IR 05000313/1986029
| ML20215N777 | |
| Person / Time | |
|---|---|
| Site: | Arkansas Nuclear  |
| Issue date: | 10/21/1986 |
| From: | Craig Harbuck, Hunter D, Johnson W, Rogers J NRC OFFICE OF INSPECTION & ENFORCEMENT (IE REGION IV) |
| To: | |
| Shared Package | |
| ML20215N768 | List: |
| References | |
| 50-313-86-29, 50-368-86-29, IEB-85-003, IEB-85-3, NUDOCS 8611070261 | |
| Download: ML20215N777 (11) | |
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APPENDIX U. S. NUCLEAR REGULATORY COMMISSION.
REGION IV
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NRC Inspection Report: 50-313/86-29 Licenses: DRP-51
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50-358/86-29 NPF-6
' Dockets: 50-313 50-368 Licensee: Arkansas Power and Light Company (AP&L)
P. O. Box-551 Little Rock, Arkansas 72203 Facility Name: Arkansas Nuclear One (ANO), Units 1 and 2 Inspection At: AN0 Site, Russellville, Arkansas
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Inspection Conducted: September 1-30,. 1986 Inspectors:
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/0/8/tib
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m W. D. Jogon, Senior Resident Reactor Date InspectoF (pars.3,4,5,6,7,9)
/D/l(/?b C. C. Harbuck, Resident Reactor.
Date
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Inspector-(pars. 2, 4, 5, 6, 8, 10)
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J./7.RogdrffResidentReactor Dat6 /
IMpector l
(par. 10)
l Approved:
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)Sft; D. R. Hunter, Chief, Reactor Date Projects Section B, Reactor Projects Branch i
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i 8611070261 861021 PDR ADOCK 05000313 G
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Inspection Summary Inspection Conducted September 1-30, 1985 (Report 50-313/86-29)
Areas Inspected:
Routine, unannounced inspection including operational safety verification, maintenance, surveillance, and followup on IE Bulletin 85-03.
Results: Within the four areas inspected, no violations or deviations were identi fied.
Inspection Summary Inspection Conducted September 1-30, 1986 (Report 50-368/86-29)
Areas Inspected:
Routine, unannounced inspection including operational safety verification, maintenance, surveillance, followup ~on a previously identified item, Licensee Event Report followup, startup testing.after refueling, disposal of treated waste, and integrated engineering safeguards test.
Results: Within the eight areas inspected, no violations or deviations were identified.
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DETAILS i
1.
Persons Contacted
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J. Levine, Director of Site Nuclear Operations R. Ashcraft, Electrical Maintenance Supervisor T. Baker, Technical Support Manager B. Baker, Operations Manager M. Browning, Maintenance Engineer
- P. Campbell, Licensing Engineer H. Carpenter, Instrumentation and Controls Supervisor B. Converse, Operations Assessment Superintendent A. Cox, Operations Superintendent G. D'Aunoy, Operations Technical Support G. Davis, Engineer R. Dyer, Planning and Scheduling Coordinator E. Ewing, General Manager Technical Support E. Force, Operations Training Supervisor M. Frala, Assistant Radiochemistry Supervisor B. Garrison, Operations Technical Support R. Gillespie, Technical Analysis Superintendent L. Gulick, Unit 2 Operations Superintendent C. Halbert, Mechanical Engineering Supervisor B. Hinton, Operations Technical Support H. Hollis, Security Coordinator
- D. Horton, Quality Assurance Manager
- D. Howard, Special Projects Manager
- L. Humphrey, General Manager, Nuclear Quality P. Jones, Instrumentation and Controls Superintendent J. Lamb, Safety and Fire Protection Coordinator R. Lane, Engineering Manager
- D. Lomax, Licensing Supervisor B. Lovett, Electrical Maintenance Engineer A. Massengale, Mechanical Maintenance Supervisor
- B. McCord, Quality' Control Inspection Supervisor A. McGregor, Engineering Services Supervisor
- J. McWilliams, Maintenance Manager N. Mosher, Nuclear Engineer V. Pettus, Mechanical Maintenance Superintendent
- D. Provencher, Quality Assurance Supervisor
- S. Quennoz, General Manager, Plant Operations E. Rice, Electrical Maintenance Supervisor P. Rogers, Plant Licensing Engineer C. Shively, Plant Engineering Superintendent R. Simmons, Planning and Scheduling Supervisor
- M. Smith, Reactor Engineering Supervisor G. Storey, Safety and Fire Protection Coordinator
- M. Stroud, Project Engineering Supervisor
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J. Taylor-Brown, Quality Control Superintendent
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L. Taylor, Special Projects Coordinator R. Taylor, Consultant (Wyle)
R. Tucker, Electrical Maintenance Superintendent B.-West, Instrumentation and Controls Supervisor R. Wewers, Work Control Center Manager
- D. Williams', Mechanical Engineering Supervisor
- G. Woerner, Licensing Engineer C. Zimaerman, Operations Technical Support
- Present at exit interview.
The inspectors also contacted other plant personnel, including operators, technicians, and administrative personnel.
2.
Followup On a Previously Identified It a (Unit 2)
(0 pen) Violation (368/8627-03):
Seismic pipe support concrete expansion anchor bolts not in configuration depicted by design drawings.
As discussed in paragraph 4 of this report, "A" HPSI pump (2P89A)
recirculation line seismic support' 2-DCB-511-H2 had one anchor bolt missing a nut.
This is contrary to the configuration depicted in the
' design drawing 2-DCB-511-H2, Rev 0, dated January 31, 1985.
This item is considered to be'another. example of this violation.
The NRC. inspector informed the licensee that their response to the violation should include this~ additional example.
3.
Licensee Event Report (LER) Followup (Unit 2)
Through direct observation, discussions with licensee personnel, and review of records, LER 86-007-00 was reviewed to determine that reportability requirements were fulfilled, immediate corrective action was accomplished, and corrective action to prevent recurrence has been accomplished in accordance with Technical Specifications.
This LER reported a reactor trip due to a reactor coolant pump (RCP) trip.
The cause of the RCP trip was found to be failure of a surge capacitor on the_RCP motor.
The three surge capacitors on this RCP were replaced prior to startup after the trip. The NRC inspector reviewed report of abnormal conditions 2-86071 and the job orders for surge capacitor replacement and breaker inspection.
The surge capacitors on the other three RCP motors were replaced during refueling outage 2RS.
The RCP motor maintenance procedures were being revised to include surge capacitor inspection the replacement at intervals recommended by the manufacturer.
No violations or deviations were identified.
4.
Operational Safety Verification (Units 1 and 2)
The NRC. inspectors observed control room operations, reviewed applicable logs, and conducted discussions with control room operators.
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i-inspectors verified the operability of selected emergency systems, reviewed tagout records, verified proper return to service of affected
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components,.and ensured that maintenance requests had been initiated for equipment in need of maintenance.
The inspectors made spot checks to verify that the physical security plan was being implemented in accordance with the station security plan.
The' inspectors verified implementation of radiation protection controls during observation of plant activities.
The NRC inspectors toured accessible areas of the units including both reactor buildings to observe plant equipment' conditions, including potential. fire hazards, fluid leaks, and excessive vibration. The inspectors also observed plant housekeeping and cleanliness conditions during the tours.
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The NRC inspectors walked down the Unit 2 service water system using licensee Procedure 2104.29, " Service Water, Auxiliary Cooling Water and Cooling Tower Makeup," Attachments A, B, C, 0, and E, and Drawing'M-2210.
Deficiencies noted were as follows:
Packing glands were loose on manual valves 25W-82, 25W-101, and
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(The licensee issued Job Requests 767334, 767335, and 767547.) Although the glands were loose, no packing leakage was observed.
Minor packing leakage was observed on valves 2CV-1404 and 2CV-1505-5.
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Stem covers were missing from motor operators for 2CV-1500-1,
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2CV-1532-1, 2CV-1502-2, 2CV-1529-2, and 2CV-1501-5.
There was an unisolable pin hole leak in the 3-inch return line from
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2E53A, the HPSI pump 2P89A cooler.
(After notifying the licensee, JO 757549 was issued.) This item is discussed in more detail below.
Seveal valves had no permanent label - 2SW-238, 2CV-1532.-1,
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2CV-1445-1, 25W-15A, 25W-17A, 25W-11A, 2SW-13D, 2CV-1456-2, 25W-0711, 25W-18A, 2SW-17C, 25W-19B, and 25W-21B.
(The NRC inspectors did not attempt to identify all unlabeled valves in the service water system; the foregoing list is not comprehensive.)
2CV-1402-1 was noted to be de-energized in the open position.
The
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licensee.had removed the corroded internals of this normally open valve during the recent refueling outage under jumper and lifted lead log serial number 2729.
The NRC inspectors expressed concern over the material condition of the service water piping of both units.
The pin hole leak noted above was another example of similar leaks that have occurred in recent months.
The licensee ~ stated that they have a program for identifying and correcting service water piping deficiencies and that it was working well.
The NRC inspectors will evaluate the effectiveness of this program durir.g the next inspection perio._
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During a routine tour of the Unit 2 auxiliary building, the NRC inspector noted two flexible conax conduits that had become separated from their associated components, exposing the cables inside. The components in the boric acid makeup tank area, were 2LS-4904 and 2CV-4921. The licensee was informed and job requests 767332 and 767333 were issued. The licensee stated that in general this type of conduit problem does not affect operability.
During the service water system walkdown for Unit 2, the NRC inspector identified a concrete expansion onchor bolt which was missing a nut on seismic support 2-DCB-511.H2, for the recirculation line of high pressure safety injection pump 2P89A.
(This finding is further discussed in paragraph 2 of this report as an additional example of a previous violation.) The licensee was notified and Report of Abnormal Conditions (RAC)
number 2-86-458 was issued on September 29, 1986, to evaluate and correct the deficiency.
These reviews and observations were conducted to verify that selected
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facility operations were in conformance with the requirements established under Technical Specifications, 10 CFR, and administrative procedures.
No other violations or deviations were identified.
5.
Monthly Surveillance Observation'(Units 1 and 2)
The NRC inspector observed the Technical Specification required surveillance testing listed below and verified that testing was performed in accordance with adequate procedures, test instrumentation was calibrated, limiting conditions for operation were met, removal and restoration of the affected components were accomplished, test results conformed with Technical Specifications and procedure requirements, test results were reviewed by personnel other than the individual directing the test, and any deficiencies identified during the testing were properly reviewed and resolved by appropriate management personnel.
The NRC inspectors witnessed the following test activities:
Monthly test of turbine driven emergency feedwater pump
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(Procedure 2106.06, Supplement 1)
Monthly tests of emergency diesel generators (Procedure 2104.36,
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Supplements 1 and 2)
"A" high pressure safety injection pump 2P89A monthly test
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(Procedure 2104.39, Supplement 1). This test verified that the pump head, although acceptable, was less than the normal value.
Plant protection system channel
"C" test (Procedure 2304.39) The NRC
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inspector noted that the test procedure for the turbine driven emergency feedwater pump was in need of revision. This revision was needed to properly set up the initial. conditions for testing this
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pump during periods when the motor driven emergency feedwater pump was running. This unusual condition was not accounted for in the test procedure and this caused confusion during the test. The licensee initiated a revision to the procedure.
No violations or deviations were identified.
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6.
Monthly Maintenance Observation (Units 1 and 2)
Station maintenance activities of safety-related systems and components listed below were observed to ascertain that they were conducted in accordance with approved procedures, Regulatory Guides, and industry codes or standards; and in~conformance with Technical Specifications.
The following items were considered during this review:
the limiting conditions for operation were met while components or systems were removed from service; approvals were obtained prior to initiating the work; activities were accomplished using approved procedures and were inspected as applicable; functional testing and/or calibrations were performed prior to returning components or systems to service; quality control records were maintained; activities were accomplished by qualified personnel;
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parts and materials used were properly certified; radiological controls were implemented; and fire prevention controls were implemented.
Work requests were reviewed to determine status of outstanding jobs and to ensure that priority is assigned to safety-related equipment maintenance which may affect system performance.
The following maintenance activities were observed:
Removal of emergency diesel generator fuel strainer 2F-1958 (Job
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Order 719015, Plant Change 86-3327)
Removal and replacement of reactor building escape hatch ends and
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doors (Job Order 718606)
Installation of new alarm panels for emergency diesel generators ~ (Job
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Orders 712737 and 719260, Design Change Package 85-1032)
Testing of Unit 2 pressurizer safety valves (Job Order 720713)
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Preventive maintenance on breaker A-307 for "B" makeup pump (P36B).
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(Procedure 1307.07) (JO 528485)
Refueling interval preventive maintenance on emergency diesel
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generator engine (Job Order 528316, Procedure 1402.66)
Repair of crankcase vacuum manometer for Number 2 emergency diesel
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generator for Unit 2 (JO 719787)
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The NRC inspector observed that the pressurizer code safety valve setpoint testing effort would have benefited from more detailed planning and preparation prior to attempting to perform the job. This matter was discussed with the site director of nuclear operations and he agreed to review the moller further.
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No violations or deviations were identified.
7.
Integrated Engineering Safeguards Test (Unit 2)
Continuing the inspection effort discussed in NRC Inspection Report 50-368/86-27, the NRC inspector observed the performance of the integrated engineering safeguards test, performed in accordance with Procedure 2305.01. The NRC inspector verified that required data was recorded for evaluation and that discrepancies were listed as required.
The NRC inspector reviewed the resolution and retest records and verified that all discrepancies were resolved by licensee personnel. At the completion of the test, the affected systems and components were returned to their normal configuration as required by Procedure 2305.01.
No violations or deviations were identified.
8.
Startup Testing After Refueling (Unit 2)
The NRC inspector reviewed the data from the following completed core physics tests associated with the startup after the fifth refueling of Unit 2, and verified that the results met the acceptance criteria and that all deficiencies were resolved.
2302.06 RTD Response Time Penalty Calculation 2302.03 Determination of CEA Worths By Exchange 2302.22 Initial Criticality Following Refueling 2302.23 Low Power Physics Base Power Level Determination 2302.28 Determination of Critical Baron Concentration and Inverse Boron Worth 2302.26 Isothermal Temperature Coefficient Measure 2302.44 Hot Functional Data Collection 2302.36 Process Variable Intercomparison 2302.09 Moderator Temperature Coefficient At Power 2302.42 Radial Peaking Factor and Rod Shadowing Factor Verification 2302.34 Power Ascension Testing Controlling Procedure
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The NRC inspector witnessed the performance of~ portions of Procedures 2302.22, 2302.23, 2302.26, 2302.09, 2302.42, and 2302.34 through the 50 percent power testing phase.
No violations or deviations were identified.
9.
Disposal of Treated Waste (Unit 2)
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- During refueli~ng outage 2R5 the licensee used a hydrochloric acid solution to clean the main condensers.
Anticipating the need to dispose of the resulting waste, the licensee requested a permit from the Environmental Protection Agency (EPA).
The EPA granted permission to discharge the treated waste water into. Lake Dardanelle in an Administrative Order dated June 30, 1986.
This Administrative Order provided specific limits on various chemical elements and on total dissolved solids.
The specified limits on copper and iron were not achieved after neutralization and treatment of the waste water, so the licensee shipped the waste to a licensed commercial waste treatment facility.
The NRC received inquiries concerning this matter by telephone and letter from members of the public.
In response to these inquiries, the NRC inspector verified the following:
The licensee was in possession of an EPA Administrative Order
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permitting release of the treated waste and specifying limits for various components.
Analysis of the treated waste indicated-that the limits on copper and.
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iron were not met.
The treated waste was not discharged into Lake Dardanelle, but was
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shipped offsite by tank trucks.
No violations or deviations were identified.
10.
Followup on IE Bulletin (IEB) 85-03 (Unit 1)
IEB 85-03, Motor-operated Valve ~ Common Mode Failures During Plant Transients Due to Improper Switch Settings, required the licensee to initiate actions to ensure that switch settings on certain safety-related motor-operated valves were set as required by design.
The NRC inspector' reviewed the licensee's program for complying with IEB 85-03.
The program, delineated in Special Work Plan 1409.56,
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coordinates IEB 85-03 testing (M0 VATS testing) with valve inspection, preventive maintenance, and environmental qualification (EQ)..The following procedures were reviewed for completeness and IEB 85-03 adherence:
1403.31, Testing of Motor Operated Valves Using The M0 VATS 2100 (as
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1403.32, Testing of Motor Operated Valves Using The M0 VATS 2100 (as
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left)
1407.37, EQ Inspection of M0Vs In. Containment
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1403.38, EQ Inspection of MOVs Outside Containment
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1403.160, Limitorque Motor-0perated Valve SMB-000 Maintenance
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1403.161, Limitorque Motor-0perated Valve SMB-00 Maintenance
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1403.162, Limitorque Motor-0perated Valve SMB-0 Through SMB-04
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Maintenance.
The NRC inspector also reviewed the following job order (J0) packa'ges pertaining to EQ and M0 VATS valve ~ testing:
Job Order Number Valve Number J0 762950 CV-1220 J0 716235 CV-1219 J0 716217 CV-1228 J0 716324 CV-1617 JO 716371 CV-2400 JO 716461 CV-2803 J0 716622 CV-7451 During review of the EQ packages 'for valves CV-1228 and CV-2803, the NRC inspector noticed that approved plant engineering action request (PEAR-No. 86-3583) authorized the use of Okonite T-95 electrical tape for EQ splicing of limitorque operator motor leads. The presence of fabric coated paper insulation on the motor wire leads precluded the use of Raychem coated butt splices approved for.EQ applications.
In discussions with cognizant licen_see personnel, the inspector concluded that the T-95 tape insulated splice may not have been EQ tested or analyzed per 10 CFR 50.49 and that the same splice may have been used in Unit 2.
This item was referred to NRC Region IV engineering for further review and will be documented in NRC Inspection Report 50-313/86-32.
The NRC inspectors observed the M0 VATS as found testing of valves CV-2617 and CV-2663 and the as left testing of CV-2619.
Field installation of the motor operator for 2CV-2803 following EQ inspection and performance of DCP 86-1083 was also observed (JO 716461).
Further observation of testing and inspection activities on motor operated valves are planned during subsequent inspections.
No violations or deviations were identifie.,
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Exit Interview c"O
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The NRC inspectors met with Mr. S. Quennoz, Acting Director, Site Nuclear.
Operations, and other members of the>AP&L staff at the end of this inspection..At this meeting, the inspectors summarized the scope of the
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inspection and the findings.
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