ML20151L327

Monthly Operating Repts for Mar 1988

ML20151L327
Person / Time
Site:	Sequoyah
Issue date:	03/31/1988
From:	Dupree D, Shawn Smith TENNESSEE VALLEY AUTHORITY
To:	NRC
References
NUDOCS 8804220020
Download: ML20151L327 (53)

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TENNESSEE VALLEY-AUTHORITY OFFICE OF NUCLEAR POWER SEQUOYAH NUCLEAR PLM;T-i MONTHLY CidRATING REPORT TO THE NUCLEAR REGULATORY COMMISSION MARCH 1988 UNIT 1 DOCKET NtHBER 50-327 LICENSE NUMBER DPR-77 7

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UNIT 2 DOCKET NUMBER 50-328 LICENSE NUMBER DPR-79 Submitted by b

1,S.J. Smith,PlantManager 8804220020 880331 s

PDR ADOCK 05000327 (I [

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TABLE OF CONTENTS

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Operational Summary Performance Summary 1

Significant Operational Events 1-2 Fuel Perf..mance and Spent Fuel Storage Capab i'. it?es 3

PORVs and ;afety Valves Summary 3

Epecial Reports 3-4 Licensee Events 5-12 Offsite Dose Calculation Manual Changes 13 II.

Operating Statistics A.

NRC Reports Unit One Statist 1cs 14-16 Unit Two Statistics 17-19 B.

TVA Reports 20 Nuclear Plant Operating Statistics 21 Reactor Histogram 22 Unit Outage and Availability 23-24 F

III. Maintenance Summary Electrical Maintenance 25-26 Instrument Maintenance 27-29 Mechanical Maintenance 30-32 Modifications 33-42 IV.

Offsite Dose Calculation Manual Changes 9

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OPERATIONAL SU> NARY i

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t PERFORMANCE SUPARY March 1988 T e following summary describes the significant operational activities for t > month of March.

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

The units remained in an administrative shutdown the entire month because of design control review, configuration control updating, and resolution of significant employee concerns.

Outage-related maintenance and modifications are being performed. Unit I has been off line 952 days.

Unit 2 has been off line 953 days.

Preparations continue for unit 2 alignment and power operation.

SIGNIFICANT OPERATIONAL EVENTS Unit 1 Date Time Event 03/01/88 0001E The reactor was in mode 5.

The administrative shutdown due to design control review, configuration, control updating, and resolution of significant employee concerns centinues.

03/31/88 2400E The reac*or was 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 03/01/88 0001E RCS at 526 degrees Fahrenheit, 1780 psi.

• cparacions are underway for power operation.

Various activities for modes 2 and 1 are proceeding.

03/15/8P 0010E h0S at 532 degrees Fahrenheit. 1810 psi.

1100E RCC at 547 degrees Fahrenheit, 2000 psi.

1150E RCS at 547 4 agrees Fahrenheit, 2235 pai.

Maintenance continues for operation.

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Unit 2 Time _

_ Event i

Date' i

03/16/88 0036E Manually tripped the reactor to comply with LCO 3.1.3.3.

Control bank "D" group 1 step counter failed to indicate rod steps.

The rod demand counter was steater than two steps from step counter.

03/?7/88 0639E While performing a rod drop test on control bank "B," group 1 demand-counter was indicating "10" steps greater than group 2.

Manual reactor trip to comply with LCO 3.1.3.3..

Rod drop testing continues.

03/19/88 2314C While testing shutdown bank "B " group demand position indicators were indicating greater than two steps between group 1 and group 2.

Manual reactor trip to comply with LCO 3.1.3.3.

03/22/88 0923E Maintenance completed on all control / shutdown banks.

.03/24/88 0130E Received an MFI while working on the reactcr trip bypass breaker.

0131E Reset MFI, 03/31/88 2005E Began cooldown to 375 degrees Fahrenheit for maintenance on the pressuriner safety valves.

2343E

.RCS at 375 degrees Fahrenheit 900 psi.

2400E RCS at 375 degrees Fahrenheit 900 psi. Activities continue for power operation.

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FUEL PERFORMANCE Unit 1 The core average fuel exposure accumulated during March was O MWD /MTU with the total accumulated core average fuel exposure of 0 >ND/MTU.

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Unit 2 The core average fuel exposure accumulated during March was O MWD /MTU with the total accumulated core average fuel exposure of 8097.51 MWD /MTU.

SPE.Yf FUEL PIT STORAGE CAPABILITIES The total storage capability in the SFP is 1,386. However, there are five cell locations which are incapable of storing spent fuel.

Four locations l

(A10, All, A24, and A25) are unavailable due to a suction strainer conflict, l

and one location (A16) is unavailable due to an instrumentation conflict.

Presently, there is a total of 348 spent fuel bundles stored in the SFP.

i Thus, the remaining storage capacity is 1,033.

PORVs AND SAFETY VALVES

SUMMARY

PORV block valve FCV-68-332 was closed for PORV leakage. There was no temperature change in the tail pipe. When FCV-68-332 was reopened, causing a temperature increase, FCV-68-340 (Unit 2) opened momeatarily.

No safety valves were challenged in March 1988.

SPECIAL REPORTS The following special reports were submitted to NRC in March 1988.

A8-04 On February 13, 1988. fire door A-62 (auailiary building, Unit 1 elevation 690, penetration room) was nor. functional for an interval great. than seven days. The active Icaf of the door had malfunctioned prohibiting proper closing. Although the door is capable of being closed and latched, the top one-half of the active leaf leaves approximately 3/4-inch mismatch with the door frame and does not meet acceptance criteria of the SI for functional fire door. A roving fire watch has been established and will continue until all repairs are completed.

88-05 On February 24, 1988, at 1630E, a cable tray fire barrier Unit 2 penetration located in the auxiliary building, elevation 774 (control rod drive equipment room) was nonfunctional for an interval greater than seven days.

This event was due to personnel error.

The tray was breeched to replace the existing cables with new ampacity cables required by a workplan. After resealing the tray.

it was realized that flarwastic material was not used in the sealing application. The tray was resealed using the flammastic and returned to operable status March 2, 1988.

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SPECIAL REPORTS (continued) 88-06 On March 3,1983, fire door A-29 (auxiliary building, Unit i elevatf.on 669, 13-3 charging pump room) exceeded the seven-day limit allowed by TS LCO 3.7.12.

It was open to facilitate maintenance being 7erformed on the 1B-3 charging pump. A fire watch has been established, and the door will be returned to operable status after all activities are completed.

88-01 This revisi:n provides clarification to the description and analysis Unit 2 of event concerning two doors which we breeched greater than seven Rev. 1 days.

9 LICENSEE EVENT REPORT (S)

The following licensee event reports (LERs) were transmitted to the Nuclear Regulatory Commission in March 1983.

Descriotion of Event LER 1-88010 On February 5, 1983, it was determined that the procedure governing the stroke time testing of ASME Sect. ion XI MOVs was inconsistent with the SQN design documents (FSAR and SQN Design Criteria) for two ESF actuated valves.

Further investigation revealed that the acceptance criteria for MAST that was contained in the subject procedure was nonconservative with respect to the FSAR.

A review of SQN records determined that the measured stroke times for all previous tests of the subject valves were within the MAST assumed in the SQN FSAR.

The deficiencies in the subject procedure were caused by an inadequate determination of the valve's design basis which was then used to determine che valve-specific MAST.

Following the discovery of this condition, permanent procedure changes to incorporate the appropriate MAST for the subject valves and the retesting of each valve to verify that the measured stroke times were less than the newly implemented MAST.

To prevent recurrence of this event. TVA is reviewing the MAST for all safety-related MOVs against requirements in the TS, the SQN Design Criteria, and the FSAR to ensure MAST for each valve has been incorporated into the procedure.

1-88011 On February 16, 1988, at approximately 0030E, it was determined that LCO 3.0.5 had been in effect since approximately 2340E the previous day because both trains of the CREVS had been inoperable since that time.

Train "A" of CREVS was inoperable because its emergency power source (D/G 1A-A) had been taken out of service for routine testing, and train "B" of CREVS had previously been declared inoperable to replace fire detectors in the ductwork.

Upon discovery of this event, Operations personnel were immediately dispatched to the D/G building with instructions to return D/G 1A-A to service. At approximately 0037E on February 16, 1988. D/G 1A~A was returned to service and LCO 3.0.5 was exited.

The event was caused by an inadequate review of the applicable TS before removing a D/G from service.

The shift supervisor on shift when the D/G testing was initiated was cognizant that removing D/G 1/A-A from service would make train "A" of CREVS inoperable; however, he did not confirm the TS required actions that must be taken when both trains nf CREVS are inoperable. A wor < control group has been established to assist the centrol room shift crew by determining the impact of work activities on the plant.

In addition, the procedures that are used to remove D/Gs from service have been revised to include precautions that specifically address the potential for causing other equipment or systems to be inoperable when D/Gs are taken out of service.

These actions should prevent recurrence of this event; however, an evaluation is continuing to determine if additional control measures are I

appropriate.

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4 Descriotion of Event LER 3

l-88012 On March 1, 1988, at 0243E, a CVI occurred caused by a spurious signal from EMI in the lower containment RM circuits.

The EMI was caused by a low flow condition in the RM sample line resulting in the alarm circuit alternately energizing and deenergizing.

This condition was caused by the associated profilters clogging from suspended particulate in the vicinity of the RM caused by grinding and welding work being performed.

As corrective action, the operators determined that a high radiation condition did not exist.

The prefilters were changed once per shift, and the CVI was reset.

At approximately 1545E, a second CVI occurred from the same cause.

The prefilters were then replaced every four hours, and the CVI was reset.

Corrective actions for CVIs were completed on March 17, 1988.

These corrective actions included provisions to reduce EMI induced CVIs through improved cable grounding, removing local audible alarms, and providing a "seal in" feature in alarm circuits susceptible to relay chatter.

1-87001 This revision provides additional details concerning incorrect trip Rev. I setpoints for air circuit breakers on the shutdown boards that feed the control and auxiliary building vent boards that have been discovered subsequent to the original submittal.

1-87006 This revision provides additional information relating to the Rev. I corrective action taken to verify the proper operation of all equipment affected by an SI signal.

1-87027 This revision provides additional information obtained during an Rev. 1 investigation of ERCW valves that were found to be mispositioned and additional details of the corrective actions taken.

1-87037 This revision provides additional information relating to the Rev. I corrective action taken to ensure that the ESF area / room coolers have sufficient cooling capacity.

It also includes additional information relating to an auxiliary building backdraft damper.

1-87046 This revision provides additional information relating to TVA's Rev. 1 safety evaluation of the potential for diluting the ECCG recirculation flow following a large break loss of coolant accident.

1-87070 This revised event report provides additional information relating Rev. 3 to the schedule for installation of new D/G voltage relays and a delay in the implementation of D/G postmaintenance testing procedures.

Description of Event LER 1-88501 This revision updates the cause of event and corrective action Rev. 1 sections.

2-88005 On February 12, 1988, at approximately 1133E, smoke was discovered coming from the speed increaser unit for the 2A-A CCP.

Immediately, the 2B-B CCP was started, and the 2A-A CCP was stopped.

Upon disassembly of the 2A-A CCP speed increaser, much of the internals were found damaged.

Further investigation revealed that the two gland seal retaining bolts inside the speed increaser lube oil pump backed out allowing the gland seal to loosen causing reduced oil flow to the speed increaser internals and. ultimate damage. The 2B-B and 1B-B speed increaser oil pumps were inspected, and the same gland seal bolts as those on the 2A-A pump were loose. The cause was determined to be a lack of a periodic adjustment of the gland seal bolts.

The original lube oil pumps had been replaced previously with incorrect pumps. These pumps had been ordered using an incorrect part number in April 1985.

The replacement pumps for 1B-B, 2A-A, and 2B-B were rated for 900 rpm and incorporated a compression packing seal which required periodic adjustment as the packing wears. The original pumps were rated for 1,800 rpm (actual pump speed in this application) and incorporated a mechanical seal which did not require adjustment. The major cause of this event was the lubs oil pumps for IB-B, 2A-A, and 2B-B l

incorporated the packing seal, and no program was in place to i

periodically tighten the bolts. The'2A-A lube oil pump was replaced with a 1,800 rpm pump on February 15, 1988, and two new pumps 1,800 rpm) have been procured for IB-B and 2B-B.

These pumps are expected to be replaced by March 19, 1988, and the 1A-A lube oil pump gland bolts are expected to be inspected by April 1, 1988. To prevent recurrence, a new procurement program is in place which provides additional independent review / verification of all plant-initiated procurement documents.

1 2-88006 On February 7, 1988, at 2141E with unit 2 in mode 4, an MSI occurred and a reactor trip signal was generated by the ESFA system.

This event was generated from the symptoms of main steam line break--low S/G pressure, low-low average RCS temperature, and a high steam line flow signal.

The S/G pressure and RCS temperature conditions existed because the unit was in mode 4.

The high steam line flow signal was generated when opening the MSIVs l

due to the inherent design of the steam flow program generator and maintenance in progress. The reactor trip signal coincident with a low RCS temperature caused an MFI.

When the MSIVs closed, the S/G 1evels experienced "shrunk" to the low S/G setpoint.

Coincident i

with the low S/G 1evel, the steam flow /feedwater flow mismatch 2

bistable was tripped in loop 4 for maintenance resulting in a j

second : eactor trip signal.

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Description of Event LIR 2-83006 The plant was stabilized. An attempt to open one MSIV was made at (Cont 'd) 2535E. This resulted in S/G 1evel "swell" above the high-high S/G 1evel setpoint resulting in a turbine trip signal and a second MFI.

The causes of these events were im oper compliance with procedures, nuance between ope-ating procedures, human factor engineering of plant equipment, a steam dump valve not fully seated, and maintenance activities not fully evaluated for plant evolutions in progress.

Corrective actions for this event are as follows:

(1) procedures have been changed and/or are being recategorized; (2) temporary instrumenP.ation was installed for plant measurements; (3) the steam dump valve positior.er was adjusted; and (4) a plant statement has been made to address maintenance activities for protective equipment.

2-88007 On February 10, 1988, at 022SE, with unit 2 in mode 4 (480 psig, 250 degrees Fahrenheit) an MSI signal was generated as a result of the high steam flow bistables being tripped while performing a calibration of channel I turbine impulse pressure transmitter. At the time of this event, the main steam system was in operation to control the RCS temperature. Tripping two out of four loops high steam flow bistables with the existing low-low T Operating ave temperature (below 540 degrees Fahrenheit) or steam line pressure low (below 500 psig) condition simulated high steam flow condition which resulted in an MSI. The U0s took immediate action to suspend the calibration activity and stabilized plant conditions.

To determine the cause of the actuation which occurred on February 7, 1988, it was decided to verify the accuracy of the channel I and channel II turbine impulse pressure transmitters.

The event occurred due to an inadequate calibration procedut2 and weak communication between Maintenince personnel and the operators.

The channel I and channel II turbine impulse transmitters provide input to the high steam line flow setpoint reference controllers to program a steam line flow reference for each channel. The channel I reference is provided as one of the inputs to "A"

train, and channel II reference is provided as one of the inputs to "B" train deviation bistables on each S/G with the other input being actual steam line flow.

As a corrective action, channel I and channel II turbine impulse pressure transmitter calibration procedures are being revised, and a work control group has been established to review plant operation impact before authorizing maintenance work.

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4 Description of Event LER 2-38003 On February 9, 1958, with unit 2 in mode 4 (hot shutdown), it was determined that SI-137.2, "Reactor Coolant System Water Inventory,"

was not completed within the time interval required by TS 3/4.4.6.2.

It is performed every 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> when the plant is in modes 1 through 4 to determine the total unidentified RCS leakage.

If the total unidentified RCS leakage exceeds 0.34 gpm, additional calculations are performed to determine.the primary to secondary leak rate (based on S/G activity levels).

During the February 8, 1988, performance, personnel were unable to obtain a timely S/G liquid sample because of the low pressure. As a result, the completion of SI-137.2 exceeded the 72-hour time limit required by TS.

The event was caused by personnel not initiating the performance of SI-137.2 until just before the time it should have been completed.

Once the SI was initiated, complications with obtaining a liquid sample extended the completion of the subject SI beyond the time interval allowed by TS.

However, following the completion of SI-137.2, it was verified that no primary to secondary leak rate was present, and the action statement associated with TS 3/4.4.6.2 was exited.

To prevent recurrence of this event, personnel have been instructed to allow sufficient time to complete SI-137.2 without entering the 25-percent extension allowed by the TS 4.0.2.

In addition, alternate methods of sampling the S/Gs when secondary system pressures are too low to obtain a liquid sample using standard methods are being evaluated.

If alternate sampling methods are identified, SI-137.2 will be revised to incorporate them.

Also, the feasibility of implementing a plant modification will be implemented to provide a means of obtaining a S/G liquid sample with low secondary system pressures.

2-88009 On February 28, 1988, at 1737E with unit 2 in mode 3 (hot standby) an MSI ESFA occurred generated by the RCS temperature being below the ESFA setpoint due to the established mode 3 temperature and a high steam flow protection bistable in the tripped position in two of the four main steam line loops in order to support maintenance.

Upon closure of the MSIV, the senior reactor operators in the control room realized the cause of the actuation and requested the mechanics who had tripped the bistables to return them to their normal position. At 2057E, the bistables were returned to normal.

At 2112E, the MSIVs were reopened.

The cause of this event is attributed to an improper verification of the required logic that will generate the ESFA signal.

Two loops of steam flow channels were released simultaneously for maintenance. To prevent recurrence, all unit 2 designated operators have been provided additional training on plant protection circuits.

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Description of Event LER 2-88010 on March 9, 19S8, at approximately 1930E, with unit 2 in mode 3, an NRC inspector discovered the handseitch for CCP 2A-A in the "PULL-TO-LOCK" position.

An investigation of this incident determined that CCP 2A-A had been in this position since approximately 1316E that afternoon and, therefore, had been inoperable since that time. Also, CCP 2B-B which had previously been out of service to perform maintenance, had also been inoperable until approximately 1440E that same day. As a result, unit 2 had inadvertently entered TS LCO 3.0.3 and had been in that LCO for approximately 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> and 24 minutes.

Upon discovery of this event, Operations personne1'immediately returned CCP 2A-A to service by placing it in the "AUT0" position.

The event was caused by the day shift UO not recognizing that placing the pump in the "PULL-TO-LOCK" position would result in it being inoperable during plant operation in mode 3.

The failure to recognize the inoperability of a CCP when it is in the "PULL-TO-LOCK" position was possibly the result of the day shift operator not fully understanding a TS interpretation. To prevent recurrence of this event. TVA is reviewing all TS interpretations currently in use and evaluating other TS to determine if a TS change is necessary to clarify the CCP operability requirements.

In addition, changes to administrative procedures have been initiated and will provide additional training to Operations personnel relating to the use of TS during off-normal plant operations.

2-87003 This report provides additional details concerning a failure to i

Rev. 2 perform an inspection on ASME Section XI equipment due to procedural inadequacy.

One of the areas had previously been determined not to require a pressure test inspection. A second area has recently been reclassified and also does not require a pressure test inspection.

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'AB3REVIATIONS Page 1 of 2

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Auxiliary Building Gas Treatment System 1..

ABGTS Auxiliary Building Secondary Containment Enclosure 2.

ABSCE.

Auxiliary Building Isolation 3.

ABI 4.

AFW

- Auxiliary Feedwater

-5.

AOI

- Abnormal Operating Instruction Assistant Unit Operator 6.

AUO Boric Acid Storage Tank 7.

BAT Boron Injection Tank 8.-

BIT Condition Adverse To Quality Report 9.

CAQR

' Centrifugal Charging Pump 10.

CCP Component-Cooling Water

11. CCW-Control Room Isolation

12. -CRI Control Room Emergency Ventilation System

13. CREVS Containment Spray System 14.

CSS (CS)

Containment Ventilation Isolation

-15.

CVI 16.

D/G(s)

- Diesel Generator (s)

Design Change Request

17. DCR Division of Nuclear Engineering 18.

DNE Emergency Core Cooling. System 19.

ECCS.

Engineering Change Notice 20.

ECN t

Emergency Gas Treatment System 21.

EGTS Electromagnetic Interference 22.

EMI Environmentally Qualified / Environmental Qualification 23 EQ Essential Raw Cooling Water 24.

ERCW Engineered Safety Feature (Actuation) 25.

ESF(A)

Flow Control Valve 26.

FCV Final Safety Analysis Report 27.

FSAR Feedwater Isolation 28.

FWI General Operating Instruction 29.

GOI Callons Per Minute

30. GPM Hold Order

31. H0 Instrument Maintenance Instruction 32.

IMI Limiting condition for Operation 33.

LCO Loss Of Coolant Accident 34.

LOCA Maximum Allowable Stroke Time

35. MAST Main Feedwater Isolation

36. MFI Motor Operated Valve

37. MOV Main Steam Isolation

38. MSI Main Steam Isolation Valve

39. MSIV Main Control Room 40.

MCR Nuclear Security Service 41.

NSS.

Nuclear Steam Supply System 42.

NSSS Plant Operation Review Committee 43.

PORC I

Potential Reportable Occurrence 44.

PRO Reactor Coolant System 45.

RCS 46.

RHR

- Residual Heat Removal t

Radiation Monitor (RAD Monitor / RAD MON) 47.

RM Refueling Water Storage Tank 48.

RWST Significant Condition Report 49.

SCR Spent Fuel Pit 50.

SFP

4 ABBRrVIATIONS Page 2 of 2 51.

S/G(s)

Steam Generator (s) 52.

SI Surveillance Instruction /or Safety Injection 53.

SMI Special Maintenance Instruction 54.

SOI System Operating Instruction 55.

SQN Sequoyah Nuclear Plant 56.

SR Surveillance Requirement 57.

SSPS Solid State Protection System

53. TACF Temporary Alteration Control Form 59.

TI Technical Instruction 60.

TS(s)

Technical Specification (s)

~

61.

CO Unit Operator 62.

WP Workplan 63.

WR Work Request

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0FFSITE DCSE CALCULATION MANUAL CHANGES No changes were made to the SQN Of fs;te Dose Calculation Manual (0DCM) in March 1988.

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4 OPERATING STATISTICS (h1C REPORTS) 9 O

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WER A f 4:<G DATA REPORT DOCKET NO. 50-327 DATE APRIL 05, 1988 COMPLETED DY D.C.DUPREE TELEPHONE (615)S70-6722 CPERATING GTATUS 1.

UNIT NAME: GEQUOYAH NUCLEAR PLANT, UNIT 1

NOTES:

2.

9EPORT PERIOD: MARCH 1983 3.

L ICENSED THERMAL POWER (MWT).

3411.0 4.

N AMEF LATE R ATING (GROSS MWE):

1220.6 5.

DESIGN ELECTRIC AL RATING (NET MWE):

1148.0 6.

MAXIMUM DEPENDAGLE CAPACITY (GROSS MWE):

1183.0 7.

MAXIMUM CEPENDADLE CAPACITY (NET MWE):

1148.0 8.

IF CHANCES OCCUR IN CAPACITY RATINGS (ITEMS NUMDERS 3 THROUGH 7)SINCE LAST REPORT. GIVE REASONS:

z.

9 PCWER LEVEL TO WHICH RESTRICTED,IF ANY(NET MWE):

10. "EASONS FOR RESTRICTIONS, IF ANY:

THIS MONTH YR.-TO-DATE CUMULATIVE

11. hCURS IN HEPORTING PERIOD 744.00 0184.00 59185.00

12. NLMBER OF HOURS REACTOR WAS CRITICAL O.00 0.00 24444.91

13. REACTOR RESERVE SHUTDCWN HOURS 0.00 0.00 0.00 14 HOURS GENER ATOR ON-LINE O.00 0.00 23781.13

15. UNIT RESERVE SHUTDOWN HOURS 0.00 0.00 0.00

16. GROSS THERMAL ENERGY GENERATED (MWH) 0.00 0.00 77060971.91

17. GROSS ELECTRICAL ENERGY GEN. (MWH) 0.00 0.00 2L976386.00

10. NET ELECTRICAL ENERGY GENERATED (MWH)

-4315.00

-18901.00 24835422.00

19. UNIT SERVICE FACTOR O.00 0.00 40.18

20. UNIT AVAILADILITY FACTOR O.00 0.00 40.18

21. UNIT CAPACITY FACTCR(USING MDC NET) 0.00 0.00 36.55

22. UNIT CAPACITY FACTOR (USING CER NET) 0.00 0.00 36.55

23. UNIT FORCED OUTAGE RATE 100.00 100.00 52.66

24. SHUTDOWNS SCHEDULED OVER NEXT 6 MONTHS (TYPE, DATE. AND DURATION OF EACH):

25..

IF SHUTDOWN AT END OF REPORT PERIOD, ESTIMATED DATE OF STARTUP:

S TAR T UP IS UNDETERMINED AT THIS TIME PENDING DESIGN CONTROL REVIEW, CCNFIGUHATION CONTROL UPDATING. AND RESOLUTION OF SIGNIFICANT EPPLOYEE CONCERNS.

NOTE 1 HAT THE THE YR.-TO-DATE AND CUMULATIVE VALUES HAVE DEEN UPDATED.

1' SBQUDYAH NUCMAR PIANT AVEIGGE DAILY poler IZVEL DOCIGTP 30. t 50-327 UNIT CEE DkN : APRIL 02,1988 CCMPWrED BY t D.C.DUPREE

'NIZPIEEE : (615)S70-6722 MWatt MARCH 1988 AVEIUGE DRILY POIER I2 VEL AVEIUGE DhILY PolfER IEVEL DAY

()Sfe Net)

DAY (Mite Net) 01 0

17 0

02 0

18 0

03 0

19 0

04 0

20 0

05 0

21 0

06 0

22 0

07 0

23 0

08 0

24 0

09 0

25 0

10 0

26 0

i 11 0

27 0

12 0

28 0

13 0

29 0

14 0

30 0

15 0

31 0

16 0

O UNIT SHUTDOWNS AND POWER REDUCTIONS DOCKET NO.

50-327 UNIT NAME Sequoyah One DATE April 1.

1988 COMPLETED BY D. c. Dupree REPORT !!0NTl!

March 1988 TELEPHONE (615)870-6722 m

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C cg oyu Licensee g-*,

en, Cause & Corrective Ng No.

Date o

ty gt=

Event u7 gj Action to o

g 3o g

gge Report #

>. o gu Prevent Recurrence m

e e.c c u

o

c un 3,n I

8E3101 F

744 F

4 Design Control, Configuration Updating, and Employee Concerns.

L T

3F: Forced 2Reason:

311ethod:

4 Exhibit G-Instructions S: Scheduled A-Equipment Failure (Explain) 1-!!anual for Preparation of Data B-!!aintensuce or Test 2-!!anual Scram.

Entry Sheets for Licensee C-Refueling 3-Automatic Scram.

Event Report (LER) File D-Regulatory Restriction 4-Cont. of Existing (NUREG-0161)

E-Operator Training & License Examination Outage F-A.iminis t ra tive '

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5-Reduction G-Operational Error (Explain) 9-Other 5Exhibit I-Same Source

!!-Other (Explain)

I OPERATING DATA REPORT DOCKET NO. 50-320 DATE APRIL 05, 1988 COMPLETED DY D.C.DUPREE TELEPHONE (615)D70-67P2 JFERATING STATUS 1.

UNIT NAME: SEQUOYAH NUCLEAR PLANT, UNIT 2

NOTES:

2.

REPORT PERIOD: MARCH 1983 3.

LICENSED THERMAL POWER (t1W T):

3411.0 4.

NAMEPLATE R ATING (GROSS MWE):

1220.6 9.

CESIGN ELECTRICAL RATING (NET MWE):

1148.0 6.

MAXIMUM DEPENDADLE CAPACITY (GROSS MWE):

1183.0 7.

MAXIMUM DEPENDADLE CAPACITY (NET MWE):

1140.0 8.

!F CHANGES OCCUR IN CAPACITY RATINGS (ITEMS NUMDERS 3 THROUGH 7)SINCE LAST REPORT, GIVE REASONS:

9.

5CWER LEVEL TO WHICH RESTRICTED,IF ANY(NET MWE):

10. REASONS FOR RESTRICTIONS, IF ANY:

THIS MONTH YR.-TO-DATE CUMULATIVE

11. HCURS IN REPORTING PERIOD 744.00 2104.00 51145.00

12. NLMDER OF HOURS REACTOR WAS CRITICAL O.00 0.00 21984.34

13. REACTCR RESERVE SHUTDOWN HOURS 0.00 0.00 0.00

14. HCURS GENERATOR ON-LINE O.00 0,00 21494.22

15. UNIT RESERVE SHUTDOWN HOURS 0.00 0.00 0.00

16. GGOSS THERMAL ENERGY GENERATED (MWH) 0.00 0.00 69127977.22

17. GFOSS ELECTRICAL ENERGY GEN. (MWH) 0.00 0.00 23536700.00

19. NET ELECTRICAL LNERGY GENERATED (MWH)

~22004.00

-42590.00 22465547.60

19. UNIT SERVICE FACTOR 0.00 0.00 42.03

20. UNIT AVAILADILITY FACTOR O.00 0.00 42.03 4

21. UNIT CAPACITY FACTOR (USING MDC NET) 0.00 0.00 38.26

22. UNIT CAPACITY FACTOR (USING DER NET) 0.00 0.00 38.26

23. UNIT FORCED OUTAGE R ATE 100.00 100.00 53.52

24. THUTDOWNS SCHEDULED OVER NEXT 6 MONTHS (TYPE, DATE, AND DURATION OF EACH).

25. IF SHUTDOWN AT END OF REPORT PERIOD, ESTIMATED DATE OF STARTUP:

TFE RESTART OF UNIT-2 IS APRIL 1989.

NOTE THAT THE THE YR. -TO-DATE AND CUMULeTIVE VALUES HAVE DEEN UPDATED.

SEQUO1 TAN NUCIZAR PUNI' AVERAGE DAILY POIEER 12 VEL DOCZET 10.

50-328 UNIT t 'I110 DATE : APRIL 02,1988 CXMPIATED BY : D.C.DUPREE TEIEPIONE (615)S70-6722 300mit MARCH 1988 AVERAGE DAILY PolfER IZVEL AVERM DAILY POWER IZVEL DAY (HBie Net)

DAY (10te Net) 01 0

17 0

02 0

18 0

03 0

19 0

04 0

20 0

05 0

21 0

1 06 0

'2 0

'I 07 0

23 0

08 0

24 0

09 0

25 0

10 0

26 0

I 11 0

27 0

i 12 0

28 0

13 0

29 0

I l

14 0

30 0

I 15 0

31 0

l l

16.

0 l l

O UNIT SHUIDOWS AND POWER REDUCTIONS DOCKET NO.

50_32g UNIT NAtiE Scouovah ?vo DATE April 1.

1988 C0t1PLETED BY D. c. Dupree REPORT !!ONTH March 1988 TELEPHONE (615)870-6722 E

w o

gg o yg Licensee g-2, ge, Cause & Corrective c*,

jg ggg Event gg gg Action to No.

Date o

y 3o g

ggm Report i gu gu Prevent Recuttence b~

?

1 880101 F

744 F

4 Design Control, Configuration Updating, and Employee Concerns.

l i

2 3

4 2F: Forced Reason:

Hethod:

Exhibit G-Instructions S: Scheduled A-Equipment Failure (Explain) 1-!!anual for Preparation of Data B-!!aintenance or Test 2-!!anual Scras.

Entry Sheets for Licensee C-Refueling 3-Automatic Scram.

Event Report (LER) File D-Regulatory Restriction 4-Cont, of Existing (NUREG-0161)

E-Operator Training & License Examination Outage F-Alministrative 5-Reduction 5

G-Operational Error (Explain) 9-Other Exhibit I-Same Source Il-Other (Explain) -

____v_.-.__

t OPERATING STATISTICS (TVA REPORTS) l 1 -

t TV A MM A (OrW.* H NUCLEAR PLANT OPERATING STATISTICS Sequoyah Nuclear Plant Period Hours 744 Month March

}9,88 Item No.

Urut No.

Unit 1 Unit 2 Plant 1

Averace Hourly Gross Lond. kW 0

0 0

a

.2 Maximum Hour Net Generstion MWh _

__0 0

0 2

0 0

0 3

. Core Thermal Energy Gen. cWDJt1 0

4 Steam Gen Therrnal Enes gy Gen., GWD (t)2 0

0 5

Gross Electrical Gen., MWh Q

0 0

j 26,319 r,

station use. MWh

4. 315___

22,004

-26,319 7

Net Electrical Gen., MWh 4.315

-22,004

{

C 8

Station Use, Percent N/A _ _.

N/A N/A 9

Accum, Core Avg. Exposure, MWD / Ton!

0 0

0 10 CTEG This Month.10 BTU 0

0 0

6 11

$GT EG This Month,106 BTU 0

0 0

19 13 Hours Reactor Was Critical 0.0 0.0 0.0

' O.00 0.00 0.00 14 Umt Use Hour 5. Min.

15 Capacity Factor, Percent 0.0 0.0 0.0 I

]6 Tusbine Avail. Fastor, Per(ent 0.0 0.0 0.0

$.,_17..flestor Avad Fa ctor. Percent 0.0._

0.0 D

g ' 18 Turbocen Avail. F'allor Percent 0.0 0.0 0.0 19

_ Reactor Ava3Llaenfenent 0.0 0.0 0.0 3

,1 Unit Avad. Factor Percent

_J. 0 0.0 0.0

. 21 Tuibre startuns 0

0 0

.1 Jeactor Coldtartuns 0

0 0

n N/A 24 Gross Heat Rate, Htu/kWh N/A.

_EA O

f 25 Net he.n T' ate. Blu/kWh N/A 3

26 n

28 Throttle Pressure, pseg N/A N/A N/A f

79 Throttie Tempera;ure. F N/A N/A N/A a8 30 r abaust Pressure. InHg Abs.

N/A N/A N/A

• U*\\

f A. Intake Water Temp., 'F N/A N/A 32 33 Main Feedwater. A.b/h' N/A

_ N/A N/A

{

4 35 i

r, JQ/ &_

363.65 168.51 l

37 Full Power Capacity, E FPD t

38 Accum. Cycle full Power Days. EFPD 0.0 210.8416 210.8416 2,574 N

39 Oil F ired for Generation, Galtons 138.000 1

5 _iQ_.

00 Heatma Vatue. btu! Gal.

39 i

41 J1rigtceneration MWh D

~

i Man. Hour Net Gen.

Man Day Net Gen.

Load l

MWh Time Date MWh Date Factor, %

43 v/3 N/A N/A N/A N/A N/A

_p R emar k s - A F or UF NP this value is MWD /ST U and for SONP and WBNP this value is MWD /MiU.

j 2(t) indicates Thee mal Energy.

3 1,

I "2I"

[vy v v Date Submitted Date Revised Plant $operinterwent

iw <,.

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~

SEQUOYAH ONE REACTOR HISTOGRAM

>U.

110 -

L iOO -

90 -

80 -

l 70 -

E

.0 f

30 -

a-g

..u 30 -

9 20 '

10 -

O 0 --~4W e

-iO -

i 0

4 8

12 14 20 24 28 32 WARCH 1948 SEQUOYAH TWO REACTOR HISTOGRAM 110 100 -

90 -

I l

1 n-l p

70 -

U 60 -

• ~

40 -

g Q

n-r 20 -

l 10 --

O-O O

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8 12 16 20 24 28 32 WARCH 1988

4 1 vA c%eC t.* 176)

+

Ots:T OUT AGE At40 AVAft.ABit.fiY i

SFQUOTAll f aixtca, 51arit i

Ocemed Heatim Proveer_341L._MW(ft.)

@ tw o'8E

~

- Geneestor Ratmg 177ft k9AWie) ac

1. A,wetify,,, _ttA M 1988 Dese Gems ( let trwal nategj g 33 TAW gw,,,,3,o g 744 U

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SU.SDfARY OF MAINTENANCE ACTIVITIES i

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MAINTENANCE SL? DIARY (ELECTRICAL)

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dd.tR$C6L HAIN!EMANCE IONTHLY SurMARY 94-6-63 CUMP MR3.... U TUXC SYS ADDRESS. DATE.... DESCRIPTION........................ CORRECTIVE ACTI0H.......................

F125593 2 23 087 0024 2 08/21/84 2-ZS-087-0024 2-C,EkNPRDM3,UHI CAG VLV 2-MV0P-087-0024-B;THE LIMIT SWITC'l CLOSED LIMIT SWITCH. ADDITIONAL EQUIP MOUNTING BRACKET WAS BENT PREVENTING THE 714 AGAINST WEST WALL. WITH THE GdC ULY STRIKER FROM MKING CONTACT WTH LIMIT IN THE CLDSED POSITION THE LOWER LIMIT SWITCH ARM. CONDUIT AND EABLE WERE SWITCH IS NOT MKING UP. THE LS lEJNTING CONHFCTED TO THE WRONG LIMIT SWITCH.

BRACKET APPEARS TO BE BENT SO THAT REPAIRED MOUNTING BRACKET AND REPLACED STRIKER CM'I MAKE CONTACT WITH LS ARM THE TOP AND BOTTIM COVER CAstET3. MOVED CONDUIT MD CABLE 62A3472 TO THE CURRECT LIMIT SWITCH. WRt B-125593.

B234113 211V0P 047 013010/21/87 2-MV0P-067-0130-A,ExWPPIm3,DIffEENCE LIMIT SWITCH 18tICH PROVIDES LIGHT BETWEEN REMOTE AND LOCAL STROKE TIME INDICATION WAS APPROXD1'.TELY 2 PERCENT FAILED TO MEET ACCEPTANCE CRITERIA FOR DUT Of ADJUSTMENT. ADJUSTED LIMIT SWITCH SI-idd.18 4 INVESTICATE AND REPAIR MD RETURNED VALUE OPERATOR 10 SERVICE.

WR 0 B-234113.

B2761221 GEND 082 0001A109/02/871-CEMB-082-0001A1,EuMPRDM3,WHEN D/C WAS THE GOVERNOR ACTUATOR DID NOT RESPOND TO RESET AFTER EMERG START (86 LC2 ESET)

CONTROL SIGNALS. VERIFIED THE RELAY WAS ENGINE 11 TRIPPED ON MECH DVERSPEED IN TIME TOLERANCE MD UERITIED ELECTRIC GOVERNIR CONTROL. ADDED DIL TO PROPER LEVEL AND INSTAL 1LD UIL LINE. REPLACED THE ENGINE i 1 COVERNDR ACTUATCR. WRt B-274122.

~25-

t.LCIRICAL !rdNith6hCE liDNIiLY SinMRY a-9 M 3 PACE 1 CW MR2.... U f t'XC SYS ADDRESS. DATE.... BESCRIPTION.

CORRECTIVE ACTION......................

B203554 2 nVCP 070 009011/11/87 2-HV0P-070-0090-A ERNPRDu,h10CFR50.49m], MIXED llPERATOR CEASE. CALCIl!M CASF0 DISCONNECT NVQP FOR MAINTENMCE ON FCV GREASE MIXED WITH LITHIllM BASED GREASE.

REF WR B130998 RE0VILT THE LIMITORGE OPERATOR REPLACl* HANDWEEL BEVEL PINION, THE-SPRING PACK ASSERY MD THE CASKET 5 SEAL SET.151RK PLM 112634 WILL INSTALL A NEW SPRINC PACK DUE TO F11LL COMPRESSION BEFORE REACHINC MINIMUM REQUIREMENT. WR B-203554.

B274074 1 JHVC 250 GR 01/18/831-INVB-250-PR-F,ExXPRDu], INVERTER FAN THE FM MOTOR WD91NCS EE OPEN. THE DOES NOT DPERATE OLD FM HAD DE RIENCHARC ON THE TERMINAL BLOCK, MREAS TE NEW FM HAD TWO 91DCHMCS ACROSS THE COMON MD NORMLLY CLOSED CONTACTS. THE ADDITI0hAL QUENCHARC ALLAWED THE COMBIED LEAKAGE CURRENT TO ' PULL IM' THE RELAY INITIATING AFM FAILLEI ALARM. THE QUENCHARC WAS DES 1sNED TO IMPROVE LONGEVITY OF Tile SWITCll CONTACTC, BUT DNLY DE IS ECESSARY IN THIS CIRCUIT OF FOUR PARALLEL CONTACTS. REPLACED THE FM MOTOR AND ALARM DID NOT CLEAR. REMOVED THE QUENCHARC FRWI ACROSS THE SWITCH CONTACTS AND RE-ESTABLISHED THE ORIGINAL CIRCUIT CONFICURATI0d. WR B-274074.

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1 MAINTENANCE

SUMMARY

(INSTRUMENTATION) l 3

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INSTRUMENT MAINTENANCE MONTHLY REPORT FOR MARCH 1988 COMMON 1.

Prepared and implemented workplans WP-7343-02 (unit 1) and WP-7344-02 (units 0, 2) to add seal-in relays to various radiation monitors that initiate ESF actuations. This was needed to reduce the-inadvertent CVI actuations caused by EMI.

UNIT 2 1.

Prepared and implemented workplan WP-X00167A-01 to add the proper clamps to the hydrogen analyzer calibration gas bottles to ensure a proper seismic mounting.

2.

Prepared and implemented workplan WP-6347-01 to replace dsfective Barton stcam flow transmitter, 2-FT-1-21A, with a qualified Foxboro transmitter.

3.

Initiated and processed CAQR SQP880265 to identify grounding problem with NIS detector.

Provided justification for continued operation because of detector response characteriatics.

Detector will be replaced during the next outage.

4.

Initiated and processed CAQR SQP880272 to identify a bent pressurizer level sensing line for 2-LT-68-320.

Coordinated with DNE to have the condition analyzed and judged to be acceptable.

The level transmitter was calibrated as necessary to compenrate for different reference leg height.

5.

Documented completion of corrective actions for NRC commitment, CCTS NC0850397002. This involved the replacement of existing unit 2 containment sump level transmitters with new transmitters having a double-0-ring seal configuration.

6.

Completed performance of SI-219 to calibrate and verify operability of the hydrogen analyzers after all upgrade modifications were completed.

This was an NRC commitment per CCTS NC0870284001.

7.

Completed calibration of all CSSC instruments needed to support entry into mode 2 and above. This completed the unit 2 restart corrective actions for DQA Audit QSQ-A-86-0007-D01.

8.

Continued to provide support to the pressurizer loop seal investigation while DNE and Modifications installed additional heaters.

Instrument Maintenance calibrated and/or verified the calibration of the temperature switches on the loop seals.

Instrumentation also provided technical support to prepare SI-746 which will be used to monitor and maintain the operability of the pressurizer loop seals if a low temperature alarm is received in the control room..

.,.-.uw~~-

,n

--n..

An

stamETeX EMMalt EMLY WA%Y v4 v8-93 COMP rR2.... U IUNC SYS ADC.RESS. DATE.... DESCRIPIIGH......

CORRECTIVE ACTIDH......................

B228798 2 PBS 003 0148 02/16/88 2-P03-003-0148-B,EWRDn),LCV LERS THE EXHAUSTER VALVE AND POSITIDHER RELAY THRU-CAUSES AFWP DISCHARGE CECK UALVE CH THE VALUE POSITIDHER TO CYCLE AGAINST ! EAT. ADJUST STRCKE MLFUNCTIDHING. THIS MY HAVE BCEH DE AND UERIFY FRUBLEM MS IEEH CORRIETED BY TO AGING, CYCLING, AND/OR WEAR. REPL* & -

RUNHING 2B-B AFPP DH MINIFLOW.

EXHAUSTER VALVE AND POSITIDHER RELAY.

CALIBRATED, SET LIFTOFF AND FULL TRAVEL PRESSURE. VERIFIED PROPER LIFTOFF, SEATING PRESSUQC, PROPER STROKE, AND STATUS LICHTING. VERIFIED HD LEAKAGE AND L TT IN SERVICE. WR8 B-228798.

i;257405 2 PI 001 0033 03/02/88 2-PI-001-0033,EMHPRDm],(1) CALIERATE INDICATOR. (2) UFDATE CALIBRATIDH CARD AND GIVE A COPY OF DeTA TO ORIGIMTOR.

8257425 2 XI 001 0033 03/02/88 2-XI-001-0033,EhWPRDN3,CALI[ RAT [

INDICATOR.

• T APPEARS THE CALIES!ATIDH 4

IS HDT CURRECT.

B262147 2 iC0 003 0103 02/19/88 2-FCV-003-0103,EuMPRDn],THE frYPASS THE FLOW MODIFIER WAS FOUND TO BE OUT OF VALVE LEAKS THROUGH WITH A FL'LL CLOSED TOLERANCE LOW THROUGHOUT T DEMHD DH IT RANGE. THIS MY HAVE BEEN DUE TO WEAR, AGING AND/QR CYCLING. THE MODIFIER WAS RECALIERATED, VALVE ADJUSTED FOR PROPER LIFT-UFF AND STROKE AND kESTROKED.

VERIFIED PROPER (PERATIDH OF UALVE.

8267193 21M 068 002D 03/08/88 2-TM-048-0028-D,EmHPRDn],INDICATGi INDICATES LOW AS COMPARED 10 UTHER CHAHKELS. IHVESTICATE AND REPAIR AS HECESSARY C271654 2 IE 068 00568 02/01/88 2-TE-068-0056A-F,Ex10CFR50.495,WRDn],0 IT WAS DETERMINED THAT THE WIRE HAD BEEN ETFJJtINE CAUSE OF 4.8 READING OF SHIELD CRUSHED WHICH CAUSED THE SHIE WIRE TO GROUND DUTER SHEATH TO BE SHDRTED TO GRDUND.

CUT AND PREPARED CABLE, COHHECTED YELLOW WIRE TO INHER BRAID FOR SHIELD.

INSTALLED RAYCHEM IH JUNCTIDH BOX 2928 GH SHIELD WIRE TERMINATICH. SEALED CONDUITS IH JUNCTIDH BOX. WRt B-271854.

0279062 2 PT 068 0334 02/17/83 2-PT-068-0334-E,Eul0CFR50.Y m], cit.'D 12-13-87 USING H 1 IE 1507263 WHICH Wh3 FOUND 0.0.T. AT THE L AB. INFORM QRIGINATOR CF AS-FCUHD CATA AND LATE PERFURr.ED ASf,P.

B285547 2 LCV 003 0173 02/09/88 2-LCV-003-0173-B,ExP2m,nHPRDn], FAILED THE ELECTRICAL WIRES WERE PUSHED AGAIHST t

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[..,_-.___.__.

AHSIEU'. INT f.AIkTENMCE iCITHLY SU.74RY W-08-63 Cult?

F.R2.. U f uMC SYS ADDRESS. DATE.... DEICRIPTIUN..

................ CORK CTIVE ACTIDN.......................

SI-164.4 LOCAL REr.0TE STR.Id TIl!E THE FLAPPER AND N022LE WHEN THE COYFR DIFFERENCE.

WAS INUELED. VERIFIED STEM WAS PROPERLY LIERICATED. PERFORMED SI-75 TO TROUBLESHOOT DPERATION OF-TE VALUE.

PULLED FIELD WIRES AWAY FROM THE FLAPPER N0ZZLE ALLOWING TE YALVE TU STROKE PROPERLY.

1:29 m d 2 U 048 VARIOUS 01/19/88 2-E-048-UARICUS,[wHPRDu,m10CFR$0.49N,n ELEf.ENT AND TRANSHITTER PROBLERS. THE P:n], CHANNELS 340, 334, 366 ALL SHOW NO CONNECTORS AND TE ACCELEROMETERS WEK SIGNALS REPLACED. RAYCHLED CONNECTORS, VERIFIED OPExATIDN AND RETURNED TD SERVICE.

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MECHANICAL MAINTENANCE MONTHLY REPORT FOR' MARCH 1988 UNIT 1 1.

Completed repair on 1-FCV-074-0037 and -0038.

2.

Rebuilt 1A-1 CCS pump.

3.

Completed repair on 1-FCV-062-1047.

4.

Completed SI-102 on D/G 1A-A.

UNIT 2 1.

Balanced reactor coolant pump No. 1.

2.

Adjusted spring tension on 2-FCV-063-007?, -0165, and -0167.

3.

Plugged 19 tubes in B stator water heat exchanger.

4.

Replaced valve stem in 2-FCV-003-0081.

5.

Completed repair on containment isolation valves 2-FCV-043-0061 and

-0064.

6.

Replaced diaphrages in containment isolation valve 2-FCV-062-0073.

7.

Opened / closed 2A-1 water box.

8.

Replaced the trip solenoid on main turbine.

9.

Opened / closed polishers 2-5,

-3, and

-2.

+

10.

Repaired oil leak on RCP motor.

11.

Rebuilt chemical drain tank pump.

12.

Completed repair on containment isolation valves 2-FCV-043-0055 and

-0058.

13. Completed repair on four steam dump valves.

14.

Added balance weights to reactor coolant pump No.1.

15.

Recoupled 2A and 2B main feed pumps.

16.

Completed repair on 2B-B MDAFW pump.

17. Completed repair on 2-VLV-072-0513-B.

18.

Completed repair on 2-VLV-068-0530-3.

19. Completed repair on 2-FCV-062-0093.

20.

Completed various sis.

COMMON l

'1.

Repaired door No. A-57.

OTHER L

1.

Continued closure of various CAQRs, CARS, DRs, etc.

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riLGWE MlHIEhAhCE GidLT SWW.ARY G4-08-!J CCG8 rR2.... U FUNC SY8 ADDRESS. DATE.... DESCRIPTIDN....

............... CORRECTIVE ACTIDH......................

E.2??774 2 VLV 048 0530 03/22/88 2d.UJ-068-0530-S.ExXPRDs),YEVE MS IT MS SUSPECTED THAT THE BONNET CASKET CRYSTALLIZED BDRON I:UILDUP CETWEDI YEVE WAS LEAKING. THIS MY HAYE BEEN CONNET & JALVE BODY. RWP REQUIRED NORML WEAR AND MTERIR ACING. THE BONNET CASKET W.is REPLACE 0 AND POST MINTENANCE TEST PERFORflED. THE VEVE WAS RETURNED 10 SERYICE. WR$ B-277774.

B285178 2 VLV 072 051312/04/87 2-VLV-072-0513-B,EAXPRDnJ, RELIEF VLY IS SEAT As DISC WERE SCRATCED AND DAMGED LEAKING, PLEASE REPAIR DR REPLACE.

APPARENTLY BY A FUREIGN DBJECT IN INE PIPE. DISASSDSLED YEYE, CLEANED, LAPPED SEAT AND DISC, REPLACED DISC, BELLOWS, DISC PIN AND DISC RINC.

REASSElWLED AND REINSTELID VALYE. (WRt B285178) l.

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$04181 M6ECG ?. gilly surmRY-6-03-23

%W ff2.... ' u f t1HC SY8 A 00RESS. D ATE... D ESCRIPTION.......................... CO 1

' P219537 2 FCU 062 009311/25/87 2-fCV-042-0093,EMP24,mHPRDa3,ULY STEM STEM WAS BENT DDE TO IMPROPERLY SET IS BENT. OBSERVED I:Y CARY DEltRD 8 L.E.

STRDKE. FABRICATED AND INSTALLED NEW MGRCAN.

STEM. INSTALLED htM DIAPHRAGM AND REASSDSLED VALVE. (WR8-9-219537).

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6 4 -

e MAINTENANCE SUSNARY (MODIFICATIONS) 9

\\

SUMMARY

OF WORK COMPI.ETED MODIFICATIONS - CURRENT STATUS MARCH 1988 4

Maior Capital Projects:

PN7101:

ECN 6388 - 500-kVA Switchyard Current Transformer Heaters Workplan (WP) 12223 is in progress pending safe access to current transformers.

PN7102:

ECN 5938 - Replace Feedwater Heaters 3 and 4 No work in progress at this time.

PN7105:

ECN 5009 - Essential Raw Cooling Water (ERCW) Piping Changoout From Carbon Steel to Stainless Steel Insulation of new stainless steel piping has been completed.

No additional pipo replacement is scheduled in the near future.

PN7108:

ECH 6720 - Crane Consistency Program Unit 2 polar crane modification is complete.

Postmodification testing (PMT) by Electrical Maintenance is not complete. Unit 1 polar crane work started on July 6, 1987 and is approximately 98 percent' complete.

Painting of blocks and limit switch weights remain.

Auxiliary Building crane WP 1.2596 is in the approval cycle.

Drawings have not been issued on the remaining cranes. WP 12596 is in nonwork status. Work is stopped pending resolution of budgetary problems.

PN7115:

ECN 6719 - Volumetric Intrusion Detection System ECN 6719 is still on hold.

Security is dissatisfied with system operation.

Security and DNE have not concluded discursions on resolution.

Design is working on making the system functional.

Lighting is not finished. Workplan change for drainage is being written.

Field Change Request (FCR) 6645 for DNE changes is approved. Work is stopped pending resolution of budgetary problems.

PN7122:

DCR 1373 Secondary Side Steam Generator Preservation ECN 5657 - Installation of Moisture Separator Reheater (MSR)

Drain Valves Work is essentially complete on all the ECNs.

Some minor insulation installation activities are in progress as resources permit.

Major Capital Projects (cont.):

ECN 5841 - Hot Shop Fire Protection /Evscuation Alarm -

WP 12637 All fieldwork for evacuation alarm complete. Awaiting Work Request (WR) B240406 to be worked to restart fans to do functional test on fire protection.

PN7123:

ECNs 5938, 6305, 6571 - Replace Feedwater Heaters 1 and 2.

Units 1 and 2 and Eroded Pipe Modifications Group B is supporting PMT on heaters 1 and 2 on both units as requested.

Insulation work on unit 1 coatinues.

PN7130: DCR 1156 - Post Accident Monitoring This work has slipped to allow work to continue on priority unit 2 restart efforts. NRC commitment on NUREG 1.97 called for unit I completion by September 1987 (this has been moved to July 1988) and unit 2 by U2C4. A request has been sent to the NRC to move the unit 2 completion date to U2C4.

PN7132:

DCR 2348 - Sewage Treatment Facility and Civil Upgrade New DCR for onsite sewage treatment facility upgrade.

City of Soddy-Daisy will be responsible for interface work on site, lift station, and ploeline between Sequoyah Nuclear Plant and Highway 27.

PN7136_: ECN 6259 - MSR Tube Bundle Replacement Complete except for PMT and inservice leak test.

Leak checks will be performed during system heatup.

PN7161:

ECN 5855 - Replacement of Doors A56 and A57 Installation of door A56 is complete.

Security of A56 to be worked later. Work on door A57 and interlocks will begin later. Workplan 11654 is in work. Work has proceeded to the point of functional testing.

Pressurizer loop seal work has taken priority and drafted manpower.

PN7181:

DCR 1898 - ECNs 6832 and 6596 - Dry Active Waste (DAW 1 Building Electrical interface work is complete. Workplan closure held for Instrument Maintenanca (WP 12478) and Elect?ical Maintenance (WP 12612) checks and update of SOIs by Operations.

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1-Major Capital Proiects (cont.):

PN7199: Miscellaneous Activities Under $100.000 This is for various work orders prepared for work under

$100,000 total site cost. This work is done as manpower resources are available that will not impact unit 2 restart effort.

Significant Items:

The following major significant items are under Operation and Maintenance Expense (0&M) and will continue to be until restart of unit 2.

s 1.

Fuse Program Work ECN 5886 - Work complete for class IE vnit 1 and 2 and non-IE fuses associated with unit 2 restart. Remaining work is non-claas IE unit 1 and non-class IB unit 2.

WP is being written for non-IE checklist for unit 1.

2.

Cable Ampacity Program Unit I has only one cable remaining. This cable is complete except for termination which is held for DNE.

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e Other Items:

ECN 5111 - Provide Permanent Power to Manholes 42-46 Electrical conduit and wiring installation for manholes 44-46 is complete according to WP 12262. Manholes 42 and 43 are being held for information from DNE on power cable routing and terminations.

FCR 4572R1 was sent to DNE and was logged in, but it was not sent to the responsible engineer. Manholes 42-46 will be worked by FCR 4572R1.

This item is not considered unit 2 restart by DNE, and they will not authorize the engineer to do the necessary work to obtain pull cards or drawings for manholes 42-46.

FCR 4572R2 will be written to supersedo 4572R1 for conduit and cable routing for manholes 42-46.

WP 12276 is 100 percent complete. Workplan closure in process.

ECN 5412 - ERCW Nuisance Alarms WP 5412 Fieldwork complete. Workplar in closure cycle.

ECN 5435 - Fire Doors No work is in progress at this time.

ECN 5503 - Evacuation Alarms O&PS/ Fire Detection O&PS No work in progress at this time.

WP 12664 - Work is in progress and is approximately 95 percent complete. Remainder restrained by CAQR SQP 871616 (evacuation alarm O&PS).

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

A mode 2 restart item.

WP 5552 In work.

Functional test in progress.

ECN 5609 - Air Compressors Makeup Water Treatment Plant i

Installation and checkout is complete. Work is complete.

WP 11987 is field complete.

Obtaining all documentation for closure of workplan.

ECN 5609 - Evacuation Alarm / Fire Detection Valve 26-290 WP 12387 is in work and is 90 percent complete. Workplan change is needed to allow local testing of alarm horn.

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Other Items (cont.):

ECN 5609 - Alteration to the Makeup Water Treatment Plant WP 12576 - Work is in process and approximately 90 percent complete.

WP 12633 - Work is in process and approximately 50 percent complete.

WP is being held for material on WP 12665 (Mechanical).

WP 12731 - WP is approved and being held for material procured on purchase requests 74262A and 74321A.

WP 12684 - WP in work, approximately 60 percent complete.

WP 12665 - WP is being worked, and is 20 percent complete.

WP 12682 - WP is being worked, and is 20 percent complete.

DCN 113 - WPs 113-01 and 113-02 are complete.

ECN 5626 - Containment Ladders, Unit 1 L workplan is being written to incorporate this ECN.

Modifications needs additional design information to complete.

DNE needs to issue all drawings listed on this ECN.

Work has not begun because of this holdup.

ECN 5726 - CAQR SQP870478 - Reroute Sense Line Piping for Train Separation to Panels 2-L-58 and 2-L-68 Fieldwork is complete.

In-service leak check will be performed during heatup.

ECN 5754 - ERCW Nuisance !.larns WP 5754 Fieldwork complete. Workplan in closure cycle.

ECN 5841 - Hot Shop Fire Detection WP 12360 is 95 percent complete and is being held for material ordered for PNL O-L-633.

Modifications issued a purchase requisition to buy material and DNE will purchase.

ECN 5935 - Correct Power Block Lighting Deficiencies WP 12437 has been approved and is in work. This is a nonrestart item. WP 12275 is being written.

Modifications needs DNE to provide light mounting detail for raw water storage tanks and estimate design date after unit 2 restart. WP 5935-01 has been written to install security grills and gratings.

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Other Items (cont.):

ECN 6005 - Replacement of AFW Steam Ejector, Unit 2 In-service leak check performed and reinstallatio.: of piping insulation is complete.

ECN 6057 - Cable Tray Covers This activity is complete for the unit 2 restart.

The only remaining work is the unit 1 annulus and this will be completed prior to June 1, 1988.

ECH 6082 - Vent for Boric Acid Tank (BAT)

Work complete except final inspections and painting on duct supports end performance of SI on High Efficiency Particulate Air. Work is nearing completion.

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

Remaining unit 2 work is scheduled for U2C3 refueling outage.

ECN 6205 - Replacement of Instrument Loop Power Supply Fuses Unit 2 and unit 0 work is complete except for spares. Fuses are not on order. United Engineering has not notified materials group about fuse type (100 milliampere). WP 12447 has been turned in to Document Control for partial completion. WP 12611 initiated to perform unit I work. There are material problems that will cause delays.

ECN 6357 - Essential Raw Cooling Water (ERCW) Roof Access and Rails for Security Equipment WP 12238 is in work.

ECN 6380 - Replacement of Barton Pressure Transmitters Unit 2 fieldwork is complete.

Final closure awaiting instruction revision by Instrument Maintenance.

ECN 6388 - Hydrogen Monitors in Switchyard Workplan 12223 - Craft support as needed for installation of hydrogen analyzers at 500-kV switchyard (50 percent work complete).

Other Items (cont.):

ECNs 6402 (Unit 1) and 6439 (Unita 1 and 2) - Pressurizer Instrumentation Relocation Inservice tests will be performed when the system la brought up to temperature and pressure.

ECN 6429 - Component Cooling Meat Exchanger B Replacement DNE to procure piping, hanger, and plate heat exchanger frame material.

DNE to issue hanger. drawings. Workplans are in work to fabricate and weld piping and fabricate and install new plate heat exchanger.

ECN 6455 - Upgrade CU-3 Box Battery Packs WP 12295 has been issued. Modifications are complete for all CU-3 boxes. Site Security still needs to perform some PMT before the workplan can be closed out.

ECNs 6491 and 6534 - Essential Raw Cooling Water (ERCW) Supports All restart work is complete. A workplan to remove previously installed piping was approved and will be worked as resources permit.

ECN 6543 - Install Public Safety Access Portals and Modify Entrance Road Work is being $ald 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 Unit 1 work is incomplete.

ECN 6631 - Modify Snubbers Unit 2 work is complete.

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

All work AJ complete for unit 2.

Work on unit I has started..

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I Other Items (cont.):

ECN 6698 - Repull 120-Volt Cables Unit 2 is complete. Unit 1 is 90 percent complete and held by ECN 6742. This ECN should be completed prior to unit I restart.

ECN 6706 14 Support Enhancement / lost Calculations Repairs continue on unit 1 as resources allow. This project has been combined with the calculation regeneration project for unit 1.

Work is in progress with six workplans in the field and two in the approval cycle. Unit 2 work is complete and workplans are closed.

ECN 6739 - Alternate Analysis Unit I work has started and 74 of 83 hangers are complete. Work has started on the maintenance items.

ECN 6742 - Install Fuses in Radiation Monitor Power Supply Circuits The workplan is complete for unit 2.

Unit 1 is 50 percent complete.

Instrument Maintenance cannot support until March 14, 1988. This ECN should be completed prior to unit I restart.

ECN 6761 - East Valve Room (EVR) Blowout Panels Implementation of unit I work is progressing as resources are available. Unit 2 work is complete.

ECN 6784 - Documentation to Show Pipe Class Breaks q

d Final closure is awaiting a revision to AI-19 deleting requirements to mark shift supervisor drawings.

ECN 6815 - Installation Power Circuit Breaker Install 500-kV power circuit breaker and associated equipment for bay 1.

Retire 161-kV PCB and associated equipment.

A total of eight workplans will be required.

Foundations and conduit are presently being installed by WP 12654. WP 12740 for lighting, drain pipe, and surface ground mat has completed the review cycle. WP 12739 for the structural steel installation has been written and approved.

Completion of WP 12654 will probably be delayed somewhat by late delivery of anchor bolts and bad weather.

An attempt is being made to make up for lost time. Workplan 6815-02 has been written and is in the review cycle. Workplan 6815-01 is now being written..

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e-Other Items (cont ):

ECN 6860 - Control Room Bullet Resistivity - DCR 2268 - ECN 6860 WPs 12602, 12603, 12604, and 12605 are in closure cycle.

ECN is complete except for miscellaneous touchup painting.

The lockset for door C-37 malfunctioned and a CAQR has been initiated. Work is estimated to be completed by March 14, 1988.

ECN 7000 - Addition of Support to Main Steam Dump Header Fieldwork is complete. Workplan 12217 is closed.

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

ECN 7190 - Replace Duct Detectors and Install Thermal Detectors WP 7190 Installation and checkout is complete. Workplan closure is in process.

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.

DCN 200018B - Install Needle Valve for Hydrogen Analyzers The workplan lacks PMT (SI-219).

DCN 49 - Computer Room Air conditioner Awaiting instruction revision to close workplan.

DCN 70 - Hydrogen Analyzer Check Valves The workplan lacks PMT (SI-219).

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e Other Items (cont.):

DCN 89 - Crane Wall Penetration Additional penetrations were added by DNE and completed by Modifications.

DCN 192 - Pressurizer Loop Seal Added heat rings, cable and conduit, and made adjustments to the insulation on the piping system.

Instrumentation Verification Program For unit 2, there have been 953 discrepancies issued to MODS to date with 476 not required for restart. All discrepancies required for restart have been completed; 94 nonrestart discrepancies are open.

For unit 1, there have been 193 discrepancies issued to MODS to date with 30 not required for restart. Of 163 required for restart, 93 remain open and are being worked.

ECN 6596 - WP 12402 - Complete with the exception of five percent of paving to be completed spring 1988.

WP 12477 - Requires Instrument Maintenance calibrattun and checkout of area radiation monitor and air compressor.

WP 12612 - Complete. Closure in process.

SOIs are complete.

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

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6 THIS PAGE INTENTIONALLY LEFT BLANK l

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TENNESSEE VALLEY AUTHORITY Sequoyah Nuclear Plant i

P. O. Box 2000 Soddy-Daisy, Tennessee 37379 April 11, 1988 Nuclear Regulatory Commission Office of Management Information and Program Control Washington, DC 20555 Centlemen:

SEQUOYAH NUCLEAR PLANT - MONTHLY OPERATING REPORT - MARCH 1988 Enclosed is the Mtrch 1988 Monthly Operating Report to NRC for Sequoyah Nuclear Plant.

Very truly yours.

TENNESSEE VALLEY AUTHORITY

-j S. J.

mith fee Plant Manager Enclosure cc (Enclosure):

Director, Region II Nuclear Regulatory Commission Office of Inspection and Enforcement Suite 3100 101 }arietta Street j

Atlanta, Georgia 30323 (1 co y)

Director. Of fice of Inspectiod and Enforcement Nuclear Regulatory Commission Washington, DC 20555 (10 copics)

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

INPO Records Center Suite 1500 9

1100 Circle 75 Parkway Atlanta, Georgia 30339 (1 copy)

Mr. K. M. Jenison, Resident NRC Inspector i

l 06PS-2, Sequoyah Nuclear Plant An Equal Opportunity Employer

.. _...... _ _