IR 05000400/1992010
| ML18010A695 | |
| Person / Time | |
|---|---|
| Site: | Harris  |
| Issue date: | 06/24/1992 |
| From: | Christensen H, Shannon M, Tedrow J NRC OFFICE OF INSPECTION & ENFORCEMENT (IE REGION II) |
| To: | |
| Shared Package | |
| ML18010A692 | List: |
| References | |
| 50-400-92-10, NUDOCS 9207270041 | |
| Download: ML18010A695 (12) | |
Text
~
AS AEGII~
- "'~
+/g (4
++*++
Report No.:
UNITED STATES NUCLEAR REGULATORY COMMISSION
REGION II
101 MARIETTASTREET, N.W.
ATLANTA,GEORGIA 30323 50-400/92-10 Licensee:
Carolina Power and Light Company P. 0. Box 1551 Raleigh, NC 27602 Docket No.:
50-400 Licensee No.:
NPF-63 Facility Name:
Harris
Inspection Conducted:
May 23
- June 19, 1992 Inspectors: ~
~
~
~
drow, Senior Resident Inspector at Signed P
M.
annon, Resident Inspector t
igned Approved by:
H. Christensen, Secti C
ef Division of Reactor Projects Date Signed SUMMARY Scope:
This routine inspection was conducted by two resident inspectors in the areas of plant operations, radiological controls, security, fire protection, surveillance observation, maintenance observation, design changes and modifications, and licensee action on previous inspection items.
Numerous facility tours were conducted and facility operations observed.
Some of these tours and observations were conducted on backshifts.
Results:
No violations or deviations were identified.
Good operator response and attention to detail were noted, as discussed in paragraph 2.b.(2).
A weakness was noted in paragraph 4 regarding the failure to properly add oil to the turbine driven auxiliary feedwater pump.
920727004l 920b24 PDR ADOCK 05000400 Q
REPORT DETAILS 1.
Persons Contacted Licensee Employees
- J. Collins, Manager, Operations
- J. Cribb, Manager, Quality Assurance
- C. Gibson, Manager, Programs and Procedures C. Hinnant, General Manager, Harris Plant D. Knepper, Manager, Site Engineering B. Meyer, Manager, Environmental and Radiation Monitoring T. Morton, Manager, Maintenance
- J. Moyer, Manager, Project Assessment J. Nevill, Manager, Technical Support C. Olexik, Manager, Regulatory Compliance H. Smith, Manager, Radwaste Operation
- G. Vaughn, Vice President, Harris Nuclear Project E. Willett, Manager, Outages and Modifications
- L. Woods, Manager, System Engineering Other licensee employees contacted included office, operations, engineering, maintenance, chemistry/radiation and corporate personnel.
2.
- Attended exit interview Review of Plant Operations (71707)
The plant continued in power operation (Mode 1) for the duration of this inspection period.
a ~
Shift Logs and Facility Records The inspector reviewed records and discussed various entries with operations personnel to verify compliance with the Technical Specifications (TS) and the licensee's administrative procedures.
The following records were reviewed:
Shift Supervisor's Log; Control Operator's Log; Night Order Book; Equipment Inoperable Record; Active Clearance Log; Grounding Device Log; Temporary Modification Log; Chemistry Daily Reports; Shift Turnover Checklist; and selected Radwaste Logs.
In addition, the inspector independently verified clearance order tagouts.
The inspectors found the logs to be readable, well organized, and provided sufficient information on plant status and events.
Clearance tagouts were found to be properly implemented.
No violations or deviations were identifie Facility Tours and Observations Throughout the inspection period, facility tours., weie conducted to observe operations, surveillance, and maintenance activities in progress'.
Some of these observations were conducted during backshifts.
The facility tours and observations encompassed the following areas:
security perimeter fence; control room; emergency diesel generator building; reactor auxiliary building; waste processing building; turbine building; fuel handling building; emergency service water building; battery rooms; electrical switchgear rooms; and the technical support center.
Also during this inspection period, licensee meetings were attended by the inspectors to observe planning and management activities.
During the above tours, the following observations were made.
(1)
Monitoring Instrumentation
- Equipment operating status, area atmospheric and liquid radiation monitors, electrical system lineup, reactor operating parameters, and auxiliary ecpxipment operating parameters were observed to verify that indicated parameters were in accordance with the TS for the current operational mode.
(2)
Shift Staffing - The inspectors verified that operating shift staffing was in accordance with TS requirements and that control room operations were being conducted in an orderly and professional manner.
In addition, the inspector observed shift turnovers on various occasions to verify the continuity of plant status, operational problems, and other pertinent plant information during these turnovers.
On May 23, 1992, an auxiliary operator noticed an oil leak on the lube oil cooler for the turbine driven Auxiliary Feedwater Pump (APW) pump.
Further inspection of the cooler revealed that an incorrect shell side drain blank flange had been installed which was made out of rubber and pressboard.
A work request and temporary modification were generated to return the system to design, specifying that the flange material be stainless steel.
During a power reduction on May 27, 1992, to troubleshoot problems with the main turbine Digital Electro-Hydraulic Control (DEHC) system,
(4)
(6)
the DEHC system malfunctioned and caused an increase in turbine load of approximately seven percent.
The DEHC system had.been placed in automatic control to assist in troubleshooting efforts.
The pre-evolution brief anticipated this type of failure and operators expeditiously placed the system in manual control which stopped the power excursion at approximately 94 percent.
The prompt operator action and attention to detail noted above was considered to be noteworthy..
Plant Housekeeping Conditions
- Storage of material and components, as well as cleanliness conditions of various areas throughout the facility were observed to determine whether safety and/or fire hazards existed.
Radiological Protection Program
- Radiation protection control activities were observed routinely to verify that these activities were in conformance with the facility policies and procedures, and in compliance with regulatory requirements.
The inspectors also reviewed selected radiation work permits to verify that controls were adequate.
Security Control
- The performance of various shifts of the security force was observed in the conduct of daily activities, which included:
protected and vital area access controls; searching of personnel, packages, and vehicles; badge issuance and retrieval; escorting of visitors; patrols; and compensatory posts.
In addition, the. inspector observed the operational status of:
closed circuit television monitors and the intrusion detection system in the central and secondary alarm stations; protected area lighting; protected and vital area barrier integrity; and the security organization interface with operations and maintenance.
Fire Protection
- Fire protection activities, staffing, and equipment were observed to verify that fire brigade staffing was appropriate, and that fire -alarms, extinguishing equipment, actuating controls, fire fighting equipment, emergency equipment, and fire barriers were operable.
The inspectors found plant housekeeping and safety.-
related component material condition to be good.
. The
licensee's adherence to radiological controls, security controls, fire protection requirements, and TS requirements in these areas was satisfactory.
c..
Review of Nonconformance Reports Adverse Condition Reports (ACRs) were reviewed to verify the following:
TS were complied with, corrective actions and generic items were identified, and items were reported as required by 10 CFR 50.72 and
CFR 50.73.
Surveillance Observation (61726)
Surveillance tests were observed to verify that:
approved procedures were being used; qualified personnel were conducting the tests; tests were adequate to verify equipment operability; calibrated equipment was utilized; and TS requirements were followed.
The following tests were observed and/or data reviewed:
OST-1013 MST-I0006 1A-SA Emergency Diesel Generator Operability Test Containment Pressure (P-0953)
Calibration MST-I0237 Containment Pressure (P-0951)
Operational Test MST-I0475 Diesel Generator 1A-SA Starting Air Pressure Calibration The performance of these procedures was found to be satisfactory with proper use of calibrated test equipment, necessary communications established, notification/authorization of control room personnel, and knowledgeable personnel having performed the tasks.
No violations or deviations were identified.
Maintenance Observation (62703)
The inspector observed/reviewed maintenance activities to verify that correct equipment clearances were in effect; work requests and fire prevention work permits, as required, were issued and being followed; and TS requirements were being followed.
'E Maintenance was observed and work packages were reviewed for
the following maintenance activities:
,Troubleshoot pressure transmitter RT-953 in accordance with procedure MST-I0006, Containment Pressure (P-0953)
Calibration.
~
Replace and adjust
"A" emergency diesel generator governor in accordance with procedures MPT-M0015, Emergency Diesel Generator Governor Oil Change, and MPT-M0041, Emergency Diesel Generator Governor Drive Inspection.
Post maintenance testing in accordance with procedures OST-1013, Emergency Diesel Generator Operability Test, OST-1823, Emergency Diesel Generator 18 Month Operability Test, and OPT-1511, Emergency Diesel Generator Overspeed Trip Test.
~
Replace Potter-Brumfield relay in the "A" emergency diesel generator speed control circuit.
~
Repair/calibrate the rod control pulse to analog converter in accordance with procedure PIC-I441, Rod Bank Position Pulse-To-Analog Converter.
Oil addition to the turbine driven AFW pump.
The performance of work was generally satisfactory with proper documentation of removed components and independent verification of the reinstallation.
Following the replacement of an AFW turbine driven oil cooler blind flange, the AFW turbine was restarted and the lube oil reservoir refilled.
During the review of the work package, observation of the AFW oil level, and review of the AFW turbine technical manual, the inspector found several deficiencies.
The corrective action section of the work request stated that the turbine was started and oil was added as needed to establish the proper level.
The work request directed the craft to refill the lube oil reservoir in accordance with the directions provided in the technical manual.
The Terry Corporation Technical Manual, Lubrication Section, stated that the system be filled with oil when the unit was shutdown and that the oil be at ambient temperature when filling. Further, the manual stated that the oil level should be maintained between the two sight glass marks.
The inspector noted that the AFW oil level was approximately one inch above the upper scribe mark on the turbine bearing sight glass and notified maintenance personnel.
The oil reservoir was subsequently drained to the proper level.
The inspector concluded that the technical manual was not followed by the maintenance staff as instructed by the. work
request.
NRC Information Notice 81-24, Auxiliary Feed Pump Turbine Bearing Failures, addressed events during which pump bearings were damaged due to the failure to maintain the oil level within a narrow operating range of approximately 1/4 inch.
In response to the oil level problem, the
~
manufacturer (in a letter dated October 12, 1981) stated that if the oil level is maintained properly no problems would be encountered and recommended an upper oil level limit of 3/8 inch above the original low level mark.
This letter also detailed the proper shutdown fillingprocedure.
These documents had been incorporated into the technical manual by the licensee.
The manufacturer also sent an attachment to detail the proper marking of the oil reservoir sight glasses to specify minimum and maximum oil level.
The marking of the sight glasses was implemented by Field Change Request FCR-M-1167 in August 1984.
Although the manufacturer detailed the process for making permanent labeling, the FCR specified that scribe marks be placed on the sight glasses.
In 1986, the sight glass at the pump coupling was damaged and replaced, but was not remarked for proper oil level.
The failure to properly implement the manufacturer's recommendations contributed to the overfilling of the lube oil reservoir.
Because the oil reservoir level sight glasses were not adequately marked as recommended by Information Notice 81-24, and because the maintenance staff did not follow the technical manual instructions for filling the reservoir, the AFW turbine lube oil system was overfilled.
This condition could have caused bearing damage as referenced by NRC Information Notice 81-24 and the manufacturers instructions.
The failure to properly fillthe AFW lube oil reservoir is therefore considered to be a weakness.
In addition, the manufacturer's technical manual
'pecifically prohibits the use of rubber gaskets in the lube oil system.
The inspector noted a rubber gasket installed in a flange connection just downstream of the oil cooler outlet.
Licensee personnel were informed of this finding and a work request was initiated to replace the gasket with one suitable for this application.
It was found that the vendor manual recommended a 14-16 pounds per square inch gage (psig) setting for the lube oil relief valve which is used to maintain proper lube oil pressure to the bearings and governor when the turbine is at rated speed.
Operating Procedure OP-137, Auxiliary Feedwater System, listed the normal lube oil operating pressure range as 10-17 psig.
Operators were not required to record the AFW turbine lube oil'pressure during pump operation.
Since the relief valve was not included in the preventive maintenance calibration program, the inspector
considered a check of lube oil pressure while the pump was running to be appropriate.
Following discussions with licensee personnel, proper oil pressure
.was recorded during the next pump operation.
The manufacturer's technical manual listed various preventative maintenance items.
It was noted that some of these items were not included or performed in the licensee's preventive maintenance program.
This item was discussed with licensee technical support personnel who stated that, these items had been previously identified during the licensee's technical manual review.
As part of this effort, the licensee has completed a review of approximately 200 of the 350 safety-related technical manuals since January 1992, and discrepancies have been formally documented and resolved.
Maintenance feedback reports had been generated to pick up the missed items.
No violations or deviations were identified.
Design Changes and Modifications (37828)
Installation of new or modified systems were reviewed to verify that the changes were approved in accordance with 10 CFR 50.59, that the changes were performed in accordance with technically adequate and approved procedures, that subsequent testing and test results met acceptance criteria or deviations were resolved in an acceptable manner, and that appropriate drawings and facility procedures were revised as necessary.
This review included selected observations of modifications and/or testing in progress.
Temporary modification PCR-6373, AFN Turbine Driven Oil Cooler Blind Flange, was reviewed.
This short term repair, which substituted a flange made from carbon steel in lieu of the original stainless steel design material, was considered to be acceptable since the carbon steel was compatible with the oil environment and the pressure rating was similar.
No violations or deviations were identified.
Licensee Action on Previously Identified Inspection Findings (92702 R 92701)
(Closed) Violation 400/92-04-02:
Failure to use a qualified person for the performance of independent verifications.
The inspector reviewed and verified completion of the corrective actions listed in the licensee's response letter dated May 12, 1992.
Proper valve positions were verified and technical support personnel were promptly notified not to perform independent verifications.
Appropriate administrative controls have been implemente Exit Interview (30703)
The inspectors met with licensee representatives (denoted in paragraph 1) at the conclusion of the inspection on June 19, 1992.
During this meeting, the inspectors described the areas inspected and the associated findings.
The licensee representatives acknowledged the inspector's comments and did not identify as proprietary any of the materials provided to or reviewed by the inspectors during this inspection.
Dissenting comments were not received from 'the license '