IR 05000269/1987004

Insp Repts 50-269/87-04,50-270/87-04 & 50-287/87-04 on 870113-0209.No Violation or Deviation Noted.Major Areas Inspected:Operations,Surveillance,Maint,Verification of ESF Linups,Followup of Events & Shutdown Work in Progress

ML20211N074
Person / Time
Site:	Oconee
Issue date:	02/17/1987
From:	Bryant J, Peebles T, Skinner P, Wert L NRC OFFICE OF INSPECTION & ENFORCEMENT (IE REGION II)
To:
Shared Package
ML20211N011	List: IR 05000269/1987004 ML20211N007
References
50-269-87-04, 50-269-87-4, 50-270-87-04, 50-270-87-4, 50-287-87-04, 50-287-87-4, NUDOCS 8702270434
Download: ML20211N074 (8)

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p K f %q'o UNITE 3 STATES NUCLEAR REGULATORY COMMISSION

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Report Nos: 50-269/87-04, 50-270/87-04 and 50-287/87-04 Licensee: Duke Power Company 422 South Church Street Charlotte, N.C.

28242 Facility Name: Oconee Nuclear Station Docket Nos.: 50-269, 50-270, and 50-287

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License Nos.: DPR-38, DPR-47, and DPR-55 Inspection Conducted: January 13 - February 9, 1987 Inspectors:

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Approved by:

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T. A. Peebles, S'ection Chief Date Signed Division of Reactor Projects SUMMARY

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Scope:

This routine, announced inspection -involved resident inspection on-site in the areas of operations, surveillance, maintenance, verification.of engineered safety features lineups, followup of events, and shutdown work.in progress.

Results: Of the six areas inspected,'no ~ violations or deviations were identified.

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REPORT DETAILS 1.

Licensee Employees Contacted

.M. S. Tuckman, Station Manager T. B. Owen, Maintenance Superintendent R. L Sweigart, Operations Superintendent

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J. M. Davis, Technical Services Superintendent C. L. Harlin, Compliance Engineer

• F. E. Owens, Assistant Engineer, Compliance

• L. V. Wilkie, Superintendent of Integrated Scheduling Other licensee employees contacted included technicians, operators, mechanics, security force members, and staff engineers.

Resident Inspector:

• i. C. Bryant

• L. D. Wert

• Attended exit interview 2.

Exit Interview The inspection scope and findings were summarized on February 9, 1986 with those persons indicated in paragraph 1 above.

The licensee did not identify-as proprietary any of the materials provided to or reviewed by the inspectors during this inspection.

3.

Licensee Action on Previous Enforcement Matters Not inspected.

4.

Unresolved Items No unresolved items were identified during this inspections.

5.

Plant Operations The inspectors reviewed plant operations throughout the reporting period to verify conformance with regulatory requirements, technical specifications (TS), and administrative controls.

Control room logs, shift turnover records, and equipment removal and restoration records were reviewed routinely.

Interviews were conducted with plant operations, maintenance, chemistry, health physics and performance personnel.

Activities within the control rooms were monitored on an almost daily basis.

Inspections were conducted on day and on night shifts, during week days and on weekends.

Some inspections were made during shift change in order to

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evaluate shift turnover performance.

Actions observed were conducted as required by Operations Management Procedure 2-1.

The canplement of licensed personnel on each shift inspected met or exceeded the requirements of TS.

Operators ~were responsive to plant annunciator alarms and were cognizant of plant conditions.

Plant tours were taken throughout the reporting period on a routine basis.

The areas toured included the following:

Turbine Building Auxiliary Building

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Units 1, 2, and 3 Electrical Equipment Rooms Units 1, 2, and 3 Cable Spreading Rooms Station Yard Zone within the Protected Area Standby Shutdown Facility During the plant tours, ongoing activities, housekeeping, security, equipment status, and radiation control practices were observed.

Unit 1 began the report period, January 13 to February 9,1987, at 98%

power, restricted by high level in B steam generator.

On January 13 power was increased to 100%.

On January 21, power was reduced to 90%. There had been a buildup of gases in the Unit 1, main stepup transformer over the past few months and the power reduction was an attempt to learn if the gas concentration was power sensitive.

After ten days, power was returned to 95% and was continued at that level for the remainder of the report period.

Unit 2 began the report period at 94% power, restricted by high steam generator level, and operated at that power until January 18 when it was taken to hot shutdown to investigate low level noise detected by the loose parts monitor.

The unit was started up on January 18 and tripped from 19%

power.

The reactor was started up again on January 19 and reached 95% on that day.

The shutdown and trip are discussed in paragraph 8 of this report.

Unit 2 continued operation at 97% for the remainder of the report period.

Unit 3 began the report period in refueling shutdown and continued in that

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mode throughout the report period.

The shutdown is discussed in paragraph 11.

No violations or deviations were identified.

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Surveillance Testing The surveillance tests listed below were reviewed by the inspector to verify procedural and performance adequacy.

The completed tests reviewed were examined for necessary test prerequisites,

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instructions, acceptance criteria, technical content, authorization to begin work, data collection, independent verification where required, handling of deficiencies noted, and review of completed work.

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The tests witnessed, in whole or in part, were inspected to determine that approved procedures were available, test equipment was calibrated, prere-quisites were met, tests were conducted according to procedure, test results were acceptable and systems restoration was completed.

Surveillances witnessed in whole or in part:

IP/0/A/3001/11 230KV Switchyard Battery Monthly Surveillance IP/0/A/0310/13C Engineered Safeguards System Logic Subsystem 2 LPI Channel 4 On Line Test IP/0/A/0310/12C Engineered Safeguards System Logic Subsystem 1 RB Isolation and Cooling Channel 5 On Line Test No violations or deviations were identified.

7.

Maintenance Activities Maintenance activities were observed and/or reviewed during the reporting period to verify that work was performed by qualified personnel and that approved procedures in use adequately described work that was not within the skill of the trade.

Activities, procedures and work requests were examined to verify proper authorization to begin work, provisions for fire, clean 11-ness, and exposure control, proper return of equipment to service, and that limiting conditions for operation were met.

Maintenance witnessed in whole or in part:

WR 50315F Disassembly and Reassembly of Limitorque Operator for Valve 3SSH-3 WR 57260B High Pot Testing of 3A and 3B Emergency Feedwater Breakers WR 50104F Movats Testing of Valve 3C391 WR 57259D Cleaning of Emergency Feedwater Pump Turbine Oil Cooler WR 99255B Revise C' LPI Pump Controls Preventive Maintenance on Valves MS-83 and 85, Unit 3 Examination of Reactor Coolant Pump 3RCPB1 No violations or deviations were identified.

8.

Unit 2 Trip From 19% Power On January 18, 1987, Unit 2 tripped from 19% power following a reduction to hot shutdown to locate the source of noise detected by the loose parts monitor (LPM).

At 6:50 a.m. on January 17, a reactor operator performing instrument surveillance noted low level noise, without alarm, on three points of the LPM.

The points were all related to the B steam generator (OTSG).

Duty engineers were notified and recordings of the three points were begu "

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4-Noise analysts from the Duke general office came to the site to analyze the noise.

At 2:45 a.m. power reduction to hot shutdown was begun to permit reactor building entry.

The noise faded away during secondary system flow reduction.

The only possible source of the noise detected was a piece of loose insulation located about two inches from the feedwater line.

Due to the noise disappearing during secondary system shutdown and inability to locate a-noise source, it was decided to restart the unit and criticality was reached at 5:16 p.m. on January 18. While the main turbine was being accelerated to 1800 RPM, it tripped at 1500 RPM due to a 22 second loss of a turbine oil pump.

After checking the oil system, the turbine was brought to speed and placed on line.

As power increased to 19% at 10:23 p.m.,

the turbine tripped causing an anticipatory reactor trip.

The apparent cause was that contact buffers for the turbine to reactor anticipatory trip had not been reset after the turbine trip at 1500 RPM. The reactor operator stated that there had been a feedwater increase followed by a power surge to 19% from 16%.

This was just before he reached the procedure step calling for verification that the buffers had been reset.

The reactor was taken critical again at 5:09 a.m. on January 19.

As the turbine was being brought to speed it tripped at 100 RPM on low oil pressure.

After investigation, the turbine was brought to speed and placed on line at 15% power.

The system reached 94% power at 6:18 p.m. on January 19.

No violations or deviations were identified.

9.

Unusual Event - Personnel Injury An Unusual Event was declared at 10:30 a.m. on January 20, when two uen were injured while working in a reactor coolant pump cavity. The injury occurred when an

'I' beam above the work area was inadvertently released.

One man received a puncture wound in one leg and deep lacerations in the other. The second man received bruises on the back.

Both men were transported to the local hospital and treated. They were able to return to work the next day.

A health physics supervisor and four technicians accompanied the men to the hospital.

One man was transported in his anti-C clothing due to the nature of his injuries.

Neither man was contaminated on his person, although there was some contamination on the anti-C clothing. Contamination was contained by the HP personnel and there was no contamination of the emergency room or ambulance. All materials used were returned to the Oconee site.

The Unusual Event was terminated at 1:30 p.m. on January 20.

No violations or deviations were identified.

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10. Examination of Check Valves MS-83 and MS-85 In the Safety System Functional Inspection Report (50-269,270,287/86-16)

concern was expressed that valves MS-83 and MS-85 were not periodically tested in the reverse flow direction.

MS-83 and MS-85 are chack valves in the two steam lines which take off from the main steam headers, one from each header, and operate the emergency feedwater turbine driven pump turbine when called upon..These valves have been in operation approximately twelve years.

During the current Unit 3 refueling outage, these 6 inch valves, 3MS-83 and 3MS-85, were cut out of the lines for examination. The valves were found to be completely operational and no threatening defects were detected, although there was some steam scoring of the valve seats and discs. The valves were examined by liquid penetrant, the seats were lapped and new discs installed.

Current plans are to rework valves 1MS-83, IMS-85, 2MS-83 and 2MS-85 on the next refueling shutdown of.the respective units.

No violations or deviations were identified.

11. Unit 3 Refueling Outage As stated in IE Report No.50-269,270,287/86-34, Unit 3 was shut down early for refueling outage due to damage to reactor coolant pump (RCP) 3B1 and increased vibration in RCP 3B2.

All fuel was removed from the reactor and the core barrel assembly was removed to permit inspection of the vessel.

Metal shed by RCP 381. impeller, wear ring and suction piece adapter were removed.

All four reactor coolant pumps were removed for inspection and maintenance and to permit inspection of the reactor coolant system cold

legs.

Inspection of the cold legs is still in progress.

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.ections cf fuel assembly lower end fittings revealed loose metal in most of them. All of the metal seen has been removed with the assistan:e of a Combustion Engineering team. This inspection and removal continues and is expected to.be completed by February 10.

Inspection has revealed no damage to the fuel other than minor surface abrasions, and all fuel scheduled to be reinstalled in the reactor will be installed. During operation there was no overheating of fuel assemblies and no core power changes were indicated.

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All metal removed from the vessel and fuel to date is estimated to weigh from 25 to 50 pounds and has ranged in size from fractions of an ounce to 2 to 3 pounds.

Inspection of RCP 3B2, which demonstrated increased vibration and preci-pitated the early shut down, revealed no cause for increased vibration. Two bearing housing cap screws were found broken, but this apparently had no relationship to the vibration.

Bearing housing cap screw failures were discussed in IE Reports No.50-269, 270, 287/85-26 and 85-27. The vibration experienced was not extreme and possibly would not have caused shut down were it not for the problems experienced with RCP Bl.

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Werk performed and current status of RCP's is as follows:

RCP 3Al - is a refurbished pump and has had new bearing cap screws and new wear ring and suction piece adapter bolts installed.

It is now in place.

3RCP A2 - had previously been refurbished and now has new wear ring and suction piece bolts installed. Will be reinstalled this week.

3RCP B1 - is being totally refurbished and casing work is in progress.

The wear ring / suction piece bolts to the casing were found broken, which allowed the suction piece / wear ring to be forced into the impeller.

Further details in report 50-269/87-01.

3RCP B2 - has had new bearing cap screws, and new wear ring and suction piece bolts installed.

It is now back in place.

Other shutdown work in progress includes the following :

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Eddy current testing of 31,000 steam generator tubes is complete with approximately 45 tubes to be plugged.

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Ultrasonic examination of feedwater piping.

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Rebuilding of 111 Limitorque valve operators, with 75 rebuilt to date.

Unit 3 startup is currently scheduled for March 20 and is possibly ahead of that schedule.

12. Open Items The following items are being closed based on inspection and/or discussions with licensee personnel as appropriate.

(Closed) LER 269/86-12: Emergency Discharge Valve Opened Without Command Due to Component Malfunction.

The inspectors witnessed portions of the work on this LER as reported in IR50-269/86-26.

In IR50-269/86-34 it was reported that the inspectors reviewed the station modifications.

All work had been completed at that time.

l Part 21 Reports (Closed) P2185-01; DN50-269,270,287: Effect of Lube Oil Modification on Circulating System - Emergency Generator Lube 011.

In an inter-office letter dated February 25, 1985, Morrison-Knudsen Co., Inc. states that the Oconee station has the described DC motor, but a bypass line with orifice was included, which relieves the problem.

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(Closed) P2185-03; DN50-269,270,287: Defective Analog Level Detector.

In a letter to DPC Manager of Engineering Services dated May 16,1986, DPC E&I reported that all TEC model 914-1 modules at Oconee had passed the pres-cribed test and, therefore, do not exhibit the described problem.

(Closed) P2185-05; DN50-269,270,287: K-Line Circuit Breakers.

In an internal report dated 7/31/86, Oconee engineers reported that all affected breakers at Oconee had been inspected for the referenced problem and none were found to exhibit the problem.

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