IR 05000416/1989029
| ML20005G184 | |
| Person / Time | |
|---|---|
| Site: | Grand Gulf  |
| Issue date: | 01/04/1990 |
| From: | Cantrell F, Christensen H, Mathis J NRC OFFICE OF INSPECTION & ENFORCEMENT (IE REGION II) |
| To: | |
| Shared Package | |
| ML20005G179 | List: |
| References | |
| 50-416-89-29, NUDOCS 9001180259 | |
| Download: ML20005G184 (8) | |
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UNITED STATES -
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NUCLEAR REGULATORY COMMIS$10N-ldl p, J '.., ' 4;S, J
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1101 MARIETTA STREET,N.W.
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Report Nof:' ' 50-416/89-29 y<
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W s Licensee:
. System Energy Resources, Inc.
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{g LPort Gibson,.MS: 39150
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uP 5 ' Docket'No.:
50-416-
' License No.:
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J Facility Name::1 Grand' Gulf, Nuclear Station
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Inspection Conducted:. November'18 - December 15, 1989 z
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inspect' ors:.
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': H. 0.1.ChristenseK,j64n16r: Resident Inspector Dat6 Signed
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J. "L. Mathis,.ResiddpVI6pector Da'te Signed INI
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'F.TS.ECantrell, Secfpff Chief Date' Signed
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, Y" SUMMARY
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-Scope:- ' The; resident -inspectors conducted a routine inspection in the
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. following areas:-
operational safety. verification; maintenance observation,
. surveillance observation, evaluation of licensee -self-a'ssessment capability, action ~-on 1 previous ~ inspection findings, and reportable occurrences.
The m.
inspectors conducted backshift' inspections on November 22 and 23,1989.
Results: WithinL the areas inspected one violation was identified for failure Lof:the plant safety review committee to-perform an adequate review of a quality
? deficiency;. report -(paragraph 6).
This violation does ' not represent a.
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programmatic problem with the PSRC review process.
In the areas of safety
verification, maintenance observations' and surveillance observations (paragraph 3,2 4f and 5), no? problems were identified.
The licensee's programs-were
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effective with respect to meeting the safety objectives in these areas.
The
. inspection of i the licensee self-assessment capability for the ' plant safety
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re' view committee indicated that the meeting discussions were in depth, detailed.
and generally address all plant safety concerns,
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9001180259 900104
PDR ADOCK 05000416 O
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m Ek REPORT DETAILS e
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Persons Contacted.
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m Lictnsee Employeesi y
- J. G. Cesare, Director, Nuclear Licensing
,W. T..'Cottle, Vice President, Nuclear Operations
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' M, L. Crawford, Manager, Nuclear Licensing
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. D.: G' Cupstid,. Manager, Plant Modifications and Construction
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- L. F. Daughtery, Compliance Supervisor
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'*J._P. Dimmette, Manager, Plant' Maintenance eb LS.LM._Feith, Director,-Quality Programs cC. R. Hutchinson,-GGNS General Manager g
F F.~K. Mangan, Director,-_ Plant Projects and Support t
R. H. McAnuity, Superintendent, Electrical.
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- A, S=.;McCurdy, Technical Asst., Plant Operations Manager L~ B.-Moulder, Operations Superintendent (
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W.LR. Patterson,: Technical Asst., General Manager
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J,.C. Roberts,-Manager,LPlant & System Engineering
.i G. Smith, Superintendent, Chemistry
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- S, F. Tanner, Manager, Quality Services L. G. Temple, Superintendent, I & C
T. G. Tinney, Superintendent, Mechanical
- F.sW. Titus, Director,_ Nuclear Plant Engineering
-*M.-J; Wright,: Manager, Plant Support LJ. W. Yelverton, Manager, Plant Operations c
- G~ Zinke, Superintendent, Plant Licensing
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Other licensee employees - contacted included technicians, operators, securityLforce members, and office personnel, c
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- Attended exit. interview'
i JDn November 30, 1989, the following NRC personnel were on site to present
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the Grand Gulf SALP:
S.;D. Ebneter., Regional Administrator, Region II (RII)
C. W. Hehl, Deputy Director, Division of Reactor Projects, RII D. M. Verre111, Branch Chief, Division of Reactor Projects, RII E. Adensam, Director, Project Directorate II-1, NRR L. Kintner, Project Manager, Project Directorate II-1, NRR
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Chairman K. Carr; L.
Norrholm, Technical Assistant; and J.L. Milhoan, Deputy Regional Administrator, RII, toured the site on December 6,1989 and met with the resident inspectors and plant management.
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Plant Status-The, unit operated _.in Mode _1, power operations,L throughout the inspection period.
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Operational. Safety (71707)
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The ~ inspectors were cognizant of the overall plant status, and of any significant. safety-matters related to plant ' operations.
Daily
- discussions were' held.with plant management and various members of the plant operating staff.. The inspectors made frequent visits to the control room.
Observations included the verification of instrument readings, setpoints ' and recordings, status of operating systems, tags andl clearances on equipment controls and switches, annunciator alarms, adherence _to climiting' conditions for operation, temporary alterations in
~ ffect,- daily -journals and data sheet entries, control-room manning, and e
access ~ controls.
Thi s inspection activity included numerous informal
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. discussions with operators and-their supervisors.
On a weekly basis selected' engineered safety feature (ESF) systems were
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confirmed operable.
The confirmation was made by verifying that
accessible valve flow path alignment was correct, power supply breaker and fuse status was correct and instrumentation was operational.
The following systems-were. verified operable:
LPCS, RCIC, SPMU, and containment vent systems.
Additionally, the inspector walked down the reactor protection system, using S0I 04-1-01-C71-1, Reactor Protection
. System. 'No deficiencies were identified.
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Generali plant tours were conducted on -a weekly basis. Portions of the-control building, turbine building, auxiliary building and outside areas were. visited. ;The observations included safety related -tagout verifications, shift turnovers, sampling programs, housekeeping and general plant conditions, the status of fire protection equipment, control ' of activities in progress, problem identification systems, and containment isolation and the readiness of the onsite emergency response n
. facilities.
The' inspectors observed health physics management involvement and
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awareness of significant plant activities, and observed plant radiation controls. Periodically the inspectors ver_ified the adequacy of physical security control.
'The inspectors reviewed safety related tagouts, 894043 (HPU 16-21) and 894034 (TBCW Pump) to ensure that the tagouts were properly prepared, and performed.
Additionally, the inspectors verified that the tagged components were in the required position.
The inspectors have noted that senior plant management makes routine tours.to the plant and the control room.
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i The' inspectors; reviewed the activities associated with the events listed c
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0n 10ecember L13, 1989 ~, at approximately 4:00 a.m.,, Claiborne County-Sheriff's. Department reported an Alert Notification System siren in alarm.
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The Claiborne County ' Civil Defense officer on ' call responded.
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spurious alarm was; verified to have terminated at approximately 4:20 a.m.
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The _ alar _m stopped without _ intervention.
After further investigation by
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the licensee, itt was determined that the siren was not part of the Grand.'
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Gulf: alert notification system but a fire department siren of Newellton,-
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Maintenance Observation (62703)
During the report ' period, the inspectors observed portions of the maintenance ' activities listed below.
The observations included a review-of -the MW0s and other related documents for -adequacy; adherence to
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procedure,. proper'_tagouts, technical specifications, quality -controls,
and; radiological' controls; observation of work ' and/or retesting;. and specified retest-requirements.
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=MWO-DESCRIPTION 000758
. Rod control information system.
112089 Calibrate' loop 1A pool exhaust fan A delta
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pressure.
1128891 Replace air regulator on instrument air.
'11300 Clean PSW side of CCW heat exchanger C.
113089 Clean / replace filter on standby diesel air dryer after filter, s
EL0091 Inspect. division 1 1A3 battery.
-W01183 Replace solenoid on valve T42F019, No violations or deviations were identified. The results of the
inspection in this areu indicate that the program was effective with respect to meeting the safety objectives.
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5, Surveillance Observation (61726)
The inspectors observed the performance of portions of the surveillances listed below.
The observation included a review of the procedures for technical adequacy, conformance to technical specifications and LCOs;
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The mechanical indicator and the indicator lights for the vent
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valve and latch indicated the inner door was closed, but the
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indicator light for the inner door indicated that the door
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remained opened.
This prevented the outer door from being
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opened electrically; however, the personnel were able to : pen the outer door manually. When the outer door was opened, the
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inner door was observed to be open about 8 inches. They entered
.the airlock and immediately closed the outer door. The ramp was
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removed and the inner door was properly closed.
The cause of this event involved a. personnel error in the failure to close the inner door after entering containment.
Procedure SOP-14, Containment Access System, requires both personnel airlock doors to be closed upon entering or exiting the containment. The licensee identified this event, Incident Report No. 1-89-387 was promptly written, the licensee evaluated
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the circumstances associated with this event and determined the
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appropriate actions to prevent reoccurrence.
This licensee identified violation is not being cited because criteria i
specified in Section V.G.1 of the NRC Enforcement policy were
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satisfied.
This item is identified as NC4 348/89-31-02,
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Failure' to maintain containment integrity via open containment air lock. The licensee is issuing an LER on this event, j
(3) Unit 2 Reactor Trip On November 18, at 4:33 p.m., Unit 2 tripped while operating at 100 percent powerc The cause of the trip was due to a malfunction in the DEH.
The malfunction resulted in an
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e(toneous eleci.rical over:psed turbine trip signal and a loss of DES powe signal. These signals called for a turbine trip which
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then caused a reactor trip. The malfunction was due to a power i
supply voltage spike that occurred in the DEH power supply
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inverter.
All plant systems functioned satisf actorily during the reactor trip and shutdown operations.
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The unit was returned to power on November 18 at 10:16 p.m. and
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reached 100 percent - power on November 20 at 5:00 a.m.
lne licensee 5.lans to issue an LER following completion of an evaluation to determine the cause of the trio.
(4) Unit 1 Uncoupled Main Turbir> Governor Valves On November 17, at approximately 10:30 p.m., a system operator
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found governor valve No. 1 on the Unit 1 main turbine uncoupled from the valve actuator.
The unit was operating at about
94 percent power.
The licensee initiated an evaluation to
determine the action required to close this valve.
Governor valves are required to be operable to meet the turbine overspeed protection requirements of TS 3.3.4.
At approximately 2:45 p.m.
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en November 18, governor valve No. I was manually closed from the j
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verification of test instrument calibration; observation of all or part
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or component; and review of the data for acceptability based upon the acceptance criteria.
06-IC-1B21-M-1003, Reactor Vessel Low /Hi Water Level (RPS) Functional Test.
06-IC-1821-M-2010, Reactor Vessci Water Level (HPCS) Functional Test -
Channel G.
06-IC-IC11-M-0003, Scram Discharge Volume High Water Level Float Switches (RPS) Channel D.
06-0P-1M71-M-0003, Post Accident Monitor, Instrument Channel Check.
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06-RE-1J31-V-0001, Power Distribution Limits Verification.
No violations or deviations were identified. The results of the inspections in this area indicate that the program was effective with respect to meeting the-safety objectives.
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Evaluation of-Licensee Self-assessment Capability (40500)
The inspector reviewed the requirements for the Plant Safety Review
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Committee (PSRC).
Additionally the inspector observed several committee meetings, reviewed selected meeting minutes, and reviewed PSRC
actions on previously identified concerns.
The PSRC meetings were well attended and they met the TS quorum requirements.
The committee meets approximately twice a week, which exceeds the TS rewirement of once per month.
The meeting discussions are in depth, detailed and generally address all plant safety concerns.
The meeting minutes documented items approved, disapproved and reasons for disapproval. ' Additionally, all PSRC action items are assigned to responsible individuals and the status is tracked.
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I The inspector reviewed Quality Deficiency Report (QDR) 237/89 to determine if the PSRC adequately reviewed the report.
The QDR documented that the analytical basis supporting the FSAR pipe break analysis for the RWC'l system was incorrect.
The analysis assumed an isolation time of 50 seconds for high room temperature and high delta flow signals.
However, the isolation time for the delta flow signal is 80 seconds and some RWCU rooms have no temperature monitoring or isolation instrumentation.
NPE performed an evaluation which identified two inconsistencies.
The first was that the RWCU isolation circuit contains no room temperature or delta temperature isolation signals for rooms normally having RWCU piping with water temperature of less than or L
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equal' to 120F (cold piping).
These isolation signals were deleted in i
_ a 1984 technical specification change.
The second inconsistency was
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that the RWCV valve nest room, 1A443, has no temperature monitoring
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instruments and that the intended temperature instruments were
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inadvertently installed in the RWCU heat exchanger room.
The valve nest room is also a evid piping area. To support the as-built configuration,
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NPE performed a new pipe break analysis using the 80 second delta flow isolation signal.
The new analysis showed that the RWCU pipe break is
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still_ bounded by the existing FSAR analytical margins.
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p The PSRC on October 26, 1989, concluded that the as-built configuration of the plant is acceptable and there is no concern for plant safety.
The inspector reviewed the QDR on November 15, 1989, and noted that the valve nest room, > which is defined in FSAR Section 6.2.1.2.2.a.6, and
Figures 6.2-62 and 6.2-63, is required to have temperature isolation
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instrumentation in accordance with TS Table 3.3.2-2.4.c.3 and d.3.
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When the discrepancy was brought to the licensee's attention, a justification for continued operation was issued on November 16, 1989.
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The JC0 states, that the RWCU valve nest room, IA443, contains only cold
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RWCU piping and this is adequately protected using the existing high
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- delta flow. instrumentation alone.
The licensee stated they plan to c
request a TS change to clarify the instrumentation requirements for the
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valve area in the heat exchanger room.
Additionally, the licensee performed a 10 CFR 50.59 evaluation which determined that tne as-built design did not constitute an unreviewed safety question.
TS 6.5.1.6.1, requires the PSRC review all recognized indications of an unanticipated deficiency in some aspect of design or operation of safety
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related structure, systems, or components.
Contrary to the above, the
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PSRC inadequately reviewed QDR 237/89, in that they failed to determine L
that instrumentation required by TS was not installed in the required location, this is violation 89-29-01.
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Reportable Occurrences (90712 & 92700)
The event reports listed below were reviewed to determine if the informa-tion provided met the NRC reporting requirements.
The determination
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included adequacy of event description and corrective action taken or planned, existence of potential generic problems and the relative safety significance of each event. Additional inplant reviews and discussions with plant personnel as appropriate were conducted for the reports indicated by an asterisk. The event reports were reviewed using the guidance of the general policy and procedure for NRC enforcement actions, regarding licensee identified violations.
(0 pen) LER 89-015, Failure to retest isolation dampers following maintenance.
This event was documented in NRC inspection report 89-28.
Corrective actions will be verified after issuance of the final LER.
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I (0 pen) LER 89-016, Lighting induced spike causes APRM scram.
This event was documented in NRC inspection report 89-29.
(Closed) LER 89-010, Reactor scram caused by lighting strike.
This LER is administrative 1y closed and the corrective actions will be tracked under LER 89-016.
No violations or deviations were identified.
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Action on Previous Inspection Findings (92701',92702)
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(Closed)'InspectorsFollowup Item 88-14-01, Corrective action to prevent l
inadvertent condensate pump trips on low suction pressure.
The licensee i
determined that low suction pressure trips for the condensate pumps were j
not required when startup suction strainers are not installed.
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Change Package 89/1086 was issued to install key operated switches in l
.the low pressure trip circuity.
This will allow disabling the circuity when the strainers are removed from the system.
This item is closed.
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(Closed) Inspector Followup Item 89-27-01, MSIV leakage control system
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walkdown discrepancies.
The noted discrepancies have been corrected.
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This item is closed,
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(Closed) ; Violation 89-14-03, Inadequate feedwater system procedure
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results in loss of feedwater control and reactor scram.
The licensee
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admitted the violation in letter dated July 13, 1989.
The following corrective actions have been completed.
The 501 was revised, the training simulator manual speed changers were modified to run back in slow speed and licensed operator retraining was completed, This item is
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closed.
t (Closed) TI 2515/104.
The resident inspectors attended selected
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licensee Fitness for Duty (FFD) training-sessions to determine whether
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required training is being conducted to implement the program.
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licensee FFD training, sessions are set up for supervisors and a joint session is set up for awareness training and escort training for
. non-supervisory personnel. The training session fulfilled the require-
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ments of 10 CFR 26. The licensee procedures had not been implemented at the time of the training sessions, however the procedures are scheduled
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to be in place by the end of the year.
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Exit Interview (30703)
The inspection scope and findings were summarized o.. December 15, 1989, with those persons indicated in paragraph I above.
The licensee did not identify as proprietary any of the materials provided to or reviewed by the inspectors during this inspection.
The licensee had no comment on the following inspection findings:
Item Number Description and Reference 89-29-01 Violation Failure of the PSRC to perform an adequate review of a QDR. (paragraph 6)
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10. -Acronyms and Initialisms APRM -
Average Power Range Monitor
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ECCS -
Emergency Core Cooling System ESF Engineering Safety Feature
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Flow Control Valve
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FFD Fitness.For Duty
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FSAR -
Final Safety Analysis Report
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I&C Instrumentation and Control
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IFI Inspector Followup Item
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JC0 Justification for Continued Operation
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LCO Limiting Condition for Operation
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LER Licensee Event Report
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LPCS -
Low Pressure Core Spray
MNCR -
Material Nonconformance Report
MSIV -
Main Steam Isolation Valve MWO Maintenance Work Order
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NPE
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-Nuclear Plant Engineering
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NRC Nuclear Regulatory Commission
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P&ID -
Piping and Instrument Diagram
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PSRC -
Plant Safety Review Committee PSW Plant Service Water
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Quality Deficiency Report
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RCIC -
Reactor Core Isolation Cooling
.RPS Reactor Protection System
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RWCU --
Reactor Water Cleanup RWP Radiation Work Permit
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SERI -
System Energy Resource Incorporation SOI System Operating Instruction
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SPMU -
Scppression Pool Makeup TS-Technical Specification
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