05000255/LER-1992-001, :on 911209,observed That Seal Oil Pressure on Air Side of Electrical Generator Had Decreased from Previous Reading.Caused by Malfunction of Electrical Generator Seal Oil Sys Due to Plugged Filter.Filter Cleaned

:on 911209,observed That Seal Oil Pressure on Air Side of Electrical Generator Had Decreased from Previous Reading.Caused by Malfunction of Electrical Generator Seal Oil Sys Due to Plugged Filter.Filter Cleaned

ML18057B465
Person / Time
Site:	Palisades
Issue date:	01/08/1992
From:	Hillman C, Slade G CONSUMERS ENERGY CO. (FORMERLY CONSUMERS POWER CO.)
To:	NRC OFFICE OF INFORMATION RESOURCES MANAGEMENT (IRM)
References
LER-92-001, LER-92-1, NUDOCS 9201150048
Download: ML18057B465 (10)

LER-1992-001, on 911209,observed That Seal Oil Pressure on Air Side of Electrical Generator Had Decreased from Previous Reading.Caused by Malfunction of Electrical Generator Seal Oil Sys Due to Plugged Filter.Filter Cleaned

Event date:
Report date:
Reporting criterion:	10 CFR 50.73(a)(2)(iv), System Actuation
2551992001R00 - NRC Website

text

• Palisades Nuclear Plant:

27780 Slue Star Memorial Highway, Covert, Ml 49043 January 8, 1992 Nuclear Regulatory Commission Document Control Desk Washington, DC 20555 DOCKET 50-255 - LICENSE DPR PALISADES PLANT -

GB Slade General.Manager LICENSEE EVENT REPORT 92~001-LOSS OF AIR SIDE SEAL OIL IN THE ELECTRICAL GENERATOR RESULTS IN A TURBINE/REACTOR TRIP Licensee Event ~eport (LER)92-001 is attached. This event is reportable to the NRC per 10CFR50.73(a)(2)(iv).

Gerald B Slade General Manager CC Administrator, Region III, USNRC NRC Resident Inspector - Palisades Attachment 920115004:::: 92010:::

050002'55 PD!:::

PDR ADOCK

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A CIW5 1\\/El?GY COMPANV

NRC ilo.111 lie U.I. NUCLEAll llEGULATOllY C:O...mlON 19.aJl APPJIOVEO OMI NO. 3150~104.

LICENSEE EVENT REPORT (LER)

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• 1 s 1 loF O 19 TITLE 141 OSS OF AIR SIDE SEAL OIL IN THE ELECTRICAL GENERATOR RESULTS IN A TURBINE/REACTOR TRIP IVINT DATE ftll

• LER NUMBER 181

. REPORT DATE 171

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• LICENSEE CONTACT FOR THIS LER 1121 NAME TELEPHONE NUMBER AREA COD.E Cris T Hillman, Licensing Engineer 6 11 16. 7 I 6 14 I - I 8 19 I 1 t 3 COMPLETE ONE LINE FOR EACH COMPONENT FAILURE DHCRllED IN THIS REPOllT 1131 CAUSE SYSTEM COMPONENT MANUFAC-TURER MANUFAC-TURER X

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On December 9, 1991, at 1630 hours0.0189 days <br />0.453 hours <br />0.0027 weeks <br />6.20215e-4 months <br />, with th~ plant operating at 100% power, the* turbine building auxiliary operator observed that seal oil pressure on the air side of the el.ectrical generator had decreased frrim the previous shif~

reading.

Automati~ and manual. action was taken to restore the seal oil pressure however, pressure continued to drop.

It was also observed that*

hydrogen pressure on the main electrical gen~rator was dropping.

At 1715 hours0.0198 days <br />0.476 hours <br />0.00284 weeks <br />6.525575e-4 months <br />, the Shift Supervisor ordered an emergency power reduction due to a continuing. loss of electrical generator hydrogen pressure. During the emergency power reduction, the level jn the "B" steam generator went to its high lev~l setpoint which caused the automatic closure of the feedwater regulating valve.

Steam generator level continued to increase. At 1722 hour~

control room operators initiated both a manual reactor trip and a manual turbine trip.due to increased steam generator l~vel. At 1722 hours0.0199 days <br />0.478 hours <br />0.00285 weeks <br />6.55221e-4 months <br />, with the plant operating at approximately 20% power, an automatic reactor trip on loss of load occurred when the turbine trip was initiated slightly befo~e the reactor trip.

The cause of the event was a malfunction in the electrical generator seal oil system due to a plugged filter.

No root ~ause for the plugging of the filter*

was determined.

Numerous short term corrective actions related to minor equipment problems observed during the emergency power reductiori were taken prior to re-start of the plant.

Long term torrective actton includes evaluation and troubleshooting of the main generator air side seal oil system.

NRC Form 318 19-831

LICENSEE EVENT REPORT !LERl TEXT CONTINUATION

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EVENT DESCRIPTION

On December 9, 1991, at 1630 hours0.0189 days <br />0.453 hours <br />0.0027 weeks <br />6.20215e-4 months <br />, with the plant operating ~t 100% power, the turbine building auxiliary operator_ observed that seal oil pressure on the air side of the electrical generator [TK;GEN] had detreas~d from the previous shift r~ading. The operator immediately notified the c9ntrol room df the

• observed condition. Approxtmately 35 minutes.1 ater ( 1705 hours0.0197 days <br />0.474 hours <br />0.00282 weeks <br />6.487525e-4 months <br />) the auxiliary operator observed that the ~eal. oil pressure was continuing to drop.

Automatic and manual action was taken to restore the seal oil pressu~e but at 1714 hours0.0198 days <br />0.476 hours <br />0.00283 weeks <br />6.52177e-4 months <br /> seal oil pressure was observed as continuing to dropping.

It was also ob~e~ved that hydrogen pressur~-on the main electrical generator was dropping.

At 1715 hours0.0198 days <br />0.476 hours <br />0.00284 weeks <br />6.525575e-4 months <br />, the Shift Supervisor ordered ati emergency power reduction due to a continuing loss of electrical generator hydrogen pressure.

During th~ emergency power reduction, the level in the "B" steam generator [AB;SG] went to its high level setpoint which caused tha automatic cl~sure of*

• the f~edwater regulating valve CV-0703 [SJ;FCV]. Steam generator level continued to increase and it was assumed that the level would approach or exceed the level required for a mandatory trip of the reactor. At 1722 hours0.0199 days <br />0.478 hours <br />0.00285 weeks <br />6.55221e-4 months <br />, control room operators initiated both a manual reactor trip-and a manual turbine trip. At 1722 hour0.0199 days <br />0.478 hours <br />0.00285 weeks <br />6.55221e-4 months <br />sj with the plant operating at* approximately 20~

• power, an automatic reactor trip on loss of load occurred since the turbine

• trip was initiated slightly before the reactor trip.

The following is a ch~onological sequence related to this event.*

.December 9, 1991

_ *.. 1630. Secondary side auxiliary operator notes the air side seal oil presstire is 85 psig instead of 89 psig as on the last shift. The*

. auxi 1 i ary-operat()r reports the discrepancy to the control room.

The Shift Engineer notifies the System Engineer of the problem.

1705 Secondary side auxiliary operator reports to the Control Room that seal oil pressufe is continuing to drop and is at 82 psig.

1710 P~23 Air Side Seal Oil Backup Pump starts automaticall~ as air side s~al oil pressure approaches generator hydrogen pressure.

1711 *Control operator infor~s Region Power Control Jackson, Michigan of the situation and the potential for a power reduction.

1714 Shift Supervisor directs* opening of the Backup Regulating Valve Bypass Valve in an attempt to restore air side seal oil pressure.

Air side seal oil pressure was approximately 68 psig and dropping along with hydrogen pressure.

At this point, a report was received of smoke coming from the generator seals.

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electrical generator hydrogen pressure.

1715/ Announcement made for unauthorized personnel to stay clear of the turbine building area due to the loss of hydrogen to the area.

1716 1716

_ 1717 A 4-inch deviation al~rm is re~eiVed for control rod 36.

At two times during the rapid power reduction~ the control operatrir shifts __

to manual individual for this-control rod and to -drive* it ba,ck within its group.

During the emergency power reduction, the PCS cold leg temperature drops below 525°F.

This places the plant in a limiting condition of operation (LCO) as defined by Technical Specification-3.0.3. The*

control operators take action to compensate by balancing turbine and

. reactor power.

An 8-inch deviation alarm oc~urs for control rod 36 as a result of it driving in slower than the other r6ds in 1ts group.

This caOses eritry into the action statement of Technical Specification 3.10 as a result of control rod 17 being previously declared inoperable.

1717 The coritrol operat6rs manually trip main feedwater pum~ P-18 as part of the emergency power reduction.

1718 PCS cold leg t~mperature returns to greater than 525°f. This allows exiting Technical Speciftcation 3.0.3.

• The lowest cold leg temperature reached was 517°F.

1720 PCS cold leg temperatur~drops below 525°F.

The LCO for Technical Specification 3.0.3 is entered. The control* operators compensate

- further for the mismatch between reactor power and turbine demand.

1721 Steam Generator E-508 high level occu-rs causing an automatic closure of feedwater reg~lating valve CV-0703.

1722 The control operators simultaneously initiate a reactor and turbine trip as it appears that Steam Generator E-508 level_ is continui'ng to rise and will approach the point at which a mandatory trip is required.

The highest level reached was 92%.

1722 An automatic reactor trip on loss of load occurs since the turbine trip is initiated_ slightly before the reactor trip.

1722 Control operator notes that all control rods immediately insert as required with no noticeable lag in drop time for any control rods as indicated by the control rod matrix display and deviation lights.

LJCENSEE EVENT REPORT ILERl TEXT CONTINUATION

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__........,.IMC"- llM'111171 1722 Shift S~pervisor otders the actions of Emergency Opetating Procedu~e, EOP-1 to be performed.

• _1723 PCS cold leg temperature returns to greater than 525°F~ techriical

• Specification 3.0.3 is exited.

Lowest cold leg temperature during the period was 516°F.

1723 A malfunction in the annunciator alarm bell is thought to have occurred.

• The Shift Su~ervisor stations additional personnel to observe for alarms being initiated without an audible alarm.

- 1725 Shift Supervisor orders main electrical generator hydrogen to.be vented td the atmosphere and the electrical gen~rator purged with carbon dioxide. Shift Supervisor also orders the turbine building roll up doors opened and the roof exhausters started.*

1730 EOP-1 is completed with no discrepancies identified.

EOP-2 is initiated.

GCL-10 checkli~t is commenced.

1735. An Unusual Event is.declarea under the miscellaneous category. It is the Shift Supervis6r's opiriion that plant ~ondition~ warrant.elevated attention due to the escape of significant quantities of hydrogen gas into th~ turbine building and the possibility for ari explosion.

1743 EOP-2 Safety Function Status Checks a.re completed with no discrepancies noted.

1743 Notification of the Unusual Event is made to Van B~ren County.

• 1750 Notific~tion of the Unusual Event is made to the State Police-South Hav~n due to probl~ms contacting the State of Michigan-Lansing with the auto-dialer. Contact with the Lansing representative was finally made by manually dialing the number.

1759 Notification of the Unusual Event is made to the NRC.

- 1800 Manually started turbine-generator bearing lift pumps at the System

. Engineer's ~equest due to concern for iriadequate lubrication due to water in the lube oil.

- 1830 Steam generator blowdowns are reduced from 30,000 lbs/hr to 18,000 lbs/hr to prevent.the flash tank relief from being lifted. Backwash of tbe Feedwater Purity filters was initiated to place an artificial steam demand on the flash tank.

- 1900 Att~mpted to manually open Steam Generator E-50A main steam isolatio~

valve (MSIV) bypass_ valve M0-0510 u_sing the manual operator on the Limitorque operator.

The handwheel could be moved only three turns.

LJCENSEE EVENT REPORT (LERl TEXT CONTINUATION J a*,,,..... c:..::.*~ *E~.......... :Q * :.:..... a..:..

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- 2100 Follow-up notification w~s made to the NRC stating that the turbine and reactor _trips were both initiated by the operators but the turbine was tripped slightly before the reactor which resulted in an atitomatic reactor trip on loss of load trip.

2120 The Feedwater Purity demineralizer system was started up to begin makeup to Demineralized Water Tank, T-939.

2133 MSIVs wer~ closed to maintain PCS temperature. Since M0-0510 {Steam

_Generator E-50A MSIV Bypass Valve) could not be opened only S~_eam.

Generator E-50B could be used for PCS temperature control.*

• 2316 Reduced condenser vacuum to ~top the turbine generator. Turbine generator placed on turning gear; December 10, 19~1 0050 Terminated Unusual Event._ Notifications made to the NRC, the State of Mi ch_i gan and Van Buren County.

• This event is reportable to the NRC per 10CFR5b.73(a)(2){iv) as a* condttion that resulted in the automatic actuation of *an Engineered Safety Feature, the

• Reactor Protection System.

CAUSE OF THE EVENT

The cause of the event was a malfunction in the electrical generator seal oil*

system.

Subsequent investigation determined that the.air side seal oil filter was plugged.

No root cause for the plugging of the filter was determined.

This event did not involve the failure of equipment important to safety.

ANALYSIS OF THE EVENT

PRE-TRIP.CONDITIONS Conditions prior to the trip were st~ble with all systems in a normal full power alignment.

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1.

• Control rod 17 was-*considered inoperable as a result 6f its not being exercised on the required frequency.

This condition resulted from the rod having a high seal leak-off tempe~atu~e ind the feeling that biweekly exercising might aggravate the problem.

No Technical Specifications action was required for this item provided no other rods became inoperable.

2.

• Steam Generator -E..;50A.MSIV Bypass Valve M0-0510 was caution tagged with its breaker open stattng that it should only be operated manually until motor operator testing was performed for the valve. A packing leak had been previously.corrected by tightening the packing gland a'nd use of the motor operator was restricted to prevent damage to the operator.

3. A high water content had been apparent in the main lube oil system for some days prior to the trip. The problem was being evaluated by System Engineering and Westinghouse representatives. Additional sampling of the oil and actions to remove the water were in progress during this period.

POST-TRIP REVIEW ITEMS An emergency power reduction was initiated as a result of a loss of generator hydrogen p~essure due to a malfuriction in the air *side seal oil system.

Evaluation and troubleshootiTig of the system was performed and it was determined that the aii side seal oil filter was plugged.

A turbine and reactor trip was initiated due to a high level in E-508 Steam Generator resulting from slow or unstable feedwater level control at low power.

The following equipment problems and plant conditions were noted during_the emergency power reducti~Q:

1. Control rod 36 drove in slower than the other control rods in it~ group eventually resulting in an 8-inch deviation. Through troubleshooting it was determined that the c6ntrol rod drive package should be replaced.

2.

An increase in radiation levels in the vicinity of the Volume Control Tank. (VCT) and Charging Pump accumulators was identified when an auxiliary operator noted th.at he had received approximately 3 mill i rem

• checking the area.

Normally no readable dose is received. Subsequent surveys showed 30-40 mRem/hour at the charging pumps (pre-trip 7-12 mRem/hour) and greater than l Rem/hour at the VCT (pre-tr"ip 50-75 mRem/hour).

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3.

Dose equivalent iodine in the PCS increased from 0.028 microcuries/ml to 0.458 microcuries/ml~

4; High radiation alarm occurred briefly on Circulating Water Process Radiation Monitor RIA-1323.

5.

The Control Room annunciator audible alarm appeared to malfunction during the power reduction or trip and was thought to not sound for all alarms.

6.

Difficulties were encountered in notifying Region Power Control, Grand Rapids, Michigan after the trip.

.A recorded message gave another number to call.

7.

Steam Generator E-50A MSIV bypass valve M0-0510 could not be opened using the L imitorque manual handwheel.

Only three turns. of the handwheel could be obtained.

8.

Announcements of the Unusual Event could not be heard in some areas of the plant.

In particular, the PA system in the old demineralizer area of the turbine building and the 590' area of the auxiliary building were problem areas.

Work orders were written for these two areas.

- 9.

During emergency notifications, the-auto-dialer failed to connect with the State of Michigan-Lansing.

Later, contact was successfully made by direct dialing the same number.

10.

The telephone on the north end of the turbine deck did not work.

• 11.

The differential pressure indication for Air Side Seal Oil Filter F-65 on the Westinghouse turbine diagnostic (Gen-Aid) system was not available because the computer indicated that the sensor had failed.

12.

Nuclear Instrumentation NI-007, for the upper half of the core, did not indicate or track with the other nuclear instruments as would be expected.

~

13.

Back-up Reactor Protective System (RPS) Breaker 42-2 did not trip with breaker 42-1 when the trip pushbutton on the RPS panel (C06) was depressed by the control operator as part of the post trip actions. A Work Order wa~ written to troubl~shoot this problem;

14. A Main Feedwater Pump Low Suction Pressure alarm was noted to occur at one point during the power reduction.

LICENSEE EVENT REPORT !LERI TEXT CO~TINUATION

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15. A procedure for venting hydrogen from the rnain electrical gene*Y.ator for the plant conditions at the time of thiS event was not found.

The procedure for replacing-the hydrogen with carbon _dioxide requires less than 3 psig hydrogen initially. This situation was brought to the attention of the* Oper~tions procedure group for resolution.

16.

The procedure for replacing the hydrogen with carbon dioxide requires removal of the hydrogen spool piece prior to aligning carbon dioxide.

An opt~on should*be provided for emergency situations to isolate the spool piece and remove it later in the procedure. This situation was brought to the attention of the Operations procedur~ group for resolution.

17.

RI-47, "Auto Rod Withdrawal Probibit Interlock Matrix Check" was initiated prior to obtaining rod drop times from critical functions.

monttor (CFMS).

RI-47 causes.the times to be overwritten and lost. The d~bp times are required for the*post trip review process of

.Administrative Procedure 4.08.

CORRECTIVE ACTION

The following corrective actions were taken prior to start-up from this event:

1.

The air side seal oil failure was caused by plugging of the air side seal oil filter. lhe filter was dis~ssembled, cleaned ~nd re-assembled.

• No unusual debris was found-in the filter.

No actual root cause for why the filter was plugged was determined, however, it appears that plugging of the filter may be related to the high water content in the turbine lube oil system.

2.

The drive package.for control rod 36 was replaced. *Control rod 36 was tested and determined to perform satisfactorily.

3.. Adjustments *were made to the steam generator level control system.

During plant start-up from this event the level control system was monitored continuously by operators and the l&C group.

Several adjustments were made during start~up to fine tune system response. *,

4.

The Contro1 Room*annunciator alarm bell plunger and several ala~m cards were replaced.. Troubleshooting could not re-produce the problem of the bell not sounding for alarms.

• s. The public address (PA) system was walked down by i&C.

Several adjustments were made to the 16cal stations identified as problem areas during this event to restore operability.

LJCENSEE EVENT REPORT (LcRl TEXT CONTINUATION

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6.

The e~ergency notification auto-dialer was re-programmed and verified

. to operate properly.

7. The NI-07 problem was determined to be a problem with the datalogger and not the NI.

8.

The failure of back-up RPS breakers 42-1 and 42-2 was determined to be a problem with the reactor trip pushbutton on the RPS panel (C-06).

The pushbutton was replaced however, incomplete depression of the pushbutton could st i 11 result in the failure of one of the two breakers to perform its trip function.

A ca1,1.tion placard was mounted next to the pushbutton to warn.the operators.

The operators were also briefed on the problem.

The following long term corrective actions were assigned:

1.

Evaluate and troubleshoot the performance of the main electrical generator.seal oil system.

Provide additional corrective actions based on the.troubleshooting.

2.

Evaluate and troubleshoot the performance of the public address (PA) system.

ADDITIONAL INFORMATION

None