ML20132C282
| ML20132C282 | |
| Person / Time | |
|---|---|
| Site: | Oconee  |
| Issue date: | 09/13/1985 |
| From: | Bryant J, Dance H, King L, Sasser M NRC OFFICE OF INSPECTION & ENFORCEMENT (IE REGION II) |
| To: | |
| Shared Package | |
| ML20132C268 | List: |
| References | |
| 50-269-85-26, 50-270-85-26, 50-287-85-26, NUDOCS 8509260522 | |
| Download: ML20132C282 (8) | |
See also: IR 05000269/1985026
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UNITED STATES
NUCLEAR REGULATORY COMMISSION
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REGION 11
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101 MARIETTA STREET, N.W.
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ATLANTA, GEORGI A 3o323
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Report I!cs:
50-269/85-26, 50-270/85-26, and 50-287/85-26
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Licenset
Duke Power Ccmpany
422 South Church Street
Charlotte, N.C.
2S242
Facility lame: Oconee Nuclear Station
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Docket Nos..
50-269, 50-270, 50-287
License Nos.: DPR-33, DPR-47, and DPR-55
Inspection' Conducted: August 13 - September 9, 1985
Inspectors:
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J.~C. Bryant
Da e Signed
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M. K. Sasser
Da e 5 gned
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9 L3 Xf
L. P. Kiny
Date S gned
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Approved by:
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H. C. Danch, Section Chief
Da e S gned
Division of Reactor. Projects
St>MMARY
Scope: This routine, announced inspection entailed 195 inspector hours on site
in the areas of operations, surveillance, maintenance, refueling activities,
followup of events, c~emistry, and station modifications.
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Results: Of the seven areas inspected, no items of noncompliance or deviations
were identified in six areas; one area of noncompliance was found in one area
(Violation:
Failure to follow procedure for E-bar determination).
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8509260522 850916
ADOCK 05000269
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REPORT DETAILS
1.
Licensee Employees
Persons Contacted
- M. S. Tuckman, Station Manager
J. N. Pope, Superintendent of Operations
- T.
Barr, Superintendent of Technical Services
T. Owen, Superintendent of Maintenance
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"R. Bond, Compliance Engineer
- T. C. Matthews, Technical Specialist
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Other licensee employees contacted included t3chnicians, operators,
mechanics, security force members, and staff engireers.
Resident Inspectors
- J.
C. Bryant
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M. K. Sasser
L. P. King
- Attended exit interview
2.
Exit Interview
The inspection scope and findings were summarized on September,1985, with
those persons indicated in paragraph 1 above. The licensee had no specific
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comment about the proposed violation.
The licensee did not identify as
proprietary any of the materials provided to or reviewed by the inspectors
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during this inspection.
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3.
Unresolved Items
Unresolved items were not identified on this inspection.
4.
Plant Operations
The inspectors reviewed plant operations throughout the reporting period to
verify conformance with regulatory requirements, Technical Specifications
(TS), and administrative controls.
Control room logs, shift turnover
records and equipment removal and restoration records were reviewed
routinely.
Interviews were conducted with plant operations, maintenance,
chemistry, health physics and performance personnel.
Activities within the control rooms were monitored on an almost daily basis.
Inspections were conducted on day and on night shifts, during week da.ys and
on weekends. Some inspections were made during shif t change in order to
evaluate shift turnover performance.
Actions observed were conducted as
required by Operations Management Procedure 2-1.
The complement of licensed
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personnel on each shif t inspected met or exceeded the requirements of TS.
Operators were responsive to plant annunciator alarms and were cognizant of
plant conditions.
Plant tours were taken throughout the reporting period on a routine basis.
The areas toured included the following:
Turbine Building
Auxiliary Building
Units.1, 2, and 3 Electrical Equipment Rooms
Units 1, 2, and 3 Cable Spreading Rooms
Station Yard Zone within the Protected Area
Unit 3 Reactor Building
During the plant tours, ongoing activities, housekeeping, security,
equipment status, and radiation control practices were observed.
Unit 1 operated at essentially full power throughout the reporting period.
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Unit 2 operated at 95% power throughout the reporting period, with power
reduced due to high water levels in
"B"
Unit 3 remained.in the End of Cycle 8 refueling outage throughout the
reporting period.
The shutdown is discussed in paragraphs 10 and 11.
No violations or deviations were identified.
5.
Surveillance Activities
The surveillance tests listed below were reviewed and/or witnessed by the
inspectors to verify procedural and performance adequacy.
The completed
tests reviewed were examined for necessary test prerequi' sites, instructions,
acceptance criteria, technical content, authorization to begin work, data
collection,
independent -verification
where
required,
handling
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deficiencies noted, and review of completed work. The tests witnessed, in
whole or-in part, were inspected to determine that approved procedures were
available, test equipment was calibrated, prerequisites were met, tests were
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conducted according to procedure, tests were acceptable and systems
restoration was completed.
Surveillances witnessed in whole or in part:
pT/1/A/600/12 Turbine Driven Emergency Feedwater pump Performance
Test Calibration Check of BWST Level Transmitt'er, Unit 3
Completed Surveillances reviewed:
WR 56842 Perform Keowee underground breaker, interlock test on ACB3
and ACB4
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WR 55012A RPS Channel on line test required by Technical
Specification (TS) 4.1-1
WR 55049A Perform RPS Channel B reactor building pressure instrument
calibration required by TS 4.1-1
WR 55009A Perform source range intermediate rance channel test
required by TS 4.1-1
WR 90607C Calibrate P-432 (Flow) gauge and foward calibrttion date
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sheets to performance
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No violations of deviations were identified.
6.
Maintenance Activities
Maintenance activities, including station design modifications, were
observed and/or reviewed during the reporting period to verify that work was
performed by qualified personnel and that approved procedures in use
adequately described work that was not within the skill of the trade.
Activities, procedures and work requests were exanired to verify proper
authorization to begin work, provisions for fire, c~ ear.liness, and exposure
control, proper return of equipment to service, and that limiting conditions
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for operation were met.
Observation of the Unit 3 outage related design
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modifications will continue into the next reporting period.
Maintenance work witnessed in whole or in part:
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WR 51800C Disassembly, Maintenance, and Reassembly of RCP 3A2
WR 24427B Troubleshoot and find cause of CT-3 transformer lockout,
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repair
Station Design Modifications reviewed or witnessed in whole or in part:
NSM 2159 Modify HPI pu .p emergency cooling water supply
NSM 1282 Hydrogen recombiner Auxiliary Building piping and hangers
NSM 2288 Automatic RPS actuation of-shunt trip on CRD circuit
breakers
NSM 2432 Replace SSF Reactor Building transmitters with environ-
mentally qualified transmitters.
NSM 2422 Replace RIA-56
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Completed maintenance work requests reviewed:
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WR 90612C Investigate and repair HVAC system due to low flow and
high discharge pressure.
WR 22S188 Repair / replace CBI DC CRD.
WR 90544C U-2 SSF - RC makeup pump L.0. temperature reaches trip set
point (180F) during performance test.
WR 20966B Repack inboard and outboard stuffing boxes on LPSW pump
No violations or deviations were identified.
7.
Unit 3 Unusual Event
At 3:40 a.m. on August 28, 1985, with Unit 3 in refueling shutdown, the unit
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startup transformer, CT-3, became deenergized when the fault pressure relay
sensed an internal transformer fault.
The startup transformer provides
offsite AC power to Unit 3 during shutdown conditions.
When CT-3
deenergized, both Keowee hydro units auto started on undervoltage to the
4160 voit main feeder buses. The Keowee units provided power to the main
feeder buses through standby transformer CT-4.
At the time of the event, .
the reactor core was defueled to the spent fuel pool (SFP). SFP cooling was
lost during the initial loss of CT-3, but was restored by Operations
personnel within 10 minutes with only a one degree temperature rise recorded
for the SFP.
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In accordance with station emergency procedures, an Unusual Event was
. declared at 4:30 a.m., based on deenergization of the main feeder buses and
auto start of the Keowee units. At 5:05 a.m., the AC power from offsite was
restored through transformer CT-5 from the 100 kV Central transmission line.
The Unusual Event was -terminated at 5:43 a.m.
following restoration of AC
power.
During the Unusual Event the licensee's staff was unable to make the
required notification to the State of South Carolina as there was no
response when called
The State officials were contacted later during
normal office hours and steps were taken to resolve.this problem for the
future.
Troubleshooting on the CT-3 transformer indicated a fault in the internal
windings.
Because of the unavailability of a spare transformer, the
licensee is continuing to evaluate the feasibility of repairing the
installed transformer or temporary replacement with transformers of a
different design.
At the end of the report period it appeared that the
maintenance efforts might have been effective in returning the transformer
to serviceability.
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At 8:55 p.m. on September 7, 1985, a mechanic collapsed from heat exhaustion
in the change room after working on a valve in containment. He had been
wearing anti C's, rain gear, and a mask. The medical emergency team was
activated and the victim treated and surveyed. After the victim was placed
in an ambulance, contamination of 220 counts per minute was discovered on
one knee. Background levels in the change room masked the contamination.
The local hospital was notified that a contaminated victim was in transport.
An Unusual Event was declared at 9:25
p.m.
in accordance with station
emergency procedures and all required notifications were made. At 9:55 p.m.
the Unusual Event was terminated. At last report the victim's condition was
s ati s f a cto ry.
8.
Unit 2 - Unusual Event
An unusual event on Unit 2 was declared at 2:02 a.m. on Reptember 4,1985
due to indicated primary system leakage into containmant of approximately
two gallons per minute (gpm). Personnel entry into containment at 4:50 a.m.
determined that the leak was into a funnel from a collection line which
received miscellaneous root valve packing leakoffs. The specific root valve
with the packing leak could not be determined at the time.
Leakage.was
determined to be 1.7 gpm.
A safety evaluation determined that contirsed
reactor operati,on for the present was justified since the root valve packing
did not constitute a strength boundary of the reactor coolant system.
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unusual event was terminated at 9:55 a.m.
First indication of the leak was at 12:15 a.m.- on September 4, when control
operators noted increases in the reactor building normal sump filling rate
and in the let down storage tank decrease rate. Reactor building radiation
instrument alarms (RIA's)
showed increasing levels of iodine and
particulutes.
Analysis of the reactor building sump showed short lived
activity and a boron concentration of 1170 ppm. At the end of the report
period, Unit 2 is operating and reactor building activity is not increasing.
A decision on a planned shutdown for repairs has not been reached.
9.
Determination of Reactor Coolant E-bar
The inspectors reviewed the licensee's procedures for. the determination of
E-bar, the average beta gamma energy per disintegration in the reactor
coolant system (RCS), which is used to determine the maximum allowable RCS
radioactivity levels per Technical Specification 3.1.4.
The Chemistry
Department performs the semi-annual determination of E-bar using procedure
CP/0/A/2005/6A.
Only those nuclides with a half life greater than 30
minutes are used in the calculation.
The referenced precedure requires
liquid and gas samples to be counted 2 to 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> after the initial RCS
sample has been collected, with a recount of the same samples 5 days later
to obtain the activities of any nuclides which did not show up on the first
count.
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The inspectors initial review of the licensee's records found the following
apparent discrepancies.
For Units 1 and 2 E-bar procedures, dated 1/4/85
and 5/21/85 respectively, the documentation did not show a 5 day sample
recount. For Unit 3, dated 6/25/85, the recount was performed 4 days after
initial sampling rather than 5 days as reauired. Also, the Unit 2 E-bar
calculation was based on the initial sample count with only a 45 minute
elapsed time.
At the inspectors request, the licensee staff further researched these
discrepancies.
For Units 1 and 2, the 5 day recount was performed but the
documentation was not retained as no new nuclides were found. The Unit 3
recount was mistakenly performed with 4 days elapsed time rather than 5 days
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as required. For the Unit 2 initial sample count, the licensee determined
that E-bar was
ncorrectly calculated. The time that the initial sample was
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collected was incorrectly entered into the computer, resulting in calcula-
tions based on 45 minutes elapsed time rather that an actual elapsed time of
3 hours3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br /> 15 minutes.
The licensee agreed to correct the Unit 2 E-bar
results.
In summary, the above discrepancies resulted from the licensee's failure to
adhere to p; ocedure requirements and, also, from improper documentation.
Failure to follow procedures is an apparent violation of Technical
Specifications and Station Directives; Violation - Failure to follow
procedures for E-bar determination (50-269,270,287/85-26-01).
10.
Unit 3 Broken Cap Screws On Reactor Coolant Pump Bearing Housing
During scheduled overhaul of a' reactor coolant pump, manufactured by
Bingham-Williamett Company, 21 of 32 cap screws in a bearing housing were
found to have the heads broken off from the shank.
The heads had
disintegrated into small pieces due to having moved around in the bearing
cavity over an extended period. The RCP had been in service about 11 years.
At Oconee, one RCP is overhauled during each refueling shutdown.
However,
the impeller is not removed during these routine overhauls and the bearing
housing cannot be seen with the impeller in place.
There had been no
increased vibration or runout detected to indicate a problem.
An evaluation by Bingham stated that the ' pump should continue to operate
satisfactorily for the life of the plant; that any further degredation would
be indicated by increased vibration and shaft runout which would occur over
a period of time; and that seal performance would not be affected rapidly.
Bingham added that any change in performance would occur over a period of
time adequate to allow a normal shut down for planned maintenance.
Unit 3 has four Bingham RCP's as has Unit 2.
Unit I has Westinghouse pumps.
The licensee is preparing an engineering evaluation to justify continued
operation of Unit 2 and startup of Unit 3.
The bearing is held in place, not only by cap screws, but also by' the
thermal barrier and is held in centered position by four radial keys.
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Vertical movement is limited in both directions. The bearing and housing
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did not rotate but there was some wear due to vibration on the housing and
the surface. of the pump stuffing box. The bearing housing was returned to
Bingham to be built up and machined slightly oversized. Duke planned to
rebore the stuffing box slightly over sized, but found that Duke was not
equipped to perform the job with the required precision.
Subsequently, a
spare stuffing box was purchased from another site and has been received on
site.
The sellers QA program has been examined by Duke.
The licensee will develop a program for examination of the remaining pumps
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during scheduled shutdowns.- Problems with the RCP have been examined by a
Regional inspector and will be reported in more detail in Report No.
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50-287/85-27.
No violations or deviations were identified.
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11. Unit 3 Fefueling Shutdown
The Unit 3 end of cycle 8 refueling outage has remained essentially on
schedule; the major problems encountered are dicussed in paragraphs 7 and
10. The reactor coolant pump problem is not expected to delay startup. The
control transfomer remain's a question.
Refueling was completed on
September 6.
The steam genefators were eddy current tested and sludge lanced during the
shutdown. In steem gaierator A, 2192 tubes were tested and 4 were plugged.
Steam generator B had 3699 tested and 10 plugged. One of the 10 was plugged
due to a bubble test performed prior to the eddy current test.
Sludge
lancing removed 84 pounds total from the 2 generators.
The licensee
estimates 90*.'of the sludge on the lower tube sheet was removed.
No violations or deviations were identified.
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