prevent recurrence of this event, SQN will instruct MR planners to ensure that each MR on an indicating light assembly that can affect ESF equipment contains a requirement to take the appropriate action necessary to prevent a potential undervoltage condition before work can begin.

In addition to improved WR

planning, SQN will also review this event with Operations pexsonnel to ensure that they are aware of the potential problems that can arise from such routine activities as changing out indicating lamps.

1-88018 Rev.

1 This revision updates the corrective action TVA has taken to prevent the recurrence of reactor trip signal generated fxom radio transmission interference.

1-88023 Rev.

1 This xevision provides additional information about four piping sleeves for reactor coolant pump seal injection water lines that were discovered to be smaller than the nominal diameter shown in TVA design dxawings.

1-88027

Rev, 1

This revision updates the corrective actions and more accurately reflects the minimum reactor coolant system average temperature that occurred following the reactor txip of June 6, 1988

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Descri tion of Event 2-88026 On June ll, 1988, unit 2 in mode 3, Operations personnel attempted to stroke level control valve 2-LCV-3-172 from the MCR and discovered that the handswitch used to manipulate the subject valve in the manual mode would not operate the valve.

Instead, manipulating the handswitch for 2-LCV-3-172, (which controls AFW flow from the turbine-driven AFW pump to 3 S/G), allowed 2-LCV-3-175 (which controls AFW flow from the turbine-driven AFW pump to the Ho.

4 S/G) to modulate.

As a result, Operations personnel declared both valves inoperable and entered LCO 3.7.1.2.

An investigation into this event revealed that two wires in the valves'ontrol circuits had been crossed.

It could not be determined the precise work activity during which this occurred; however, it was determined that this incorrect wiring configuration had most likely been in place since at least Hovember 5, 1987.

This condition was caused by the failure to comply with established configuration control requirements during the performance of reponse time testing.

SQH believes that the wires were lifted without being uniquely identified and, as a result, were improperly terminated.

As immediate corrective action, the wires were connected to their proper terminals and the valves were verified to be operable in all possible combinations of "AUTO" and "MAHUAL" handswitch position".

To prevent recurrence, SQH will review this event with personnel from Flectrical Maintenance (EM), Instrument Maintenance (IM), and Modifications who may be required to lift wires associated with safety-related equipment.

In addition, SQH has reviewed the applicable configuration control procedures and determined that adequate guidance exists in this area for both RM and IM personnel.

An enhancement to the Modifications controlling procedure will ensure Modifications personnel have adequate guidance in this area.

2-88029 On June 19, 1988, at 0730E, unit 2 in mode 3, a CVI occurred as a

result of a spike on the particulate channel of radiation monitor 2-RM-90-112.

This RM provides an output to the "8" train SSPS directly and to the "A" train SSPS through train separation relays.

During this event, indications in the MCR were that the "A" train isolation valves had properly isolated but the "8" train valves had not.

Subsequent to the CVI, Operations personnel verified that no high levels of radiation existed and then proceeded to perform the necessary steps for recovery.

The cause of the spurious spike could not be determined.

Ho maintenance or modification activities were being performed on unit 2 at this time.

The improper operation of a latching mechanism on a slave relay in the SSPS was the cause of the "8" train equipment malfunction.

As a corrective action, the latching mechanism will be replaced/repaired.

LER Descri tion of Event 2-88030 On June'21, 1988, unit 2 in mode 2, personnel documented the potential for a loss of required shutdown margin (SDM) following an end-of-cycle reactor trip and subsequent cooldown below the nominal no-load average RCS temperature (Tavg) of 547 degrees F.

SDM calculations performed following reactor trips have typically been performed approximately 30 to 50 minutes following the trip and have been been based on either the RCS temperature at that time or on the minimum planned RCS temperature for the specific SDM surveillance interval.

As a result, these SDM calculations did not necessarily consider the impact of the RCS cooldown immediately following the trip.

The condition was the result of a failure to identify the effects of excessive post reactor trip cooldowns in either the core design or in plant procedures.

The excessive cooldowns and subsequent addition of positive reactivity from the negative moderate temperature coefficient have been attributed to the overall secondary system response to a reactor trip.

SQN, in conjunction with Westinghouse, has back-calculated the minimum SDM during past operation and verified the requirements have been satisfied at all times during cycle 3 operation of units 1 and 2.

As immediate corrective action, SQN revised the emergency instruction used to guide operator action following a reactor trip to include a provision requiring plant operators to manually control flow if the RCS cooldowns become excessive.

If the plant cooldown continues, operators are instructed to borate the RCS to maintain adequate SDM.

SQN is currently formulating the appropriate long-term corrective actions and will submit a

supplement to this report t.v proved details of these actions.

2-88013 Rev.

1 This revision provides additional information regarding (1) an investigation into the cause of the first reactor trip and (2) the corrective action TVA has taken to prevent recurrence of these events.

2-88022 Rev.

1 This revision provides updated details on the completion date of training for Instrument Maintenance personnel.

2-88023 Rev.

1 This revision updates the corrective action section of this report.

2-88027 Rev.

1 This revision updates the corrective actions and reflects more accurately the minimum reactor coolant system average temperature that occurred following the reactor trip of Juno 6, 1988.

ABBREVIATIONS Page 1 of 2 1.

ABGTS 2.

ABSCE 3.

ABI 4.

AFW 5.

AOI 6.

ASOS 7.

AUO 8.

BAT 9.

BIT 10.

CAQR 11.

CCP 12.

CCW 13.

CRI 14.

CREVS 15.

CSS(CS) 16.

CVI 17.

D/G(s) 18.

DCR 19.

DNE 20.

ECCS 21.

ECN 22.

EGTS 23.

EMI 24 EQ 25.

ERCW 26.

ESF(A) 27.

FCV 28.

FSAR 29.

FWI 30.

GOI 31.

GPM 32.

HO 33.

IM 34.

IMI 35.

LCV 36.

LCO Auxiliary Building Gas Treatment System Auxiliary Building Secondary Containment Fnclosure Auxili.ary Building Isolation Auxiliary Feedwater Abnormal Operating Instruction Assistant Shift Operation Supervisor Assistant Unit Operator Boric Acid Storage Tank Boron Injection Tank Condition Adverse To Quali.ty Report Centrifugal Charging Pump Component Cooling Water Control Room Isolation Control Room Emergency Venti.lation System Containment Spray System Containment Ventilation Isolation Diesel Generator(s)

Design Change Request Division of Nuclear Engineering Emergency Core Cooling System Engineering Change Notice Emergency Gas Treatment System Electromagnetic Interference Environmentally Qualified/Environmental Qualification Fssential Raw Cooling Water Engineered Safety Feature (Actuation)

Flow Control Valve Final Safety Analysis Report Feedwater Isolation General Operating T~struction Gallons Per Minute Hold Order Instrument Mechanic Instrument Maintenance Instruction Level Control Valve Limiting Condition for Operation )lpt+w@y$p>>, pt>>'p$ ~t >> t~>>>>+>> p p, >>>>+>>>> t>>t >>j~ t I>>, t tt

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ABBREVIATIONS Page 2 of 2 37.

LOCA 38.

MAST 39.

MYI 40.

MFP 41.

MOV 42.

MSI 43.

MSIV 44.

MCR 45.

NSS 46.

NSSS 47.

PORC 48.

PRO 49.

RCS 50.

RHR 51.

RM 52.

RWST 53.

SCR 54.

SFP

55. S/G(s)

56. SI 57.

SMI 58.

SOI 59.

SQN 60.

SR 61.

SSPS 62.

TACF

63. TI

64. TS(s) 65.

UO/(S)RO 66.

WP 67.

WR Loss OE Coolant Accident Maximum Allowable Stroke Time Main Feedwater Isolation Main Feedwater Pump Motor Operated Valve Main Steam Isolation Main Steam Isolation Valve Main Control Room Nuclear Security Service Nuclear Steam Supply System Plant Operati.on Review Committee Potential Reportable Occurrence Reactor Coolant System Resi.dual Heat Removal Radiation Monitor (RAD Monitor/RAD MON)

Refueling Water Storage Tank Significant Condition Report Spent Fuel Pit Steam Generator(s)

Surveillance Instruction/or Safety Injection Special Maintenance Instruction System Operating Instructi.on Sequoyah Nuclear Plant Surveillance Requirement Solid State Pr'otection System Temporary Alteration Control Form Technical Instruction Technical Specification(s)

Unit Operator/(Senior)

Reactor Operator Workplan Work Request

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RADWASTE

SUMMARY

July 1988 1.

Total volume'f solid waste shipped offsite:

A.

Dry active waste:

828 ft.~

Activity:

9.4026 curies B.

Spent resins,

sludges, bottoms:

0 Activity:

N/A curies Shipped:

July 4, 1988 Barnwell, Inc.

2.

Radwasto onsite and awaiting shipment:

A.

Resin in storage:

109 ft.~

B.

Estimate resin that will be generated:

109 ft.a C.

Dry active waste awaiting, shipment:

667.5 ft.~

OFFSITE DOSE CALCULATION MANUAL CHANGES No changes werc made to the SQN Offsite Dose Calculation Manual (ODCM) in July 1988.

OPERATING STATISTICS (NRC REPORTS)

~ '

DQCI(I:T NO.

50-32 i DA'I'E AUGU"T 05, 1988 COt'1PLETED OY D. C.

DUPRI.I'ELEPHOhlE

( 6 1 5 > 870-67" i'

~

7.

8.

IT NAME:

BEGUQYAH NUCLEAR PL*MT>

UNI T R=.PORT PERIOD:

JULY 198;S

CENSED THERi1AL POWER (ilWT'411. 0 "l'-'MEPLATE RATING (GROSS I'IWi:);

1220. 6 IFBI GIV ELFCTR ICAL RATING ("I(.:T l1WE):

1148. 0 "l~XIilUh1 DEPENDABLE CAPACITY (GROSS Ml'c ):

1183. 0

!"(iXIiIUM DEPENDABLE CAPACITY (NET MW- ):

1 l(18. 0

F CHANGES OCCUR IN CAPACI ( Y RATINGS( ITEMS NUI1BFRS

( TIIROUGH ')SINCE LAST REP"I.: IVE REASONS:

NOTES; P('WER LEVEL TO WHICI-I RESTR ICTED, IF ANY(NE I MWE):

10.

REASONS FOR RESTRICTIONS) IF ANY:

Tl-IIS t1QNTH YR. -TQ-DATF CUiilULATIVE 11.

12.

13 ~

17.

18.

19.

20.

21.

22.

23.

24

~

'".OURS IN REPORTING PERIOD IVUMBER QF HOURS RFACTQR WAS CRITICAL REACTOR RESERVE SHUTDQWIV I{OURS 11("URS

(-'El'IERA'COR QiN-LINF UNIT RESERVE SHUTDOWN HOURS

'-'ROSS IHERMAL ENERGY GEN-RATED (t1WH)

GROSS ELECTP, ICAL FNERGY GEN.

( MWH

)

NET FLECTRICAL ENERGY GENERATED (MWH)

U',wl T SERVI CE FACTOP.

UNIT AVAILABILITYFACTOR UNIT CAP*C I TY FACTOR (USING t1DC IVET)

UNIT CAP AC I TY FACTOR ( US I IVG DER NET >

UiNIT FORCED QUTAGF RATF Sl UTDOWNS SCHEDULED OVEP.

IVEX1 6 MONTHS 744. OO 0

QO

0. 00

n. Qn

0. 00

0. 00 Q. 00

-3766. 00 0 00

0. 00

0. QQ

0. no i QQ Qn (TYPES'ATEi 5111. 00 62112. 00

0. 00 24444. 91

0. 00

0. 00

0. 00 23781. 13 O. OO

0. 00

0. 00 77060971. 91

0. 00 25976386. 00

-34053. OO 2ne20270. 00

0. 00

38. 29

0. 00

38. 29

0. 00

34. 81

0. 00

34. 81 100. 00

55. 27 AND DURATION Ql=

EACH>:

25.

I.'HUTDOWN AT END QF REPORT I ER IOD ESTIMATED DATE OF STARl UP:

~

Tl"'E R EST*RE OF UIVI T1 IS TLNTATIVELY SCHEDULED FOR SEP TEI1BER 1 988 NOT:-.

IHAT THF-THE YR- -TO-DATE AND CUhIUI.(lTIVE VALUFS HAVE DEEIP UPDATFD.

SEQUOYAH NUCLEAR PLANT AVERAGE DAILY POWER LEVEL DOCKET NO.

50-327 UNIT :

ONE DATE AUGUST 05,1988 COMPLETED BY D C DUPREE TELEPHONE (615)870-6722 MONTH: JULY 1988 AVERAGE DAILY POWER LEVEL DAY (MWe Net) 01 02 03 04 05 06 07 08 09 10 12 13 15 16 DAY 17 19 20 21 22 23 24 25 27 28 29 30 31 AVERAGE DAILY POWER LEVEL (MWe Net)

-5

UNIT SIIUTDORlS AND POWER REDUCTIONS REPORT tlONTII JULY 1988 DOCKET NO.

50-327 UNIT NAHE Se uovah One DATE Au ust 5

1988 COMPLETED BY D.

C. Dupree TELEPIIONE 615 870-6722 No.

Date C ~

o N

LI 0 Cl C I Co EO C)

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CC Ll V

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0 Licensee Event Report 8

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Cann

r. e 0 'U 0- o 6 O 0(J Cause

& Corrective Action to Prevent Recurrence 880101 744 F

4 Design Control, Configuration Updating, and Employee Concerns.

F:

Forced S:

Schcdulcd 2Heason:

A-Equipmcnt Failure (Fxplain)

B-Ilaintenance or Test C-Refueling D-Regulatory Restriction E-Operator Training 6 Liccnsc Examination F-Administrative G-Operational Error (Explain)

II-Other (Explain) aHethod:

I-llanual 2-lfanual Scram.

3-Automatic Scram.

4-Cont. of Existing Outage 5-Reduction 9-Other "Exhibit G-Inst.ructions for Preparation of Data Fntry Sheets for Licensee Event Report (LER) File (NlJREG-0161)

Exhibit I-Same Source

i i"i(t iT I I'l(r ~ TATUS

!)I.l(:fiE 1 i~lQ.

aa-3?8 DA'fE AUGUS! Ooi 1988 COI'1P LE TED 0 Y D

C ~ DUP!'Il.l.

TE! EPI-IQiiIE (615) 870-672 I~ ~

6.

7.

S.

~ "T I'IAI'lE: SEGUOYAH NUCLEAR

".. ' I UiVI T 2

"-PQR T PER 'QD

~ULY '1988

C~:NSED THI.RMAL POWER (i!!IT i 24 l l. 0

'- MLPLATE RATING

( GR QSS !'N: i 1 " 20. 6

~6'8'ivk ELECTR ICAL RATING

<i i i 'NE):

I 1 +8 0

'c'X IMUii

<) 'NDADLE Cc'i!tACIT s

~ 0" ikSS l1(IE):

1 183. 0

',AX IMUM DEPENDABLE CAPAC I

. Y NE l

!AWE):

f 148. <)

" CHANGES QCCUP.

IN CAPACITY f(*TINGS<ITEMS NUMDERS THR OUGH 7 ) S Ii lC LAST REP s '

VE REASGs'IS.'QTLS:

I'Wi=R LEVEL TO WHICH RESTR1CTEDi IF ANY(I'JFT i1WE):

10.

iREASQNS FOR RESTRICT IQNSi IF ANY:

THIS MQNTiH ~

YR- -TO-DATE C(II'IUL*lIVE 11.

12 ~

13.

14.

5.

7.

18.

19 ~

20.

21.

I" i

~

23 0 2 J.

!.'OURS IN REPORTING PERIOD 744. nn 5 1 1 1. Oo 54072. 00 I'Ji.:M!3ER OF HOURS REACTOR WAS CR I 7 ICAL 744. 00 1529. 10 23513. 64 RI."ACTOR RESERVE SHUTDOWN HOURS

0. 00

o. oa

o. oo i iI 'URS GENE..ATQR QN-LIiVE 744. 00 l 424. 75 22918. 97 RVE SHIJTDQWN HOURS

0. 00

0. 00

o. 00

.-.'i oss THER!'1AL '-",i'!FRGY GFNERATED

( !NH) 2050019. 28 3650995. 64 72/78972. 86 ROSS ELFCTR ICAL ENFRGY GEiJ.

<MWH) 683010. 00 1197940. 00 2/1734720. 00

~IET =LFC I P I C(4L El'JEPGY

('EiJEPATED

( MWH )

655061

~ 00 1072087 00 23'80232. 00 UNI T SERV.'CE k iACTQA 100. 00

27. 88

42. 39 UfiJI T AV*ILAGILI TY 1 i'CTOR 100. 00

27. 88

42. 39 I 'blI T CAPAC I'1 Y FACTOR (USIi~lG I'1DC NE'"')

76. 6"/

l8. 27

37. 99 ui':1T CArACIrY FACTOR(USIfl(

DEB NET)

76. *9

18. 27

37. 99 U!,IT FORCED OUTAGE fiATF

o. aa

72. 12

53. 39

.:-'I"U'O(liJS SCl'!EDULED OVER f"'.:. 3 6 MONTHS

( 1 YPE DATE AND DURATION'3!'ACH):

=O'R REFUE',"I QU CAGE;8 TE!'ITAT!V!=LY SCHEDULFD FQR JANUARY I /O /

iITH A DURATION OF 65 DA.8,

'/ S."iU f'DOWN '

l. I'JD QF REPORT PER IOD EST I MATED DATE OF STARTUP:

NOT-THAT THE THE YR. -TQ-DATE AND CUMULATIV VALUFS HAVE i)Ett'I UPDATED

-15"

SEQUOYAH NUCLEAR PLANT AVERAGE DAILY POWER LEVEL DOCKET NO.: 50-328 UNIT: TWO DATE :

AUGUST 05,1988 COMPLETED BY D C DUPREE TELEPHONE (615)870-6722 MONTH: JULY 1988 AVERAGE DAILY POWER LEVEL DAY (MWe Net)

DAY AVERAGE DAILY POWER LEVEL (MWe Net) 01 02 03 04 05 06 07 08 09 10 12 15 752 756 756 757 755 755 754 857 758 757 758 757 758 756 757 622 17 18 19 20 21 23 26 27 29 30 31 928 1069 1068 1079 1082 1081 1078 1078 1079 1081 1078 1076 1078 666 846

UNIT SNUTDORlS AND PO'4ER REDUCTIONS REPORT NOHTlj JULY 1988 DOCKET NO.

50-328 UNIT NAtiE Sequoyah Two DATE August 1,

1988 CotlPLETED BV D.

G Dupree TELEPllOHE Ho.

Date C ~

0 Ol

~rtIJ cS 0 A

CV 0

Vl rq CI w

0 0

CO IJ0 CO 0

IJ IJ IJ g IJ IJ 0

Licensee Event Rcport JI F.m Cl 0 IJ Ul 0 NO CA IJ CIJin

r. e 0 0 0 0O 0

Cause

& Corrective Action to Prevent Recurrence 10 880716 S

0 B

Maintenance performed on the speedchanger of both main feedwater pumps.

880730 S

0 Maintenance on 2A-A main fecdwater pump speedchanger.

iF:

Forced S:

Scheduled 2Reason:

A-Equipmcnt Failure (Explain) 8-Maintenance or Test C-Refueling D-Regulatory Restriction E-Operator Trai>>inl; & Liccnsc Examination F-AIlminist ra tive G-Operational Error (Explain) ll-0thcr (Explain) atlethod:

1-tlanua l 2-tlanual Scram.

3-Automatic Scram.

4-Cont. of Existing Outage 5-Reduction 9-Other "Exhibit G-Instructions for Preparation of Data Entry Sheets for Licensee Ev. nt Rcpo rt (LER) File (tH!REG"0161) sExhibit I-Same Source

OPERATING STATISTICS (TVA REPORTS)

rVA 1 382A IONP 4 88)

NUCLEAR PLANT OPERAT/NG STATISTICS SEOUOYAH NUCLEAR Plant Item No.

Unit No.

UNIT OiVE Month JUI.Y UNIT TWO 1988 PLAViT Co 1

Avera e Houri Gioss Load kW 2

Maximum Hour Nct Generation MWh 3

Core Thermal Enera Gen GWO I 2 Steam Gcn. 1'hci'mal Lncr Gcn., GWO 5

Gross Electrical Gen.

MWh 6

Station Use. MWh 7

Net Electrical Gen., MWh 8

Station Use. Percent 9

Accum. Core Avq. Exposure. MWD/Ton 10 CTEG This Month. 10 BTU 11 SGTEG This Month. 10 BTU 12 13 Hours Aeactor Was Critical 14 Unit Use Hours Min.

15 Ca acit Factor, Percent 16 Tiirbine Avail. Factor Percciit 7

Gnr rAvail Fator Prcnl 18 Tiiibo en. Avail. Factor Percent An r Av I F r

P r n

20 Unit Avail. Factor Percent Tiirhine Startu Aeart i Cold tart<<

0 0

0 0

3,766

-3,766 N A 0

0 0

0.0 0.00 0.0 0.0 0.0 0.0 0.0 0.0 0

0 918,024 1,088 85.4175 85.8766 683,010 27,949 655,061 4.09 9,810 6,996,716 7i030%226 744.P 744:00 100.0 100.0 100.0 100. 0 100. 0 100. 0 0

0 918,024 1, 088 85.417 c

85

~ 8266 683,010 31,715 651,295 4.64 9,810 6,996,716 7,030,226 744. P 744: 00 50.0

50. 0

50. 0

50. 0

50. 0

50. 0 0

0

~II CP Q.

o I

24 Gross Heat Aatc. 13tu/kWh 25 Nel Heat Aatc. Atu/kWh Gross Heat Rate Btu kWh w o oil Net Heat Rate Btu ktA w o oil 28 Throttle Pressure, psirI 29 Throttle Tem cratiire, F

30 Exhaust Piessure.

tnt lit Abs.

31 Intake Waler Tcmo.. 'F 32 33 Main Feedwater.

M Ib/hr 34 35 36 37 Full Power Capacit, EFPO 38 Accum. Cycle Full Power Days. EFPD 39 Oil Fired for Generation. Gallons 40 Oil Hea in Value'tu Gal.

~ nr inMWh N/A N/A N A N/A N A N A 404.86 0.0 10,240 10,680 850.3 525.9

2. 91 75.8

11. 9 363.65 255.4399 10,240 10,740 10,240 10 740 850.3 529.9 2.9 75.8

11. 9 768.51 255.4399 1,386 138,000 21 Max. Hour Net Gcn.

MWh Time Date 43 1,088 1500 7/20/88 Max. Oay Net Gen.

MWh Date 25,956 7/21/88 Load Factor. %

80.46 Co Aernarks:

IF'r f3FNP this value is MWO/STU and lor SQNP and WI3NP this value is MWD/MTU.

2(t) indicates Thermal Energy.

V GE ANO AVAILABILITY Litcn5cd Reactor Power 34TT h1W(th)

Generator Retina TZ 0 ~ 5 trtV(tc)

Dccg 0

ccElhccic Iilcl g

I~Decl'I SE UOYAH unit NO.

O'IE Nuttear Plnnt I Iggg<llr/Ye w JULY I 988 Pc<coil t tnglg~

1C<

Osy Time Unl< Avolloblc Tel<<

acn.

r<nt <<<cd Hr<

h'Icn In<

Mcn III<

Min fHIIC r<u< Ag<c<D<2<C Tug nlni Ccn.

nevi<or Unc I 24 '00 24 '00 24 200 24

< 00 24 00 24

<00 24 too 24 00 24 Iaa 24~00 24 Lao 24 loo 24

< 00 I

24

< 00

~24 00 24 lao 24~00 24 ioo 24 ioo 2C '00 24

<00 2C 200 24 <00 24 00 24

'OO 20 DD 24 <00 24 00 zC <oo zC Ioa zc Ioo 24 oo

'Time Ou<

I<i<

h<in Tune In

< <ii hie n Our AGE CAu5E OestEn Controt ~Conf Ipurst ion UfgdntfnE~ nnd EPp)oyltE CoyccL UNI f

'5IATU5 f)URII:hi Oufr GE I.<ETIIOO OF 5IIUTTING OOIYN REACTOR

~NA

~cdC CX CIIIIIICCfIVE AC I ION IAKCII TO PIIEVI.IIT RLPEIITIO I IO lz l3 15

~24 00

~24 00 24 <00 24

< 00 24 '00 24 00 24 <00 24 '00 24~ 00 24

<00 24 '00 24~ 00 I

24 00 24

<00 22 00 2C IQO 24

<00 2C DD z<<ao 24

'00

~24 00 24 i 00 24 00 24 00 2< Ioo 24 Ioa 2C~ OQ 2C 00 I

c

, rnl

'1I' c

j, 17 ls l9

?'I

?2 23 25 26 27 28 29 30 3l 24 00 24 00 24 iao 24 '00 24 00 24 '00 24

<00 24 00 24

<00 24

~00 24 I 00 2C

'00 24

~oo 24~ 00

~20 0 24

<QQ 24 00 2~400 2C

'00 24 I 00 24 00 zzlt) 2 0

~24 00 24 00 24 OQ 24 OQ 2

go 2260 2

<00 24 00 24 00 24 00 24 I 00 24

'00 144 I 00 144 00 44

<00 144 00 24 00 24

<00

~24 00 24 I 00 24 lao 24 00 24 iao 24 00 24 00 24 00 24 00 24 00 24 <00 24

<00 24 00 24 00 24 <00 24 00 24 gaa 24 I 00 2

00 24 00 24 00 24 I 00 24

< 00 24 Iao 24 200 24 00 70 c

- -rr 2

Dh

v-

. 's f

I VAribCOU II'IvJ /4) 8EQUOYAH Nuclear Plnnt UNI E ANO AVAILABILITY

,i.

i

.i

.1 Tinic Unit Avoilcblc To los Ccn.

NOI USCu TurhinC Ooy HrS hsin 2

IIIO Ins Min Iris Min Isrs Min 4

I Licensed ftcoctor Power 3411 MW(th)

Generator Acting 1220-5 MW(e)

Design Gross Electrical Anting 1183 MW Tlnle IIOI Avaucbfe Vnil ACCCIOr Ccn.

IOS IAn Isis hun Ins Min Unit No.

Tt'0 Unit Tonic In Tinsc OUI Isis hbn Isis lAin OU fhGE CAUSE MCTIIOO OF SIIUTT ING OOWN ACACTOIT UNIf STATUS OUITINC OUIAGC COIIAECTIVCACTION TAKCN fOPACVENT flCPC f I T ION h1rsnth/Ycor JULY 1988 r cr rod tins s

~ISO 24 Io 24 00 2g s09 g4 loo 24 00 IIV O

I I

I 10 12 13 I4 15 16 17 18 0

21 22 23 25 26 27 29 30 31 Total 24 Ioo 24 '00 24 0

4 Io 24 lo 24 00 24 0

4 0

24 Ioo 24 loo 24 00 24 00 24 00 24 00 24 Ioo 24 1 00 24 00 24 00 24 Ioo 744 IOO 4

I 0 24 00 4

00 4

00 4

0 4

00 4

0 24 00 C

Io 4

0 24 00 24 00 24 lop 24 00 24 00 2C Ioo 24 00 24 Ioo 24 Ioo 24 00 24 too 44 00

~ I

~C OC ~W

REACTOR HISTOGRAM SEQUOYAH UNlT ONE I

O Q

Q Q

O CL QO I

O

<C Q

100 90 80 70 60 50 40 30 20

'l0 0

Unit in mode f5 13 17 JULY 1988 21.

25 29

REACTOR HISTOGRAM SEQUOYAH UNIT TWO O

EL CL Cr O

CL O

I C3 Q

100 90 80 70 60 50 40 30 20 10 0

2 3

6 6A 6

13 17 JULY 1988 21.

25 29

1.

Hold for core life ext.ension.

2.

Load reduction.

Maintenance on the speedchanger on both 2A-A and 2B-B main feed pump.

3.

The pressure control valve on the H~O injection supply line failed to properly open, stopped power ascension.

4

~

Reactor at 98 percent power.

High steam flow alarm comes in at power greater than 98 percent.

5.

2A bus duct alarm initiated.

Power was reduced.

6.

Hold for oil leak on 2A condensate booster pump.

6A Reduced load to repair condensate booster pump.

SUMMARY

OF MAINTENANCE ACTIVITIES

HAINTENANCE SUHMARY (ELECTRICAL)

'hl

ELWRICAL HAIHTEHAHCE tlGHntLY SUttttARY CDHP tJt2....

U FUHC SYS ADDRESS. DATE.... DESCRIPTIDH 08-05-88 CORRECTIVE ACTINi.

74 2 s"iVOP 067 BPI2306 1 RATf: 082 8751406 2 llTRf'30 0103 01/11/88 2-ttUQP-067-0103-BiE>HPRO>i >10CFR50.4't~3.

STROKED VALVE FOR SI-166.3 STROKE TIllE MAS 63.7 SEC ttAXIttUtt ALLOMAf'LE IS 60.0 SEC.

Ul: 03/10/88 I-RATR-082-LB-AiCuHPRD>3)REMDRK CDHHECTIGHS RETMEEH CELLS 12 ! 13 AHD CELLS 21 8 22 PEP. llI-10.54. CELLS CDHHECTIOH CH 12 8 13 IS Af'DUE 207.

CF RASE UALUE.

TECH SPEC IS HOT IHVDLUED.

REF SI-238 PERFGRllED 12-14-87 01'ld 06/13/88 2-ttTRB-030-01'td-h,c~locFR50.4 t~.@PRO~3, ROOtt COOLER tIKIH6 A LGT QF HQISE.

IHVESTICATE REARIH6 AHO REPAIR REtlQTE STROKE TlttE MAS 63.7 SECTS.

ttAXIttUtt ALLOMABLE TIttE IS 60.0 SECOHOS.

ADJUSTEO ttECHAHICAL STOPS AHO LIHITS.

PERFURtKD ttOTDR OPERATED VALUE AHALYTESTIH6. MR R274174 THE IHTERCELl CGHHECTGR "Z-M" MAS RAO POSSIBLY OUE TO lEAD OXIDE f'UILDUP.

REMD"KED CGHHECTIGHS BETMEEH CELLS 12 13'1 AHD 22.

REPLACIH6 2 BARSt f'DLTS PJlD HUTS.

MR 82'l2306.

RBUESTED 'lHAT A FAIlURE AHALYSIS BE PERFOPJlED BY THE ttAIHTEHAHCE EHOIHEERIH6 SECTIQH.

THE BELT TEHSIOH MAS TOG TINT RESULTIH6 IH BAD REARIH6S AHD PEHT Sl!AFT.

REFEREHCE MR B75143'l FDR f'EARIH6 REPlACalEHTS.

REPLACED THE tlQTCtf.

VEPJFIED ACTUAL NIDOR RPHS MAS 1764.

REIHSTALLEO llDTOR PULLEY AHD ALI6HED.

FAH SPEED=1522 RPttS AHD ttIHItlUtt=1583.

MHEH ttQTOR MAS RAHU THE BEARIH6S StlCKED AHD SLUH6 CREASE.

MAINTENANCE

SUMMARY

(INSTRUMENTATION)

0 f

INfRUttM HAIHTEHAHCE tlCHTHLY SUttttARY 08-05-88 COUP N2....

U FUHC SYS ADDRESS. DATE.... DESCRIPTIOH.

CORRECTIVE ACTIOH.

3 2 LT 063 0178 06/06/88 2-LT-063-0178-F>DURIHC PERFORMHCE OF Ptl 1653-063'OUHD T.P.

READIHQ OUT GF TOLERAHCE.

8751342 2 TR 070 0161 Od/16/88 2-TR-070-0161-iE<HPRD>3iTR DOES HOT ROTATE.

REPAIR GR REPLACE 8293686 2 LT 068

'338 05/12/88 2-LT-068-0339-D,VEHT COHDEHSATE POT TO DETERtlIHE ZF SEHSE LIHE IS BLOCKED THE TRAHSt)ITTER MAS GUT OF TOLERAHCE HI6H TtlROUNOUT THE EHTIME RAHCE.

HO ROOT CAUSE DETERtlIHED. TIIE TRAHStlITTER MAS RECALIBRATED TO DESIRED TQLERAHCE AHD RETURHED TO SERVICE.

(MR48264123)

THE TRAHStlITTER HAD A LOSS ar HEAD DUE TO A DEHT PRESSURIZER TAP.

VEHTED CGNKHSATE HEAD POT PER IN-Xld. RECALEO AHD CAQDRATED TRAHStlITTER PER ICFI88<7'ld AHD It!I"'llCC5.428.

PERFORI'ZD PllT AKD RETUPZED TO SERVICE.

(MRIB2't3686)

THE GEARS IHSIDE THE MTOR DRIVE ASSEtlBLY MERE FGUHD TO 8E STRIPPED.

$mar CAUSE GF STRIPPED GEARS IS LCHGMH. THE CHART DRIVE ASSEMBLY MAS REPLACED AHD THE PllT MAS PERFORMED AHD SATISFIED.

VERIFIED THAT CHARASSEtt8LY MAS ROTATIHG PROPERLY.

(MRi8751342)

IHSTRUiscMT NAIHTEHAHCE lfO'lTllLY SU1NARY 08<5-88 CGllF AR2 U FUHC SYS ADDRESS. DA1E.... DESCRIP1IDH CDPRECTIVE ACTIOH...

80031 2 LCV 002 0003 07/01/88 2-LCV-002-0003-) NI1H THE COHTROLLER IH

!5AHUAL (> 60%)

THE FLOW SWIHCS FHN 31%

TO 55%.

LDCALLY AT THE L':oLVEi TUE VALVE STEll IS SWIHCIHC.

IHVESTICATE AI REFATR NISSIRC FEEDDACK CLIF, OSCILLATIOH CAUSIN VIDRATIGH FEEDRACKi WEAR AHD ACE.

REPLACED PRESURE RECULATOR. VALVE POSITIGHEH PRESSNE IHDICATORS.

IHSTALLED FEEDPACK ARH CLIP VERIFIED VALVE S1RQKE AND RETURHED VALVE TO HORUAL GPERATIUH.

<WR5 878)031)

MAINTENANCE

SUMMARY

{MECHANICAL)

0 0

p

llECHAHICAL MIHTEHAHCE llQHTHLY SlNQARY 08-05-88 COHP HR2....

U FUHC SYS ADDRESS. DATE.... DESCRIPTIOX.

CORRECTIVE ACTIQH.

'253&9 2 FCV 087 f'264046 2

FCV 070 f'78085'l 1 VLV 070 0021 07/23/88 2-FCV-087-0021-DiREPLACE HITRQCEH BLADDER AHD/OR SCHRADER VLV ASSOCIATED MITH HYDRAULIC ACCLtH OM alHI ISOL VLV 0133 01/1 l/88 2-FCV-070-0133.haE>P2N3i THERNL MRIER CGHTAIHnEHT ISOLATIOH FCV-0?0-133 HAS OH EXCESSIVE PACKIMG LEAK <DUE TO THIS STATUS FILE OM OF/25/88 1-VLV-070-076-hiVALVE HAS LEAK NDY CASKET LEAK Ae PACKIHC DEf'ECTIVE STE!l IH SCHRADER VALVE.

REPLACED STEll IH SCHRADER VALVE AHD RETURHED TG SERVICE.

<IlR8 P2536N)

PACKIHG HAS LOOSE.

THEPE HAS HO ADJUSTllEHT LEFT. DISASSEHf'LED VALVEiREPACKED AHD REASSEHf'LED VALVE.

<MRS B2A048)

VALVE HAS IHSTALLED NETHiOUT PACKIHC, IHSTALLED CRAPHITE TAPE QH CASKET AMD PACKED VALVE. RETNHED TQ SERVICE.

<NRI 87803 Pl)

-27"

00'l0 Od/25/88 2-FCV-070-00'tO-A)E~HPRDN.N10CFR50.4'le.1 HSPECT PACKIHC ADJUST AHD/OR REPLACE AS REttUIRED TQtt3826 1 FCU 070 0133 07/07/88 1-FCU-070-0133-A, EwHP RDa3, PER SOI-70.1h-l 1-70-786 SHDULD DE OKH)

DUT THE ULV IS COMFIGURED CLDSED DUE VLV STOI LEAK DFF FROll 1-FCU-70-133.

8768706 2 LCU 003 0156 07/02/88 2-LCV-003-0156-A)VALVE EXCEEDED ltAST DURIHG SI-166.1.

IHVESTIGATE AHD REPAIR AS NECESSARY.

rEC:IAHTQL tthIHTEHAHCE MHTHLY SUtttthRY 08-05-88 COltP rR2....

U FMC SYS ADDRESS. DATE.... DESCRIPTIOH.

E'232760 2 FCV 070 CORRECTIUE ACTIOH.

VALVE IHTERHALS 1KRE RUSTFD.

LAHTEFH RING STUCK HOT ALLDNIHG PROPER PACKIHG OF VALVE. REASSEtt8LED AHD REPACKED VALVF.. RETURHED VALVE TO SERVICE.

(NPTtt232760)

PACKTHG HAD HQ tiORE ADJUSTttEHT LEFT.

COHTIHUED LEAKAGE tthY HAVE AFFECTED REACTDR CODLAHT KlP THERtQL DARRIER OPERATIIB. IHSTALLED HEN PACKIHG AHD HEN 8OHHET GASKET AHD RETURHED TO SERVICE.

(NFT82<Lt826)

HDLE NAS FOUHD IH DIAPHRAGtt. IHSTALLED HEN DIAPHRAGll AHD PERFOtUtED SI-166.1 AHD VALVE PASSED THE TIllE LIllIT.

(NPRc768706) 0

MECHANICAL MAINTENANCE MONTHfY REPORT FOR JULY 1988 COMMON 1.

Replaced diaphragm on 0-FCV-014-0300 (Condensate System).

2.

Completed repair on ERCW traveling screen O-SCR-067-0475.

Unit 1 1.

Completed various activities on the ice condenser system and related components.

2.

Completed work on steam generators.

3.

Completed work on several valves on the RCS system.

4.

Completed repair on "BB" ERCW traveling screen 1-SCR-067-0475.

5.

Functional testing on snubbers.

6.

Installed new diaphragms on several Grinnel valves.

7.

Completed repair on limitorque operator on 1-MVOP-002-0003.

8.

Completed repair on unit 1 polar crane.

9.

Installed new lower seal housing bolts on RCP l74.

10.

Repairing throttle valves.

ll.

Rebuilt several valves on system 63 (Safety Injection).

12.

Completed repairing and testing containment personnel airlocks.

13.

Rebuilt pressurizer safety valves.

14, Completed work on long cycle valves.

15.

Installed new solenoid on 1-FSV-062-0022 (Chemical Volume and Control,

~IPVCSe

~ )

16.

Completed work on several valves on the CYCS system.

17.

Completed several WRs on the glycol system.

"29-

4

MECHANICAL MAINTENANCE MONTHLY REPORT FOR JULY 1988 Unit 2 1.

Completed work on CCW traveling screens.

2.

Completed monthly/annual inspection on D/G 2A-A.

3.

Completed repair on 2A-A boric acid transfer pump.

4.

Completed repair on hanger 2-HGR-081.

5.

Installed new valve at 2-HCV-035-0557 (Generator Cooling System).

6.

Repairing main feed pump.

7.

Repairing amertap system.

8.

Completed testing containment personnel airlocks.

9.

Completed repair on generator bus duct cooler fan.

10.

Installed new valve at 2-HCV-027-0732, (Condenser Circulating Water).

Other Continued closure of various

CAQRs, CARs, DRs, etc.

"30-

MAINTENANCE

SUMMARY

(MODIFICATIONS}

SUHHARY OF CWORK COHPLETED HODIFICATIONS - CURRENT STATUS JULY 1988

P 0

Ma'or Ca ital Pro'ects:

PH7102:

ECH 5958 Re lace Peedwater Heaters 5 and 4

No work in progress at this time.

PH7105:

ECH 5009 E"sential Raw Coolin Water ERCW Pi in Chan cput From Carbon Steel to Stainless Steel No additional pipe replacement is scheduled in the ne..r future.

PH7108:

ECH 6720 Crane Consistenc Pro ram Unit 1 polar crane blocks and limit switch weights remain to be painted.

Unit 2 polar crane post modification testing by Electrical Maintenance is not complete.

Auxiliary Building crane (WP 12569) has completed review cycle.

Turbine Building 200 ton cranes (Unit 1/6720-04, Unit 2/6720-03) are currently in Plant Manager's office for approval.

Turbine Building 15 ton crane workplans (Unit 1/6720-06, Unit 2/6720-05) and 5 ton Service Building crane (6702-02) workplan are in the process of being written.

Modification of Turbine Building unit 2, 200 ton crane is scheduled to start August 15, 1988.

PN7115:

ECN 6719 Volumetric Intrusion Detection S stem ECN 6719 is in work.

Design is working on making the system functional.

Lighting is not finished.

Field Change Request (FCR) 6645 for DNE changes is approved.

Work is proceeding.

PN7122:

DCR 1373 Secondar Side No work in progress at this time.

ECN 5841 Mot Sho Fire Protection/Evacuation Alarm WP 12637 All fieldwork for evacuation alarm is complete.

Awaiting Work Request (MR) B240406 to be worked to restart fans to do functional test on fire protection.

4

Ma'or Ca ital Pro'ects cont.

PN713D:

DCR 1156 Poet Acrident Nonitorin This work is now scheduled for unit 1 cycle 4

(U1C4) and unit 2 by unit 2 cycle 4 (U2C4).

PN7132:

DCN DD26 Sewn e To*atnent Paoilit and Civil D vade Work has begun.

PN7136:

ECN 6259 MSR Tube Bundle Re lacement ECN is complete except for PMT and inservice leak test.

Leak checks will be performed during system heatup.

Unit 2 leak checks are complete.

PN7161:

ECN 5855 Re lacement of Doors A56 and A57 WP 11654 is complete.

PN7181:

DCR 1898 ECNs 6832 and 6596 Dr Active Waste DAW D~oildin Electrical interface work is complete.

Workplan closure held for Electrical Maintenance (WP 12478),

checks and update of SOIs by Operations, and Operations (WP 12477) pending RHSI-1 revision.

Si nificant Items:

PN7199:

Miscellaneous Activities Under 100 090 This was for various work orders prepared for work under 4100,000 total site cost.

This work was done as manpower resources were available.

Other Items:

ECN 5111 Provide Permanent Power to Manholes 42-46 FCR 4572R2 has been written to supersede 4572R1 for conduit and cable routing for manholes 42-46.

An instruction change form is being written to revise MP 12262 to incorporate latest design information on FCR 4572R2.

ECN 5503 Evacuation Alarms 0&PS/Fire Detection 0&PS Mork stopped for lack of funding.

ECN 5552 Condensate Demineralizer Modifications and High Crud Filter Upgrade to higher range instrumentation for condensate demineralizer system neutralization and nonreclaimable waste pumps.

WP 5552-03 Fieldwork is complete.

ECN 5609 Evacuation Alarm/Fire Detection Valve 26-290 MP 12387 is 90 percent complete.

No work is in progress at this time.

ECN 5609 Alteration to the Makeup Water Treatment Plant MP 12576 Work is approximately 75 percent complete.

Hold for Electrical Maintenance to perform breaker tests.

Need resolution of instrument tab description from Division of Nuclear Engineering.

MP 12633 Mork is approximately 60 percent comolete.

Hold for instrument tab (478601-928) set point revision MP 12731 MP is approximately 60 percent complete.

Hold for in trument tab (478601-928) et points.

Need connection diagram revisions from Division of Nuclear Engineering.

MP 12684 MP is approximately 70 percent complete.

Hold for instrument tab (478601-928) set points.

Need connection diagram revision from Divi ion of Nuclear Engineering.

WP 12665 - MP is on hold for outage and is 95 percent complete.

MP 12682 WP is on hold for outage and is 80 percent complete.

ECN 5626 Containment Ladders, Unit 1 Modifications needs additional design information to complete.

DNE needs to issue all drawing" listed on this ECN.

Work has not begun because of this holdup.

"33"

ll

Other Items cont.

ECN 5841 - Hot Shop Fire Detc tion WP 12360 is complete.

Workplan in closure cycle.

Need drawing deviation completed.

ECN 5935 Correct Power Block Lighting Deficiencies WP 12437 is complete.

WP 12275 is in work.

Need workplan revision for FCR 7706 to add approximately 40 more lights.

WP 5935-01 is field complete.

ECN 6057 Cable Tray Covers Work is complete.

ECN 6196 Pressurizer Hangers and Valves PMT is scheduled for unit 1 restart.

Remaining unit 2 work is scheduled for U2C3 refueling outage.

ECN 6357 Essential Raw Cooling Mater (ERCW) Roof Acce s and Rails for Security Equipment WP 12238 is in work and is approximately 40 percent complete.

ECN 6388 Hydrogen Honitors in Switchyard WP 12223 Mork has been stopped duo to a lack of funding.

ECN 6429 Component Coolin Heat Exchanger B Replacement Plato head exchanger and frame is complete.

Hangers and pipe which can be installed prior to outage i" in work.

Workplan to remove old heat exchanger is in review cycle.

DNE procuring the remaining needed piping material.

Estimated completion date for nonoutage work is during the month of October 1988.

ECN 6455 - Upgrade CU-3 Box Battery Packs MP 12295 is field complete.

Other Items cont.

ECN 6543 Install Public Safety Access Portals and Modify Entrance Road Work is being held pending the release of drawings from DNE.

ECN 6601 Removal of Unit 1 Emergency Gas Treatment System (EGTS)

Backdraft Dampers PMT remains to be completed by the Mechanical Test Section.

Fieldwork is complete.

ECN 6610 Modify Air Return Fan Supports Work is complete.

ECN 6689 Relocation of Main Steam Power Operated Relief Valves (PORV)

All work is complete for unit 2.

Work on unit 1 in calibration stage.

WP 12172 (tubing reroute) is 99 percent complete and holding for material consisting of tube fittings and clamps (PR 08-2768).

ECN 6698 Repull 120-Volt Cables Work is complete.

ECH 6706 79-14 Support Enhancement/Lost Calculations Repairs continue on unit 1.

This project has been combined with the calculation regeneration project for unit 1.

Unit 2 work is complete and workplans are closed.

There are 30 modifications in work with 168 complete.

In addition, 20 maintenance items are in progress with 607 complete.

ECH 6 739 A 1 terna te Analysis All unit 1 modification work has been completed.

Review and closure has begun.

Work is in progress on the maintenance items.

ECN 6742 Install Fuses in Radiation Monitor Power Supply Circuits Work is complete.

ECH 6761 - East Valve Room (EVR) Blowout Panel Unit 1 work is complete.

Unit 2 wor'k is complete.

"35-

D I

Other Items cont.

ECN 6784 Documentation to Show pipe Class Break Final closure is awaiting a revision to AI-19 deleting requirements to mark shift supervisor drawings.

ECN 6815 500ks switchyard Addition Install 500kV power circuit breaker and associated equipment for bay 1.

Retire 16lkV PCB and associated equipment.

A total of 10 workplans will be required.

Foundations and conduit installation (WP 12654) are complete.

MP 12740 for lighting, drain pipe, and surface ground mat is 80 percent complete.

MP 12739 for the structural steel installation is 95 percent complete.

WP 6815-02 is 80 porcent complete.

MP 6815-01 and WP 6815-03 are 80 percent complete.

MP 6815-04 and WP 6815-05 for the electrical control board, main relay boards, and the communications room are 90 percent complete.

WP 6815-06 for the addition of the Franklin solid state relay cabinets is field complete.

The Watts Bar No.

1 line was energized by bay 1 on June 21, 1988.

Energization of the Franklin line has been delayed because of problems with an existing power circuit breaker (PCB 5028),

and because of incorrect supply voltage for the static relay carrier sets.

ECN 6860 Control Room Bullet Resistivity DCR 2268 -

ECN 6860 MPs 12602 and 12604 are field complete.

WP 12603 is held for disposition of CAQR 880183.

WP 6860-01 is held for material on Contract 74014A.

Essentially all work is complete except for pull

handles, replacement of door closures, and rework of one lockset.

Estimated date of completion is September 30, 1988.

MP 12605 is in closure cyclo.

ECN 7078 Install Hangers Main Steam Piping Complete except for final inspections during heatup.

DCN X00006A Remove Hydrogen Analyzers Tubing The workplan lacks PMT (SI-219)

~

ECN 7078 - Install Hangers - Main Steam Piping Complete except for final inspections during heatup. -4 jwu

ee Other Items cont.

ECN 7093 Replacement of F"edwater Pipe Work is in progress and is 98 percent complete.

Remaining work is held pending maintenance activities.

DCN 2000188 Install Needle Valve for Hydrogen Analyzers The workplan lacks PMT (SI-219).

DCN 7D Hydrogen Analyzer Check Valves The woekplan lacks PMT (SI-219).

DCN 192 Pressurizer Loop Seal Work is complete.

DCN 341 Pressueizee Drain Pipe/Hangers Work is in progress.

Instrumentation Verification Peo ram For unit 2, there have been 953 discrepancies issued to MODS to date with 476 not required for restart.

All discrepancies required for eestart have been completed; 69 nonrestart discrepancies are open.

For unit 1, theee have been 532 discrepancies issued to MODS to date with 218 not requieed for restart.

Of 314 required for restart, all are complete.

DCN 224 RHR Slope Rewoek Teain A complete, Train B needs outage.

ECN 7318 Capillary Tray Hanger Rework Complete.

DCN 27 Double Isolation Valves In work.

ECN 7345 Valve Shims Work complete, workplan in closure cycle.

DCN 373 Flex Hose Rework In work.

~ ~

Other Items cont.

DCH 214 AFH Tap Rotation

Complete, Instrument Maintenance to test.

DCH 242 Sense Line Hangers Tn work.

DCH 19B ice Conden-"ate Expansion Bellows Work is in process.

DCNs 229 and 231 H2 Analyzer Modification Mork is in progress on unit 1.

DCN 300 ERCM modifi.cation for microbiologically induced corrosion (HIC) A train is complete, B train in work.

Mork is in progress on unit 1.

ECN 6596 MP 12402 - Workplan is closed.

WP 12612 Complete.

" Closure in process.

SOIs are complete.

SI-743 is in the process of being updated by Electrical Maintenance.

~ ~

tj

CORRECTIONS

I ~

0

'4

Corrections:

Please find attached a correction to the June Monthly Operating Report, page 19.

All items with an asterisk

(~)

were revised.

~ g

+4

OPERATING DATA REPORT DOCKET NO.

50-328 DATE JULY 25.

1988*

COMPLETED DY D-C. DUPRE.f.-

TELEPI.IQNE

( 61 5 ) 870-67:>2 OPERATING STATUS 1.

UNIT NAME:

SEQUOYAH NUCLEAR PLANT> UNIT 2

2.

REP QR T PER IOD:

JUNE 1988 3.

l.iCENSED THERMAL POWER (MWT):

3411. 0 4.

NAMEPLATE RATING.<GROSS MWE):

1220. 6 5.

DESIGN ELECTRICAL RATING (NET "lWE):

1148.0

>MAXIMUM DEPENDABLE CAPACITY (GROSS MWE):

1183. 0 7.

MAXIMUM DEPENDABLE CAPACITY (NET MWE):

1148 0

8.

IF CHANGES OCCUR IN CAPACITY RATINGS( ITEMS NUMBERS 3 THROUGH 7) SINCE LAST REPORT>

GIVE REASONS:

NOTES:

9.

POWER LEVEL TO WHICH RESTRICTED> IF ANY<NET MWE):

10.

REASONS FQR RESTRICTIONS> IF ANY:

THIS MONTH YR. -TO-DATE CUMULATIVE 1.

l.fDiRS IN REPORTING PERIOD 2.

Nf;MBER OF HOURS REACTOR WAS CRITICAL 13.

?""'ACTOR RESERVE SHUTDOWN HOURS 14.

'HCAJRS GENERATOR ON-LINE 15.

UNIT RESERVE SHUTDOWN HOURS 16.

ROSS THERMAL ENERGY GENERATED (MWH) 17.

GROSS ELECTRICAL El'JERGY GEN.

(MWH) 18.

'fET ELECTR ICAL ENERGY GENERATED (MWH) l9.

UNIT SERVICE FACTOR 20.

UNIT AVAILABILITYFACTOR 21.

UNIT CAPACITY FACTOR (USING Mi)C NET) 22.

UNIT CAPACITY FACTOR (USING DER NET) 23.

UNIT FORCED OUTAGE RATE 24.

SHUTDOWNS SCHEDULED OVER NEXT 6 MONTHS 720. 00 404. 1$

0. 00 314. 77

0. 00 820272. 14 265390. 00 240870. 00*

43. 72

43. 72

29. 14*

29. 14*

56. 28 (TYPE>

DATE>

4367. 00

.">3328. 00 785. 10 22769. 64

0. 00

0. 00 680. 75

>2174. 97

0. 00

0. 00 1600976. 36 70728953. 58 514930. 00 2405>1710. 00 417026. 00* 22925171.

60'5.

59

41. 58

15. 59

41. 58

8. 32*

37. 45

8. 32*

37.

45'4.

41

54. 21 AND DURATION l)F EACH):

25.

il'-'HUTDOWN AT END QF REPORT PERIOD.

ESTIMATFD DATE OF STARTUP:

iTEMS HAVE BEEN REVISED NOTE lHAT THE THE YR.-TO-DATE AND CUMULATIVE VALUES HAVE BEEN UPDATED (

0 lq I

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