IR 05000338/1981029
| ML20041F900 | |
| Person / Time | |
|---|---|
| Site: | North Anna  |
| Issue date: | 01/07/1982 |
| From: | Dance H, Shymlock M NRC OFFICE OF INSPECTION & ENFORCEMENT (IE REGION II) |
| To: | |
| Shared Package | |
| ML20041F857 | List: |
| References | |
| 50-338-81-29, 50-339-81-26, NUDOCS 8203170528 | |
| Download: ML20041F900 (7) | |
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(s@ Ltioq#o UNITED STATES u
%s NUCLEAR REGULATORY COMMISSION g
r REGION 11
o 101 MARtETTA ST., N.W., SUITE 3100 o
ATLANTA, GEORGIA 30303
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Report Nos. 50-338/81-29 and 50-339/81-26 Licensee: Virginia Electric and Power Company P. O. Box 26666 Richmond, VA 23261 Facility Name:
North Anna 1 and 2 Docket Nos. 50-338 and 50-339 License Nos. NPF-4 and NPF-7 (
Inspection at North Anna site near flineral, Virginia 7!6 Inspector:
B ~cv ev
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M. B. Shymldck
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Date Signed r
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Approsed by:
C Aw H. C. Dance, Section Chief, Division of Date Signed Resident and Reactor Project Inspection SUffiARY Inspection on November 6 through December 5,1981
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Areas Inspected This routine inspection by the resident inspector involved 101 inspector-hours onsite in the areas of followup of previous inspection findings, licensee event reports, previously identified items, maintenance and surveillance activities, operational safety, and plant operations.
Results l
l Of the six areas inspected, no violations or deviations were identified in five areas. Two apparent violations were identified in one area (failure to perfonn
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i required functional test and failure to implement maintenance procedures -
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paragraph 10).
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8203170528 820300'
PDR ADOCK 05000338 G
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DETAILS
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1.
Persons Contacted Licensee Employees
- W. R. Cartwr.'ght, Station Manager E. W. Harell, Assistant Station Manager
- J. A. Hanson, Superintendent - Techr.ical Services
- J. R. Harper, Superintendent - Maintenance
- S. L. Harvey, Superintendent - Operations
- D. L. Smith, Director QA Operations J. M. Mosticone, Operations Coordinator F. Terminella, Engineering Supervisor D. E. Thomas, Electrical Supervisor
- K A. Huffman, Clerk, Other licensee employees contacted included 12 technicians,15 operators, 3 mechanics, and 4 office personnel.
- Attended one or more exit interview 2.
Exit Interview The inspection scope and findings were summarized on December 7,1981, with those persons indicated in paragraph-1 above.
The apparent violations identified in paragraph 9 were discussed with station management at that time and acknowledged.
3.
Licensee Action on Previous Inspection Findings a.
(Closed) Violation 339/81-16-01:
Failure to conduct fire brigade quarterly for each brigade. This violation is closed based on review of the program which the fire marshall has implemented.
It identifies the frequency for each brigade to conduct their drill for next year, and also has a fomal drill critique form.
The plant computer will be used to track completion of drills, b.
(Closed) Unresolved Items 339/79-03-01 and 338/80-42-04:
Clarify fire rating of dampers between battery rooms and control room. The licensee (Power Staion Engineering and Construction Group) has issued a memorandum dated September 8,1981, which addresses these concerns.
This memorandum was reviewed by NRC regional personnel.
The current installation was reviewed and it was found that the dampers are now held in the open position by means of a fusible link.
4.
Unresolved Items Unresolved items were not identified during this inspectio.
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5.
Plant Status Unit 1 and Unit 2 operated at or near capacity load during this inspection period.
6.
Followup of Previously Identified Items a.
(Closed) IFI 338/81-02-04, Evaluation of possible damage to core internals dua to loose steam generator tube plug.
111gration of the steam generator tube plug through the reactor coolant pump vanes was discussed with NRC regional personnel.
pump vibration was monitored-after plant startup and the indicated readings were nonnal.
The inspector had no further questions.
b.
(Closed) IFI 338/81-27-02 Inspection' of Reactor Coolant pump closure studs for corrosion.
Inspection report and inspection procedure were reviewed.
The inspector had no further questions.
c.
(Closed) 339/78-36-03, High Density Spent Fuel Racks. This item refers to a licensee report, S/N 666B dated February 7,1979, on a 10 CFR SE.55(e) matter concerning the possible weld burn through and the resulting spatter on the interior surfaces of the High Density Spent Fuel Racks. Specific documents were reviewed that contained the procedures directing the rework activity and inspection report documents that covered the rework activities. The racks were reworked and inspected in accordance with requirements.
7.
Licensee Event Report (LER). Followup The following LER's were reviewed and closed.
The inspector verified that reporting requirements had been met, causes had been identified, corrective actions appeared appropriate, generic applicability had been considered, and the LER forms were cor..plete.
Additionally, for those reports identified by asterick, a more detailed review was performed to verify that the licensee had reviewed the event, corrective action had been taken, no unreviewed safety questions were involved, and violations of regulations or Technical Specification conditions had been identified.
338/81-03 Loop 3 reactor coolant flow found out of tolerance
- 338/81-04 Three valve failed to operate during containment depressurization actuation test 338/81-05 Fire barrier open 338/81-06 Pressurizer pressure transmitter out of calibration
- 338/81-07 Plugs missing after explosive plugging 338/81-08 Steam generator ' A' level transmitter out of calibration
- 338/81-09 Type B&C containment leak test identified several excessive leakage point 338/81-10 Containment purge and exahust isolation system rendered
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338/81-11 Loss of power to common radiation alarm panel
- 338/81-12 Full building fans went to their failed and bypassed filter banks 338/81-13 Fire door inoperable
- 338/81-14 C1'osure weights on check valve removed
- 338/81-15 PG water isolation valve not shut
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- 338/81-16 DC Distribution service system surveillance not performed within required time 338/81-17 Excessive RCS leak rate caused by valve packing leaks
- 338/81-18 Inadvertant unblocking of low pressurizer pressure safety injection signal 338/81-19 Pressurizer level channel I indicated high
- 338/81-20 Emergency bus transformer failed 338/81-21 Rod position indicators showed greater than 12 steps from demand position 33C/81-22 T-Hot indication for channel III, Delta T/TAVE protection was found indicating high
- 338/81-26 Hydrogen analyzer had not been calibrated correctly
- 338/81-27 011 fire on IJ exhaust manifold due to gasket leak 338/81-28 Snubber was removed from component cooling system
- 338/81-29 Pressure transmitter was found out of calibration 338/81-31 Fire damper in cable tunnel failed to shut during operational inspection
- 338/81-37 Incorrect number charged bottles in control room air bank 338/81-38 Drifting of both upper and lower N44 detector currents 339/81-01 Tave less than 541*F while reactor was critical-339/81-02
'B' steam generator steam flow channel indication erratic 339/81-04 Flux penalty, failed summing amplifier 339/81-06 Tave less than 541 F while reactor was critical
- 339/81-08 Performance test not performed after power escalation 339/81-09 Personnel hatch outer door seal failed performance test 339/81-11 Quench spray valves closed and de-energized to repair valve 339/81-12 Containment pressure protection channel failed low 339/81-13 Containment pressure channel III hi and hi hi alarms locked in 339/81-14 Hi flux rate trip 339/81-15 Hydrogen recombiners removed from service for piping modifications 339/81-16 Loop A temperature indication erroneous
339/81-17 Temperature indicating controller failed high caused hydrogen recombiner to shutdown
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- 339/81-18 Quench spray valve valved out for maintenance 339/81-22 Surveillance on APDilS was not performed within required time 339/81-24 Quench spray pump and valves removed from service 339/81-25 Bcttled air system inadvertently depressurized 339/81-27 APDl15 processor overheated 339/81-28 NI power range channels surveillance was not performed in required time interval 339/81-29 Ventilation system valve stuck in midposition
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- 339/81-30 Casing cooling pump 2-RS-P-3B removed from service 339/81-31 Axial Flux difference outside target band 339/81-32 Level indication on aux shutdown panel out of specifications 339/81-33 Quench spray pump removed from service for maintenance 339/81-34 APDilS printer did not print 339/81-35 Channel A reactor coolant system subchannel declared inoperable 339/81-36 Axial flux difference outside target band 339/81-38 Channel III feedwater flow indication for loop 2 failed high 339/81-39 Blank flange found installed on redundant H2 recombiner return piping 339/81-40 Axial flux difference outside target band 339/81-41 Hydraulic snubber declared inoperative and replaced 339/81-42 Low boron concentration in boric acid storage tank 339/81-43 RWST low boron concentration 339/81-44 Rod position indication on rod 006 was declared inoperative 339/81-45 Instrument drift caused Delta T/Tave protection channel I to read hi 339/81-47 Stop valve - generator trip fail acceptance criteria 339/81-48 High voltage power supply failed on intermediate range WI-N-35 339/81-49 Casing cooling pump declared inoperative when it failed acceptance criteria 339/81-52 Failure of high voltage power suppy in intermediate range NI 339/81-54 On site AC power system was not tested in required time interval 8.
Unit 1 Loose Parts lionitor System On February 20, 1981, during a reactor trip from 100% power, an abnormal noise in 'C' steam generator was detected by the installed loose parts monitoring system (LPMS). This event was reported in LER 80-027 dated May 1, 1980.
The unit was maintained in hot standby while investigation of the loose parts was being performed.
An NRC Confirmation of Action letter dated February 26, 1980 listed several items to be conducted that had been discussed with the licensee.
Two of the items were; implementation of the eleven Westinghouse recommendations concerning abnomal noise detected, and submittal of a special report to NRC concerning the LPSf1 alarm on February 20, 1980 including subsequent testing and analysis conducted.
This special report was part of LER 80-027; The
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LER also stated that due to conclusions recently deducted from their ongoing
evaluations, that specific changes would be made in the original eleven i
Westinghouse recommended actions.
However those changes would not be made until NRC Region 11 concurrence was obtained. There were five Westinghouse recommendations that were covered by normal surveillance, that the licensee wanted to remove from the original eleven items.
LER 80-027 rev 1 dated October 28, 1981 further documented the licensee continued effort in this area.
The evaluation of licensee action related to this area has been reviewed. The information in both LERs was reviewed by the resident and regional personnel. The licensee request to reduce to the six part
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surveillance program is acceptable. LERs80-027, 80-027 Rev.1 and IFI j
338/80-11-02 are closed based on review of this item.
9.
Unit 1 Low Head Safety Injection System On November 17, 1981, while the swing shift was preparing for shift turnover, the Control Room Operator noted two valves (M0V-1862B suction valve for 18 low head safety injection (LSHI) pump and MOV-1885D,1B LHSI discharge recirculation valves shut) thus causing train B of the LHSI system to be inoperable. These valves were immediately opened.
Valve operability test had been conducted earlier that day on valves in that system with valve l10V-1885D being repositioned to satisfy a pennissive condition.
However these valves were not repositioned at the conclusion of the periodic test as requi red. The procedure has been revised to specify repositioning.
Administrative Procedure 29.3 ' Conduct of Operations, Attachment 1, SR0/CR0 Shift Turnover Check List requires verification of MOV-1862B open.
The completed check sheet for the shift change between day shift and swing shift on the 17th checked this valve open.
However, while the swing shift was preparing the shift turnover check sheet for their relief the mispositioned valves were noted.
The licensee identified these errors and has restressed the importance of the shift Turnover Check List in addition to the above procedural change.
10. Unit 2 Inoperable Snubber On September 11, 1981, while the unit was at 93% power it was discovered that the reservoir on hydraulic snubber 2-SHP-HSS-219A on a main steam line was empty. The snubber was declared inoperable and a 72 hour8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> action statement was entered.
The line from the reservoir was removed at the snubber to determine oil level.
There was no oil in the line, therefore air was introducted into the control valve block.
The snubber was removed and taken to the snubber shop for repairs. The snubber was repaired and returned to service. This event was reported in LER 339/81-071 dated October 8, 1981.
During review of the maintenance records by station QC personnel reveral problems were noted, the resident inspector also followed several concerns.
The snubber in question is an 8 inch Tomkins Johnson cylinder supplied by the Grinnel Corporation.
The snubber was removed, repaired and replaced under maintenance report N2-81-0911-2020.
The snubber was removed and replaced per mechanical itaintenance Procedure (itf1P) MMP-P-HSS-1 and oil was added per if1P-C-HSS-2. However, the repair work on the snubber ie, retorque on cylinder tie rod nuts, purging cylinder, vacuum evacuation, etc, were not accomplished per written approved procedures. This is a violation of Technical Specification 6.8.1 which requires written procedures to be established, implemented and maintained.TS 6.8.2 requires the procedures to be approved.
This is violation 339/81-26-02.
The snubber oil level was below the control valve block and maintenance was conducted on the snubber.
However, it was not functionally tested to
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demonstrate operability prior to returning it to service to clear the action statement. This is a violation of Technical Specification 4.7.10.b which requires affected snubber to be functionally tested. This is violation 339/81-26-01.
The licensee did not have a spare 8 inch snubber nor did they have the equipment to functionally test this size snubber.
Followup on the issuance of a revised LER (81-071) will be identified as IFI 339/81-27-03.
11. Plant Operations The inspector kept informed on a daily basis of overall status of the plant and of any significant safety matters related to plant operations.
Discussions were held with plant management and various members af the operations staff on a regular basis. Selected portions of daily operating logs and operating data sheets were reviewed daily during this report period.
The inspector conducted various plant tours and made frequent visits to the control room.
Observation included: witnessing work activities in progress, status of operating and standby safety systems, confirming valve positions, instrument readings, and recording, annunciator alarms, housekeeping and vital area controls.
Informal discussions were held with operators and other personnel on work activities in progress and the status of safety-related equipment or systems.
No violations or deviations were identified.