IR 05000285/1982032
| ML20028G294 | |
| Person / Time | |
|---|---|
| Site: | Fort Calhoun  |
| Issue date: | 01/18/1983 |
| From: | Johnson W, Yandell L NRC OFFICE OF INSPECTION & ENFORCEMENT (IE REGION IV) |
| To: | |
| Shared Package | |
| ML20028G281 | List: |
| References | |
| RTR-NUREG-0737, RTR-NUREG-737, TASK-2.B.1, TASK-2.B.3, TASK-2.B.4, TASK-2.E.1.2, TASK-2.F.1, TASK-TM 50-285-82-32, NUDOCS 8302070600 | |
| Download: ML20028G294 (8) | |
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APPENDIX U. S. NUCLEAR REGULATORY C0 m!SSION
REGION IV
Report: 50-285/82-32 License:
DPR-40 Docket:
50-285 Licensee: Omaha Public Power District l
1623 Harney Street Omaha, Nebraska 68102 Facility Name: Fcrt Calhoun Station Inspection A!.:
Fort Calhoun Station, Blair, Nebraska Inspection Conducted:
December 1-31, 1982 Inspector:
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E. A. Yandell,' Senior Resident Reactor Inspector 1)l<?/93 Approved:
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Ddte D. J.
son, Chief, Reactor Project Section C
Inspection Summary, i
Inspection conducted December 1-31, 1982 (Report 50-285/82-32)
Areas Inspected:
Routine, announced inspection of plant conditions during long term shutdown, surveillance testir.g, maintenance, followup on previously identi-fled items, followup on NUREG 0737 (TMI) items, and plant status. The inspec-tion involved 97 inspector-hours onsite by one NRC inspector.
Results: Within the six areas inspected, no violations or deviations were identiTied.
I 8302070600 030120 gDRADOCK 05000285 PDR
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-2-DETAILS 1.
Persons Contacted G. R. Peterson, Supervisor, Maintenance
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L. T. Kusek, Supervisor, Operations R. J. Mueller, I&C Engineer
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T. L. Patterson, Licensing Administrator K. A. Miller, Test Engineer K. C. Hyde, Test Engineer C. W. Norris, Senior Engineer, Nuclear & Chemical - Technical Services J. M. Mattice, Plant Health Physicist
- W. G. Gates, Manager, Fort Calhoun Station l
- Denotes attendance at the exit interview.
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The NRC inspector also talked with, and interviewed, other licensee employees during the inspection. These employees included licensed and unlicensed operators, craftsmen, engineers, and office personnel.
i 2.
Operational Safety Verification The NRC inspector performed activities as described below to ascertain that the facility is being maintained in conformance with regulatory re-quirements and that the licensee's management control system is effectively discharging its responsibilities for continued safe shutdown.
a.
The NRC inspector made several control room observations to verify proper shif t manning, operator adherance to approved procedures, and adherance to selected Technical Specifications specific to the shut-down condition. Selected logs, records, recorder traces, annunciators, panel indications, and switch positions were reviewed to verify com-pliance with regulatory requirements.
Radiation controlled area access points were observed at various times to verify that they were being maintained in accordance with approved procedures. The licenwe's equipment control was reviewed for proper implementation by reviewing the maintenance order and tag-out logs, and by verifying selected safety related tag-outs. The NRC inspector observed several shift
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turnovers and attended a number of the outage planning meetings.
b.
The NRC inspector verified operability of the shutdown cooling system by performing a walkdown and switch verification of the accessible portions of the system in accordance with Checklist SC-1-CL-A.
c.
The NRC inspector toured the plant at various times to assess plant and equipment conditions. The following items were observed during these tours:
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general plant conditions
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vital area barriers not degraded or appropriately manned by
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security personnel adherance to requirements of radiation work permits (RWPs)
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proper use of protective clothing and respirators
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plant housekeeping and cleanliness practices including fire
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hazards and the control of combustible material
the presence of fire watches when required
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work activities being performed in accordance with approved
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l activities physical security
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HP instrumentation is operable and calibrated
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i d.
The NRC inspector observed operator actions and recording of data during Containment Purge CP 82059.
The discharge permit was reviewed for completeness at the completion of the purge.
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No violations or deviations were identified.
3.
Surveillance Testing The NRC inspector witnessed portions of the following surveillance test activities:
a.
Auxiliary Feedwater FW-10 Steam Supply Line Check (Monthly) ST-FW-1, F.3 b.
Control Room Ventilation Filter Circuit Operation (Monthly) ST-CRV-1, F.1 c.
Ventilating Air Valves Inservice Testing (Quarterly) ST-ISI-VA-1, F.1 d.
Area Monitor.s (Monthly) ST-RM-1, F.2 e.
Pressurizer Pressure Low Signal (Monthly) ST-ESF-1, F.2 f.
Auto Initiation of Auxiliary Feedwater (Monthly) ST-FW-3, F.2 g.
Main Steam Safety Valve Test (Refueling) ST-MSSV-1, F.1
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Containment Local Leak Detection Tests, Type B - Electrical Penetra-tions (Refueling) ST-CONT-2, F.5 L
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Shutdown Margin Verification (Daily) ST-SDM-1, F.1 In the above surveillance tests, the NRC inspector verified, where appli-cable, that:
testing was scheduled in accordance with Technical Specification
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requirements procedures were being followed
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i calibrated test equipment was being used
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qualified personnel were performing the tests
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limiting conditions for operation were being met
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test data were being accurately recorded
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No violations or deviations were identified.
4.
Maintenance The NRC inspector witnessed portions of the work performed on the following
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maintenance items:
a.
Maintenance Order (MO) 17408, "AC-3B Inboard Seal Leaks." The inspec-tor verified that the M0 was signed off properly before work began.and that a Welding / Cutting Permit (FC-18) was provided. This work was performed under Tagout 82-846 and the NRC inspector verified that the tags were pro.nerly hung. Maintenance Procedure MP-AC-3, " Inspection and Overhaul of Component Cooling Water Pump," was at the job site and being utilized, and both QC and HP hold points were observed.
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b.
Detign Change Order 82-40/ Work Order No. 2883, "VA-66 Chronic Flow Problems." The NRC inspector verified that this work package included a Safety Evaluation (FC-154), an approved ALARA Review Checklist (FC-379), a specific RWP for this job, and an approved Procedure MR FC-81-159, " Procedure for Installation of VA-18 Baffles and VA-40 Pi tch Adjustment." The NRC inspector observed work in progress and noted that craf tsmen were dressed out in accordance with the RWP requirements, that procedure steps were being followed, and that current drawings were available at the job site.
c.
At various times during a two week interval the NRC inspector observed work with the incore detectors in the spent fuel pool. The licensee
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-5-was cutting up the old detectors into 5-to-7 inch segments to eliminate interference with the fuel racks in preparation for the 10 year inservice inspection.
It was noted that Special Procedure SP-IC-11,
" Disposal of Irradiated Incore Detectors," had been reviewed and approved for this job, that full-time HP coverage was provided, and that qualified personnel performed the work.
d.
Refueling outage work. The NRC inspector observed portions of the control element drive mechanism uncoupling as done in accordance with MP-RC-10-6, "CEDM Uncoupling Procedure." An inspection was made of
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Steam Generator B after the.manways were removed for inspection and eddy current testing. Several tours were made of the containment to observe work being performed, proper marking of HP barriers, and adequate HP coverage where required. The NRC inspector also observed part of the eddy current testing of the S/G tabes being performed by a sub-contractor using Surveillance Test ST-ISI-RC-2, " Steam Generator Tubes In-Service Testing," and contractor Procedure No. 42-EC-63.
No violations or deviations were identified.
5.
Followup on Previously Identified Items a.
Violation 8102-01. The licensee had failed to provide a summary of
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the safety evaluation done on each test and experiment not described in the safety analysis report as required by Section (2)(b) of 10 CFR 50.59. The NRC inspector verifed that the licensee's monthly reports now contain both a description and a safety evaluation of the applicable tests and experiments as required. This item is closed.
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b.
Violation 8102-06. The licensee had failed to maintain records which i
provided documentation that licensed operators were made cognizant of procedure changes, facility design changes, and facility license changes. A system has been implemented which documents for each li-censed person the date on which that person reviewed a procedure change, a facility design change, or a facility license change. This item is closed.
c.
Violation 8130-01. The licensee failed to assign fire protection respon-sibilities to management personnel. Standing Order G-28, " Station Fire Protection Plan," has been revised to include the fire protection pro-
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gram responsibilities of the Assistant General Manager - Production Operations, Division Manager - Production Operations, and Section Mana-
ger - Operations. This item is closed.
d.
Violation 8130-02. The licensee failed to have a program which assured identification and control of CQE material from warehouse issuance to installation.
Cognizant personnel have been reinstructed on the impor-
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tance of proper requisitioning, issuance and control of CQE material.
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In addition, Standing Order G-22, " Storage of Critical Element and
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brating Equipment," has been revised to implement a tagging program for all CQE materials.
This item is clcsed.
e.
Violation 8130-05. The licensee's Safety Audit and Review Committee (SARC) failed to review safety evaluations to numerous significant procedure changes made during the period 1979-1981. The SARC was
expanded temporarily to eliminate the backlog of safety evaluations requiring review. The licensee has revised SARC Procedure No. 2 to
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formalize the criteria for Plant Review Committee screening of safety evaluations requiring SARC review. This revision has reduced the number of safety evaluations actually requiring SARC review and should avoid any large backlog developing. This item is closed.
f.
Violation 8130-06. This violation consisted of 11 examples of the licensee's failure to follow procedures. Nine of these items were addressed by an OPPD letter of November 30, 1981, and closed by IE Inspection Report 81-30. The remaining three items included (1) the lifting of leads to disable nuisance alarms not being done in full
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compliance with Standing Order 0-2, " Electrical Jumper Control,"
(2) surveillance test procedures not being reviewed biannually by
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Quality Control (QC) personnel as required by Standing Order G-26,
" Maintenance Quality Control Program," and (3) combustible material being found inside and adjacent to the CQE storage area in violation
of Standing Order G-22.
The licensee has implemented Standing Order 0-40, " Annunciator Status Changes," to handle disabling annunciators due to maintenance or operating problems.
Station QC personnel have reviewed all surveillance procedures, and Standing Order G-26 has been revised to clarify that only changes and additions to surveil-lance test procedures need to be reviewed by QC personnel. With regard to the third item, the NRC inspector has verified that the combustible material has been moved and properly segregated from the CQE storage area. With the resolution of these final three examples, this entire item is closed.
g.
Violation 8134-01. The licensee failed to issue a status report of outstanding design changes at the required intervals as called for in i
Standing Order G-21, " Station Modification Control." A complete Modification Status Report was issued at the end of the year, and the licensee has continued to issue updated editions at the specified frequency.
This item is closed, h.
Violation 8202-02. The licensee failed to observe the requirements of ort Calhoun Training Manual for fire brigade training and certifi-l the c cation of fire brigade team members.
During the first quarter of 1982, all Fort Calhoun Station fire brigade members participated in a fire drill and associated training as required by the Training Manual.
Since that time, the plant has met the quarterly fire brigade training
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-7-requirement. With regard to certification, the licensee has reviewed the records of all fire brigade team members to ensure that the appropriate training had been completed and has issued a letter of certification to each members' file documenting this training. This item is closed.
6.
Followup on NUREG 0737 (TMI) Items a.
Item II.B.1.2, " Install Reactor Coolant System Vents." The reactor coolant system and reactor vessel head high point vents system has been installed under Field Change Package FC-79-176, and verified complete by the NF.C inspector. This item is closed.
b.
Item II.B.1.3, " Reactor Coolant System Vant Procedures." The licensee has submitted the operating guidelines for this system to NRR for review.
It is anticipated that the NRC will issue an evaluation of these procedures within the next six months. This item remains open.
c.
Item II.B.3.2, " Post Accident Sampling System." The system has been installed, but a minor software problem in the microprocessors has precluded declaring the system operational. The licensee is presently trouble shooting the system and expects to have it operational no later than the end of the refueling autage. This item remains open.
d.
Item II.B.4.2, " Training for Mitigating Core Damage." The licensee has established the required training programs "on the use of installed systems to control or mitigate accidents in which the core is severely damaged." These programs are described and evaluated in the safety evaluation issued by R. A. Clark, Chief, Operating Reactors Branch 3, Division of Licensing on November 17, 1982. This item is closed, e.
Items II.E.1.2.1B and 2C, " Auxiliary Feedwater System Initiation (Safety Grade)." A safety grade auxiliary feedwater system automatic initiation and flow indication has been installed and tested under Field Change Package FC-79-181. This installation is described and evaluated in the safety evaluation issued by R. A. Clark on September 1, 1982. These items are closed.
l f.
Items II.F.1.1 through 6, " Accident Monitoring Instrumentation":
(1) The noble gas effluent monitor (RM-063) has been installed in the ventilation discharge duct under Field Change Package FC-79-190, but has not been declared operational. Monitor RM-064 has been installed to monitor potential releases of radioactivity in the event of the main steam line relief valves opening, but final checkout is not complete. This item remains open.
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(2)
Iodine / particulate sampling system (long-term) has not been installed yet. This item remains open.
(3) The containment high range monitors (RM-091 A&B) have been installed under Field Change Package FC-79-190, and verified operational with remote readouts and recorders in the control room. This item remains open pending resolution of calibration procedures as discussed in IE Report 82-26.
(4) The containment pressure indicators and recorders required by NUREG 0737 have been installed under Field Change Package FC-79-179, and verified operational.
This item is closed.
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(5) Both wide and narrow range indications of containment water level have been installed under Field Change Package FC-79-178,
and verified operational. This item is closed.
(6) The containment hydrogen monitor system has been installed, but checkout has not been completed and some containment isolation valves are inoperable at this time. This item remains open.
7.
Plant Status On the evening of December 3,1982, excessive turbine vibration caused a turbine trip / reactor trip. All reactor plant systems responded as required, and the plant was taken to hot shutdown. Examination of the turbine re-vealed that a 10-to-12 inch section of blading on the first stage of the high pressure turbine had been thrown and the journal bearings were wiped.
As a result,'the licensee has commenced the refueling outage originally scheduled to start January 3,1983.
The high pressure turbine rotor has been shipped offsite for examination and rework by the vendor. The primary plant has been cooled down and placed on shutdown cooling. The steam generators have been opened and eddy current testing of the tubes completed. At the close of this report-ing period the licensee was making preparations to conduct the containment integrated leak rate test, followed by the steam generator secondary side hydrostatic test.
8.
Exit Interview The NRC inspector met with the Fort Calhoun Station Manager on January 4, 1983, to summarize the scope and findings of the inspection.
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