ML20126G890

Monthly Operating Rept for Mar 1985

ML20126G890
Person / Time
Site:	Oyster Creek
Issue date:	03/31/1985
From:	Baran R, Fiedler P GENERAL PUBLIC UTILITIES CORP.
To:	NRC OFFICE OF RESOURCE MANAGEMENT (ORM)
References
NUDOCS 8506100223
Download: ML20126G890 (11)

Text

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'[' j 50-219 DOCKETNO.

UNITSIIOTDOWNS AND POWER REDUCTIONS UNIT NAME Oyster Creek DATE 4-2-85 COMPLETED BY R.

Baran REPORTMONTl! March 1985 TELEPIIONE 971-4640

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.E5 Licensee Et,

{*3 Cause & Corrective Action to No.

Date g

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.8 ~ 5 Event g3 go Prevent Recurrence

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O 36 2-2-85 F

785.6 A

Z NA ZZ ZZZZZZ Unit shutdown to correct a potential design deficiency with Core Spray System booster pump logic and to effect repairs to the EMRVs.

NOTE:

Generator on the Line

.9:02 p.m.

on March 4.

The generator was off thc line for 24.9 hours1.041667e-4 days <br />0.0025 hours <br />1.488095e-5 weeks <br />3.4245e-6 months <br /> from March 17 to 18 due to a condenser tube leak with the reactor critical in hot standby (IRM Range 9 power level).

8506100223 850331 s

PDR ADOCK 05000219 R

PDR I

2 3

4 F: Forced Reason:

Method:

Exhibit G. Instructions S: Scheduled A-Equipment Failure (Explain) 1-Manual for Preparation of Data B Maintenance of Test 2-Manual Scram.

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

Event Repor (LER) File (NUREG-D-Regulatory Restriction 4-Other (Explain) 0161)

E-Operator Training & License Examination F-Administrative 5

G-Operational Error (Explain)

Exhibit 1. Same Source IIOther (Explain)

(9/77) g<

Monthly Operating Report - March.1985 Page 1 At the beginning of the report period, the plant was shut down and in the process of machining pipe inlet flange surfaces for

'A',

'C',

'D' and 'E'

-electromatic relief valves ( M V's).

Details of MV repairs and additional corrective maintenance accomplished during the shutdown were provided in last month's report.

Following completion of repairs and surveillances, a reactor start-up comenced at 1111 hours0.0129 days <br />0.309 hours <br />0.00184 weeks <br />4.227355e-4 months <br /> on March 4; criticality was achieved at 1350

-hours.

Drywell inspections were conducted at 500 and 1000 psig; no M V flange leaks were identified.

Scram times were recorded for nine (9) l0tDs and the generator was put "on-line".at 2102 hours0.0243 days <br />0.584 hours <br />0.00348 weeks <br />7.99811e-4 months <br /> on March 5.

Power output was maintained at -100 MWe for approximately 20 hours2.314815e-4 days <br />0.00556 hours <br />3.306878e-5 weeks <br />7.61e-6 months <br /> for containment inerting.

On March 6 the reactor mode switch was placed in "run". and-power was increased to approximately 50% thermal power, with

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the generator producing 297 MWe.

Power was held at that level to establish xenon equilibrium to accommodate core flux profile checks.

On -March 8, power was reduced to less than 40% for repairs to a steam leak on-the anticipatory scram bypass switch sensing line.

The only.

means of -isolating the leak, while operating, was to close the switch

' isolation valve and inject it with sealant.

The function of the switch, which will remain defeated until the next outage, is to bypass anticipated scrams (turbine trip and load rejection) at power levels less than 40%.

In its present configuration, anticipatory scrams are not bypassed.

In the interim; any turbine trip at a power level less than 40% will result in a reactor scram.

Power was increased to 510 MWe late in the day on March 8, at which time

.second stage reheaters were placed in-service.

During the period March 9

.11, power was gradually increased to 650 MWe.

On March 11, power was decreased to 635 MWe to accommodate control rod pattern adjustments.

' Late on, the evening of March 11, problems were experienced with pumps associated with the Drywell Equipment Drain Tank (DWEDT). With a drywell

. identified leak. rate in excess of 7 gpm, the pumps became vapor-bound causing the DWEDT to overflow into No.1-8 sump. Water routed to No. 1-8 ssp. is recorded as unidentified ' leakage and has a Tech Spec limit of 5.0 gpm. When the DWEDT.pmps became vapor-bound, the unidentified leak rate exceeded the Tech Spec limit, necessitating a plant shutdown.

Plant shutdown. commenced at 0052 hours6.018519e-4 days <br />0.0144 hours <br />8.597884e-5 weeks <br />1.9786e-5 months <br /> on March 12.

At approximately 200 MWe, suction and discharge valves associated with the recirculation pumps were backseated; the unidentified leak rate decreased to less than 1 gpm and the shutdown was terminated.

Monthly Operating Report - March 1985~

Page 2

-Problems experienced with.the IMEDT have been. determined to be the result of a ; modification performed during the last refueling outage.

The modification involved relocation of the tank's heat exchanger / cooler from within the tank to the - discharge of an associated pump.

Cooling is provided by recycling the contents of the tank.

It appears that the tank,: with the.new heat exchanger configuration, does ' not have adequate cooling-capability to accommodate-identified leakage in excess of 7 gpm.

' Tech Functions is evaluating options to resolve the problem.

Power was slowly. increased -to 608 MWe by the evening of March 12.

A temporary decrease was required late. the same day due to heavy grass accumulation in the intake canal, causing problems with the screens. The

. power decrease lasted approximately 1.5 hours5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br />.

Power increases at a rate of approximately 3 We/hr. commenced during the evening of March 13 and were interrupted because a core thermal parameter (MAPLHGR) approached the Tech Spec limit.

Power was decreased to 589 We

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(86.7%) on the morning of March 14.

Power was then. gradually increased to 650 We late -that day.

On-March 16, power. was reduced to 628 We because core (MAPLHGR) approached the Tech' Spec limit.

Power operation at the 650 MWe limit resumed later that evening.

A temporary load reduction of 7 We was required during the morning of-March 17 to clear grass accumulated at No.'s 1 and 3 intake screens.

At 1030 hours0.0119 days <br />0.286 hours <br />0.0017 weeks <br />3.91915e-4 months <br /> on March 17, high conductivity alarms on

'A' north main condenser tubesheet and a L subsequent alarm on 'A' north main condenser

.hotwell. were caused by saltwater intrusion in

'A' north condenser.

Repeated attempts were made to reduce leakage by backwashing condenser halves and then by isolating the

'A' north section with no apparent effect. A decision was made to remove the generator from service because of the inability to reduce conductivity and chloride levels by isolating the 'A' north condenser. The generator was taken off-line at 2044 hours0.0237 days <br />0.568 hours <br />0.00338 weeks <br />7.77742e-4 months <br />,

. reactor power reduced to approximately 8% and mode switch placed in

" start-up". Reactor pressure was reduced and maintained at 500 psig.

A significant leak was found in one (1) tube located in

'A' north condenser.

The tube was plugged.

On March 19 at 1314 hours0.0152 days <br />0.365 hours <br />0.00217 weeks <br />4.99977e-4 months <br />, a gradual increase in reactor power commenced. The mode switch was placed in "run" and the generator placed in-service at 2106 hours0.0244 days <br />0.585 hours <br />0.00348 weeks <br />8.01333e-4 months <br /> producing 200 MWe.

Power was increased to 435 MWe following completion of core flux profile checks.

Power was held at this level pending replacement of condensate demineralizer resin and completion of repairs to

'A' feedpump discharge

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check valve (hinge pin gasket leak).

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-Monthly Operating Report - March 1985 Page 3

-Replacanent.of. resin in No. 's 2 and 3 condensate demineralizers was completed during.the period March 21-22.. These beds were the ones most affected by saltwater -intrusion.

Remaining.demineralizer resin will be replaced following resumption of full-power operation.

Initial ' attempts to. correct the feedwater check valve leak by tightening the hinge. pin. flange bolts were - unsuccessful.

Repairs required

'A' feedwater. string ' to be isolated - and drained.

Repair activities were -

delayed until March 20, because of isolation valve seat leakage which' precluded. draining the system.

Repairs..were completed on March.21-and the feedwater_' string was ~ filled, vented and returned to service.

Power was increased to 590 MWe on March 21 and to.6.44 MWe the next day.-

Power - was reduced because of a power shape monitoring system -(PSE)

' computer hardware malfunction.

Until the problem was corrected, power was maintained at 'approximately 630 MWe to ensure, compliance with Technical Specifications relative to core thermal parameters.

The malfunction was traced to a faulty control board which was replaced on March 29.

Power was increased to 655 MWe and maintained at that ' level until April 1.

. Corrective Maintenance performed during the report period included:

o Repaired' main and pilot valve seat leaks on

'C' and

'D' BRV's.

o

-Injected additional-sealant into feedwater isolation valve V-2-11 and second stage. steam reheater valve V-1-34.

Thermal cycles (power changes) may disturb sealant previously injected, requiring additional injections.

o Replaced intercooler and cooling water solenoid valve for No. 2 air compressor, o

Replaced test valves V-9-30 and V-9-31 on fire diesels.

Repaired oil leak on No. 1 fire diesel, o

On the morning of March 15, New Radwaste feeder breaker tripped due to a ground fault on the heater elements to SL-T-14.

Power was restored the same day.

Necessary repairs are in progress.

o Calibrated main steam line temperature sensors.

o Increased reactor safety valve acoustic monitor sensitivity to compensate for failed thermocouple (back-up monitor) associated with reactor safety valves PR28A and N128N.

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Monthly Operating Report - March _1985 Page 4 o

Disabled -(lifted leads) drywell equipment drain tank pump alternator.. Ingic circuitry _ malfunction allows.No. - 2 pump to operate continuously.

In this configuration, _ No. 2 pump _will operate only when a high-high tank level exists.

o-Repaired oli leak on Core Spray booster pump NZ03D.

o

'_C' 4160 Volt switchgear room fan was. repaired and returned to service.

MEC.is investigating cause of a continuous Control Room alarm. associated with the fan.

o Repaired : loose electrical -connection in :No. 1'TIP machine retraction circuitry after unit failed to retract.

o Machined collector rings on No. I circulating water pump, o. Replaced core spray system I fill pump.

An investigation is in progress to determine failure mechanism.

o Returned Makeup System mixed bed demineralizer to service following replacement of retention screen and repair of acid line leak.-

.o.

Completed replacement of torque switches for shutdown cooling valves V-17-55, 56 and 57, satisfying a March 31 environmental qualification (E0) comitment.

Investigations / repairs in progress at the end of the report period included:

I o

Bearing replacement on Reactor Building Fan No. EF 1-6 was completed on. March.29. _ Repairs to Fan No. EF 1-5 are in progress.- Additional repairs to fan dampers are pending receipt of stiffener material.

'o

. A manway gasket leak on No. 2 flash tank has developed. Repairs are in progress.

o Intake screen - No. 6 remains out-of-service due to mechanical binding.

Lack of available work space requires overhaul of No.

2 screen to be completed prior to comencing work on No. 6 unit.

o Continued testing of new chemistry lab equipment.

.' o

'A Plant Engineering Work Request was submitted to determine if a TIP can ' be retracted with its. associated indexer ready-light burned out.

He ready-light is wired in series with the logic circuit.

He ready-light indicates proper indexer alignment to the selected guide tube.

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Monthly Operating Report - March 1985.

Page 5 o.

Newly ~ installed ~ Control Room recorders are experiencing

, recurring chart - drive and printing problems.

The problems appear _;to_~ be related to elevated temperatures - inside Control Room panels.

Plant Engineering will investigate and ' recomend c

-corrective measures, o.

Inspection / repair of 1-1 TBCCW heat exchanger.

o-

'C'ifeedwater pturp motor inner bearing _ temperatures are higherL

'than normal. Plant Engineering.is evaluating temperature data.

o 1her failure of No. 1 demineralizer water pump motor is being

--investigated by Plant Engineering.

Inspections indicate failure was-a: result of excessive vibration.

. Installation of replacement motor is complete.

Replacement. of pump mounting bolts is in progress.

o IRM channels continue to-respond erratically.

Periodic spiking occurred following plant start-up.

The~ problem will be Jaddressed during the next shutdown.

NOTE NO. 1:

Gross. generator output for March 1985 was 325,830 MWHs.

N011i NO.'2:

At the end of-the report period, drywell unidentified leak rate was steady at approximately 0.8 gpm. and identified leak rate holding at 4.2 gpm.

1188A

• Monthly Operating R;p;rt '

Pag 2 6 The following Licensee Event Reports were submitted during the month of March 1985:

Licensee Event Report 50-219/85-002 - On 2/2/85, 2 containment isolation valves in a single penetration were inoperable.

During a planned shutdown, reactor water cleanup system isolation valve (V-16-1) was required to be taken off its backseat.

To prevent full closure of valve, an electrican manually tripped the breaker, causing the cleanup recirculation pump to trip, which in turn caused a cleanup system isolation on low flow.

A second isolation valve V-16-14 failed to fully close on the system isolation signal resulting in 2 inoperable isolation valves in a single penetration.

The valves were secured in the closed position.

Licensee Event Report 50-219/85-004 - The Power Shape Monitoring System (PSM3T~is a new core monitoring system which is being used for the first time at Oyster Creek.

During January 2-30, 1985, the Oyster Creek core was highly bottom peaked during high power / flow operation.

During this period, no measured LPRM or TIP data feedback adjustments were made to the model.

As a resul t, PSMS power distribution and thermal limits calculations were inadequately monitoring core conditions due to flux peaking.

The bottom peaks violated APLHGR limits.

Core thennal power was reduced and the control rod pattern was reconfigured to reduce power peaking.

Licensee Event Report 50-219/85-005 - During routine surveillance testing, pipe breakers sensors IB05A1, IB05B1, IBilAl, IBilA2, 181181 and 181182 for both isolation condensers steam and condensate lines, tripped at values greater than specified in Technical Specifications.

One sensor had a defective switch actuating cam, which was replaced, and the others failed to trip due to instrument drift.

Licensee Event Report 50-219/85-006 - On 2/24/85, an automatic reactor scram occurred due to a low reactor water level during plant startup.

While reactor power was being reduced to prepare for a drywell inspection, rod movement caused a level, power, and pressure transient This led to a scram on low level despite operator attempts to stabilize the transient. In response to the scram, all controls rods fully inserted, all plant systems responded as L

expected and CR operators brought the plant to a shutdown condition.

.C Oyatcr Creek Station il Docket No. 50-219 REFUELING'INFORMATION - March, 1985 Name of Facility: Oyster Creek Station il

' Scheduled date for next refueling shutdown: November 30, 1985 Scheduleddateforrestartfolldwingrefueling: June 1, 1986

' Will refueling or resunption of' operation thereafter require a Technical

Specification change or other. license-amendment?

Yes

Scheduled date(s) for submitting proposed licensing action and supporting information

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June, 1985 iImportant licensing considerations; associated with refueling,' e.g., new or

'ditterent fuel design or supplier, unreviewed design or performance analysis

, methods, significant changes in tuel design, new operating procedures:

1. General Electric' Fuel Assemblies - fuel design and performance analysis methods have been approved by the NRC. New operating procedures, it necessary, will be submitted at a later date.

2. Exxon Fuel Assemblies - no major changes have been made nor are there any anticipated.

560

.The ntaber of fuel assemblies (a) in the core

=

(b) in the spent fuel storage pool = 1078 The present licensed spent tuel pool storage capacity and the size ot any increase.in licensed storage capacity that has been requested or-is planned, in nunber of fuel assemblies:

Present licensed capacity: 2,600 The projected date of the last refueling that.can be discharged to the spent fuel pool assuming the'present licensed capacity:

Reracking of the fuel pool is in progress. Pour out of ten (10) racks-have been installed to date. When reracking is completed, discharge capacity to the spent tuel pool will be available until 1990 refueling

-outage.

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AVERAGE DAILY POWER LEVEL NET MWe DOCKET #........ 50-219 UNIT........... Oyster Creek #1 REPORT DATE-....... APRIL 09, 1985 COMPILED BY....... WILLIAM J. EMRICH, JR.

TELEPHONE #....-.. 609-971-4637 M0tTfH MARCH,1985 DAY M

DAY g

1.

0 16.

617 2.

0 17.

428 3.

0 18.

10 4.

0 19.

388 5.

0 20.

386 6.

102 21.

394 7.

271 22.

604 8.

315 23.

607 9.

535 24.

623 10.

589 25.

625 11.

628-26.

618-12.

381 27.

613 13.

581 28.

607 14.

603 29.

618 15.

626 30.

628 31.

630

r= -

2..n....

.r.

OPERATING DATA REPORT

. OPERATING STA'IUS 1.-

DOCKET:

50-219 L

2.

REPORTING PERIOD:

March 1985 3.

ITTILITY 00NEACT:. ' JOSEPH R. MOLNAR 609-971-4699 4.

LICENSED THERMAL POWER ( Mt):

1930 5.

NAMEPLATE RATING (GROSS We):- '687.5 X 0.8 = 550

6..

DESIGN ELECTRICAL RATING (NET MWe)

.

650 7.

MAXIMUM DEPENDABLE CAPACITY (GROSS We):

650 8.

MAXIMUM DEPENDABLE CAPACITY (NET MWe):

620

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IF CHANGES OCCUR ABOVE SINCE LAST REPORT, GIVE REASONS:

NONE

.10 1 POWER LEVEL '10 WHICH RESTRICTED, IF ANY (NET We): N/A ll.'

REASON FOR RESTRICTION, IF ANY: ~ NONE MONTH YEAR CUMULATIVE 12.

REPORT PERIOD HRS 744.0 2160.0 133873.0-

~13.

HOURS RX CRITICAL 658.2 1501.0 87128.9' 14.

RX RESERVE SHTDWN HRS' O.0 0.0-469.7 15.

HRS GENERATOR ON-LINE 627.0 1399.3 84936.0 16.

(TritESERVE SHTDWN HRS ~

0.0 0.0 2.7

- 17.

GROSS THERM ENER-(W H) 936500 2380940 139643269 18.

GROSS ELEC ENER (WH)-

325830 827140 47210135 19.

NET EIEC ENER (WH) 313240 792045 45354610-20.

17f SERVICE PAC'ICR 84.3

-64.8 63.4 21.

17f AVAIL PAC'10R 84.3 64.8 63.4

.22.

Iff CAP FACTOR (MDC NET) 67.9 59.1 54.6 23. -

(Tf CAP FACTOR (DER NEf) 64.8 56.4 52.1 24.

(Tf PORCED OLPfAGE RATE 15.7 33.0 10.2 25.

FORCED OUTAGE HRS 85.8 690.2 9641.3 26..

SHUTDOWNS SCHEDULED OVER NEXT 6 MONTHS (TYPE, DATE, DURATION): N/A

27.

IF CURRENTLY SHI7fDOWN ESTIMATED STARTUP TIME:

N/A

O GPU Nuclear Corporation Nuclear

'en;see Forked River, New Jersey 08731-0388 609 971-4000 Writer's Direct Dial Number

April 15, 1985 Di rector Office of Management Information U.S. Nuclear Regulatory Commission Washington, DC 20555

Subject:

Oyster Creek Nuclear Generating Station Docket No. 50-219 Monthly Operating Report In accordance with the Oyster Creek Nuclear Generating Station Operating License No. DPR-16, Appendix A, Section 6.9.1.C, enclosed are two (2) copies of the Monthly Operating Data ' gray book infonnation) for the Oyster Creek Nuclear Generating Station.

If you should have any questions, please cont:ct Mr. Drew Holland at (609) 971-4643.

Very truly yours, P

dier Vice President and Director Oyster Creek PBF:KB: dam (0170A)

Enclosures cc: Director (10)

Office of Inspection and Enforcement U.S. Nuclear Regulatory Commission Washington, DC 20555 Dr. Thomas E. Murley, Administrator Region I U.S. Nuclear Regulatory Commission 631 Park Avenue King of Prussia, PA 19406 NRC Resident Inspector jN Oyster Creek Nuclear Generating Station Forked River, NJ 08731 g g GPU Nuclear Corocration is a subsidiary of the General Pubbc Utilities Corporation

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