ML20154J629
| ML20154J629 | |
| Person / Time | |
|---|---|
| Site: | Wolf Creek  |
| Issue date: | 12/31/1985 |
| From: | Koester G KANSAS GAS & ELECTRIC CO. |
| To: | Martin R, Minogue R NRC OFFICE OF INSPECTION & ENFORCEMENT (IE REGION IV), NRC OFFICE OF NUCLEAR REGULATORY RESEARCH (RES) |
| References | |
| KMLNRC-85-035, KMLNRC-85-35, NUDOCS 8603100684 | |
| Download: ML20154J629 (12) | |
Text
WOIE CREEK GENERATING SIATICH DOCKET NO: 50-482 FACILITY OPERATING LICENSE: NPF-42 JM10AL CEERIEDE REEUU Report No:
1 Report Period: Mardt 11,1985 to nu wnhar 31, 1985 Suhaitted by:
Kansas Gas & Electric Ccmpany 8603100684 051231 PDR ADOCK 05000402 R
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//
ANNUAL OPERATING REPORT This report is being subnitted in accordance with the requirenents of Technical Specification 6.9.1.4 and contains the information required by Technical Specification 6.9.1.5.
We format of this report is similar to that provided in Regulatory Position C l.b. of Regulatory Guide 1.16, Revision 4, August 1975.
Also included in this report is the information required by 10CFR 20.407. This reporting period includes the time between March 11,1985 (receipt of facility operating license) through Decanber 31, 1985.
1.
SUPNARY OF OPERATING EXPERIENCE Facility operating license NPF-32 was issued to Wolf Creek Generating Station on March 11, 1985, authorizing fuel load and plant testing up to five percent of full power. The unit achieved initial driticality on May 22, 1985. Facility license NPF-42 was issued on June 4, 1985, authorizing further testing and full power operation. The unit was initially synchronized to the grid on June 12, 1985. We Power Ascension Testing Program was completed and the unit was declared to be available for connercial service on September 3, 1985.
A sumnary of the major safety related maintenance activities during this reporting period is provided below. This information has previously been subnitted in the Monthly Operating Reports for the months of March through Decenber,1985.
March - Replacenent of the mechanical seal on centrifugal charging pm p
'A',
installation of the upper internals, positioning of the reactor vessel head and tensioning the studs, and installation of the Control Rod Drive Mechanism ductwork, cables and electrical connections. Several valves required repair due to body-to-bonnet leaks, valve operator problens, and valves leaking through.
April - Rework of the Power Operated Relief Valves to increase the clearances between the plugs and the cages and the replacenent of the inboard oil seal of a centrifugal charging punp. Work was performed on the Dnergency Diesel Generators including the performance of web deflection tests and inspection of the pillow block bearirgs.
May - Encapsulation of twenty w il Handcock root isolation valves off the steam generators. Wese valves had body-to-bmnet leaks and packing leaks. Two feedwater valves required repair involving welding and machining in steam cut areas. One of the Main Steamline Isolation valves required replacenent of a solenoid valve and a hydraulic pmp. The shroud welds on the generator portion of the Dnergency Diesel Generators were inspected due to a concern for a possible generic problen. Some undercutting was discovered on one weld and was repaired.
June - Work on the Main Steamline Isolation Valves and replacetent of sane of the associated 4-way solenoid valves to resolve problens.
Work was performed on several miscellaneous valves and flanges to eliminate leakage.
July - Conrtruction of a test bench for tasting th2 4-way valves on the Main Steam Isolation Valves and Feedwater Isolation Valves, and the repair of oil leaks. Other activities included adjusting the pressure equalizing valve on the contalment access hatch, repair of the jacket water heaters on the standby mergency diesel generators, and repair of hinge pin leakage on a Main Feedwater check valve.
August - Rebuild of Centrifugal Charging Pump "A" to replace a damaged shaft, repair of a pin hole leak in the flange material of an RTD bypass flow orifice manifold, replac ment of unqualified terminal blocks on the Main Feedwater Isolation Valves and the Main Steamline Isolation Valves, and change out of the position indicator switches on the pressurizer safety valves.
September - Rebuild and reinstallation of the relief valve for the positive displacement ptmip. We application of a freeze seal in the line the relief valve is mounted on was required to accm plish this work.
October - Reassably and testing of the Positive Displacment Charging Pmp. We pmp exhibited signs of excessive leakage, and further repairs were completed.
Novmber - Replacmient of a Reactor Coolant System flow transmitter, M-PP-434; restoration of the Diesel Fire Pump to service and rmoval of the temporary fire pmps; and rework of contalment mini-purge system valves on the supply and exhaust duct to resolve leakage problems.
Deceber - Performance of semi-annual maintenance of the reactor trip breakers and the smi-annual oil change on Centriftgal diarging Pmp "A".
In addition, oil leakage on both Centrifugal Charging Pumps "A" and "B" was corrected.
2.
SUPNARY OF OUTAGES AND FORCED POWER REDUCTIONS Provided below is a stmmary of the outages and significant load reductionc which occurred between June 12, 1985, (initial electricity date) and Deceber 31, 1985. During the period of June 12, 1985, through Septaber 3,1985 (consercial operation date), the unit operated for significant periods of time at reduced power levels in support of the Power Ascension Testing Program. Details of load reductions during this time period were provided in the Cycle 1 Startup Report. The majority of infomation has previously been submitted in the Monthly Operating Reports for June through December, 1985. References to previously submitted Licensee Event Reports are included in parenthesis where applicable.
1.
Outage Start Date: 06/12/85 cmpletion Date: 06/13/85 Type:
Forced Duration:
6.5 hours5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br /> Reason:
Investigated probl es with turbine load limiting circuitry.
2.
Outage Start Date: 06/13/85 Cmpletion Date: 06/13/85 Type: Forced Duration:
0.6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> Reason:
Further investigation of turbine load limiting circuitry.
Page 2 of 10
s 3.
Outage Start Date: 06/13/85 Completion Date: 06/14/85 Type: Forced Duration: 26.7 hours8.101852e-5 days <br />0.00194 hours <br />1.157407e-5 weeks <br />2.6635e-6 months <br /> Reason: Unit taken off-line due to turbine vibration. A reactor trip due to a Main Feedwater Pep trip occurred during this outage. Subsequent investigations and monitoring of the Main Feedwater Pmp failed to identify the cause of the pm p trip. (Licensee Event Report 85-041-00).
4.
Outage Start Date: 06/14/85 Capletion Date: 06/14/85 Type: Forced Duration:
7.0 hours0 days <br />0 hours <br />0 weeks <br />0 months <br /> Reason: Turbine trip due to insufficient reactor power to support turbine loading. The nuclear instr mentation channels were adjusted conservatively high leadina to an erroneously high indication of reactor power. The nuclear instrmentation was subsequently calibrated at the 30 percent power testing plateau.
(Licensee Event Report 85-044-00).
5.
Outage St et Date: 06/17/85 Completion Date: 06/17/85 Type: Scheduled Duration:
1.7 hours8.101852e-5 days <br />0.00194 hours <br />1.157407e-5 weeks <br />2.6635e-6 months <br /> Reason: Manual turbine trip per Power Ascension 'Ibsting Program.
6.
Outage Start Date: 06/23/85 Cmpletion Date: 06/25/85 Type: Forced Duration: 39.0 hours0 days <br />0 hours <br />0 weeks <br />0 months <br /> Reason: Reactor tripped due to the inadvertent opening of the reactor trip breakers during surveillance testing.
(Licensee Event Report 85-045-00). A second reactor trip occurred during this outage due to feedwater check valve leakage. An allowable leak rate was determined and a progr a was developed to monitor this leakage. The operating procedure was revised to prevent recurrence of this situation.
(Licensee Event Report 85-046-00).
7.
Outage Start Date: 06/29/85 Completion Date: 07/05/85 Type: Scheduled Duration: 144.1 hours1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> Reason: Manually tripped the reactor per Power Ascension Testing Progra. This test was utilized to d eonstrate the operability of the Auxiliary Shutdown Panel.
Page 3 of to
8.
Outage Start Date: 07/09/85 Completion Date: 07/13/85 Type: Forced Duration: 90.9 hours1.041667e-4 days <br />0.0025 hours <br />1.488095e-5 weeks <br />3.4245e-6 months <br /> Reason: Reactor trip due to feedwater control problen during Startup Test Program transient testing. A test recorder induced a false feedwater control signal. (Licensee Event Report 85-049-01). Two subsequent reactor trips occurred during this shutdown. On July 11, 1985, while reactor power was being manually reduced, an intermediate range high flux reactor trip occurred. The intermediate range high flux trip setpoint had been set at 15.5 percent reactor power to provide significant conservatism during the early phases of power ascension testing. This setpoint was adjusted to approximately 20 percent power (allowable setpoint is 25 percent power). During this event, problans with feedwater control were experienced, and plant operating procedures were revised and the feedwater control system was fine-tuned prior to unit restart. On July 10, 1985, a reactor trip occurred due to low-low Stean Generator level. Subsequent investigation revealed that the Main Feedwater Control Valve positioner for "B" Steam Generator was maintaining the valve approximately 25 percent open while the valve should have been closed. This allowed "B" Steam Generator to reach the high level setpoint, resulting in a Feedwater Isolation. Subsequently the low-low level setpoint was reached in Steam Generator "C" before reactor power could be reduced to be consistent with auxiliary feedwater flow, resulting in the reactor trip. The positioner for the "B" Main Feedwater Control Valve was recalibrated and verified to be functioning properly prior to unit restart.
(Licensee Event Reports 85-042-00 and 85-050-00).
9.
Outage Start Date: 07/15/85 Con.pletion Date: 07/16/85 Type: Scheduled Duration:
11.3 hours3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br /> Reason: Reactor trip to test negative rate trip circuitry and analyze plant performance per the Power Ascension Testing Program.
- 10. Outage Start Date: 07/23/85 Completion Date: 07/23/85 Type:
Forced Duration:
10.8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> Reason: Reactor tripped due to instrument power supply failure resulting in a loss of control power to a Main Fealwater Punp. 'Ihe cause of the event was failure of a wire supplying power to a 120 volt instrunent AC distribution panel. The wire failure was attributed to a faulty crimped connection which was repaired.
(Licensee Event Report 85-054-00).
Page 4 of to
- 11. Outage Start Date: 07/31/85 Completion Date: 08/01/85 Type: Forced Duration: 38.3 hours3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br /> Reason: Reactor tripped due to a failure of a power range nuclear instrmentation channel while a second channel was under test. The failure of the nuclear instr mentation channel was a result of internal arcing in its power supply. The power supply was replaced and the original returned to the vendor for evaluation.
(Licensee Event Report 85-058-00).
- 12. Outage Start Date: 08/07/85 Capletion Date: 08/07/85 Type: Forced Duration:
15.6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> Reason: Unit trip occurred due to Hi-HI level in Moisture Separator Reheater drain tank.
It was concluded that the drain tank level controller had malfunctioned leading to the high level condition without indication in the control Room.
Adjustznents were made to the controller and the unit returned to power operation.
(Licensee Event Report 85-060-00).
- 13. Load Reduction Start Date: 08/12/85 Completion Date: 03/21/85 Type: Forced Duration: 218.5 hours5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br /> Reason: While at full power, high vibration on Main Feedwater Pump "B" developed. A load reduction to approximately 60 percent power was comenced to allow the pmp to be secured. We pep was repaired and returned to service on August 20.
- 14. Outage Start Date: 08/28/85 Completion Date: 09/03/85 Type: Scheduled Duration 140.0 hours0 days <br />0 hours <br />0 weeks <br />0 months <br /> Reason: Unit was manually tripped from 100 percent power as the final test in the Power Ascension 'Nsting Progre. One Reactor trip occurred during this outage. While starting up the unit, the use of unpreheated feedwater, amplifying the " shrink" and " swell" characteristics of the Stem Generators, ultimately led to a low-low water level in the Stem Generator. Procedures were revised to provide an alternate method of feedwater preheating.
(Licensee Event Report 85-064-00). At the conclusion of this outage, the unit was declared available for comercial operation.
- 15. Load Reduction Start Date: 09/03/85 Capletion Date: 09/03/85 Type: Forced Duration: 20.1 hours1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> Reason: Unit was maintained at approximately 30 percent power due to Stem Generator chmistry being out of specification.
We rate of Steam Generator Blowdown was increased, arv3 power ascension was res med at approximately 2120 CDT.
Page 5 of 10
- 16. Outage Start Date: 09/05/85 Cmpletion Date: 09/05/85 Type: Forced Duration: 12.1 hours1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> Reason: Unit tripped due to low Electro-Hydraulic Control systm fluid pressure as a result of a faulty relief valve and drifting pressure switch settings. The relief valve was rebuilt and pressure switches were recalibrated. The periodic recalibration of these pressure switches was added to the preventative maintenance program.
(Licensee Event Report 85-065-00).
- 17. Outage Start Date: 09/23/85 Cmpletion Date: 09/23/85 Type: Forced Duration:
16.9 hours1.041667e-4 days <br />0.0025 hours <br />1.488095e-5 weeks <br />3.4245e-6 months <br /> Reason: Reactor tripped due to Lo-Lo Steam Generator level resulting fra a failure of a controller card for the Main Feedwater Control Valve for that Steam Generator. The controller card was replaced and functionally tested satisfactorily and the unit was returned to power operation.
(Licensee Event Report 85-067-00)
- 18. Load Reduction Start Date: 09/27/85 Cmpletion Date 09/27/85 Type:
Forced Duration:
10.0 hours0 days <br />0 hours <br />0 weeks <br />0 months <br /> Reason: While at full power, an auto Turbine runback on.ur: ed due to high water t m perature in the stator cooling syst m.
Generator output stabilized at approximately 20 percent load. The cause of the high tmperature was the failure of a controller for the tm perature control valve. Once repairs were emplete, the unit returned to full power operation.
- 19. Outage Start Date: 10/07/85 Completion Date: 10/10/85 Type: Forced Duration: 60.0 hours0 days <br />0 hours <br />0 weeks <br />0 months <br /> Reason: Reactor was manually tripped due to reduced circulating water flow caused by a buildup of plant material on the circulating water traveling screens. Several individual screen assablies buckled and one traveling screen assmbly collapsed. The screens (except the one which collapsed) were repaired and returned to service shortly after the event. The unit returned to power operation on October 9 at a reduced reactor power (approximately 90 percent) since repairs to the collapsed screen prevented operation of one of the circulating water pm ps. Methods of controlling suinerged plant growth are being evaluated.
(Licensee Event Report 85-069-00).
Page 6 of 10
- 20. Outage Start Date:
10/10/85 Capletion Date: 10/10/85 Type: Forced Duration: 19.0 hours0 days <br />0 hours <br />0 weeks <br />0 months <br /> Reason: Reactor tripped due to Steam Cenerator level swings while increasing unit power. This event was a result of allowing insufficient time for Steam Generator level stabilization between adjustments of the Feedwater Control Valves. The controlling procedure was revised to preclude recurrence.
(Licensee Event Report 85-072-00). Power was limited to approximately 90 percent until October 26, when repairs to the collapsed circulating water screen were empleted.
- 21. Load Reduction Start Date:
12/04/85 Cmpletion Date:
12/05/85 Type: Forced Duration: 28.0 hours0 days <br />0 hours <br />0 weeks <br />0 months <br /> Reason:
Power reduction due to Axial Flux Difference drif ting outside the target band as a result of imovable Control Rods. The Rod Control Systm malfunction was due to two defective chips on a supervisory buffer mmory card in the rod control logic cabinet. The card was replaced, and the Control Rods returned to operable status on Decenber 4.
The unit r eained at a reduced power level until Dec eber 5 due to Axial Flux Difference cumulative penalty deviation time.
(Licensee Event Report 85-079-00).
Page 7 of 10
'3.
EXPOSURE INF0FMATION A.
NUMBER OF PERSONNEL AfD MAN-REM BY WORK AND JOB l' UNCTION REPORT - 1985 lNUMBEROFPERSONNEL(>100mrom)l MTAL MAN-REM WORK & JOB FUNCTION UTILITY STATION CONTRACT UTILITY STATION COffrRACT
-_p_____________...
_____...-_.p.____...______________
REACTOR OPERATIONS & SURVEILEANCE MAItfrENANCE & CONSTRUCTION l
0 0
0 l
0.000
.178
.055 OPERATIONS 0
0 0
0.000
.164
.025 HEALTH PHYSICS & LAB l
0 4
8 l
0.000 1.015 2.622 SUPERVISORY & OETICE STAFF 0
0 0
.005
.066
.019 ENGINEERING STAFF l
0 0
0 l
.003
.046
.079 ROUTINE PLAbfr MAltfrENANCE l
l MAINTENANCE & CONSTRUCTION 0
0 0
0.000
.472
.567 OPERATIONS l
0 0
0 l
0.000
.056 0.000 HEALTH PHYSICS & LAB 0
0 0
0.000
.217
.398 SUPERVISORY & OETICE STAFF l
0 0
0 l
0.000
.070
.077 ENGINEERING STAFF 0
0 0
0.000
.091
.058
____________________p.____________________________.p______________
INSERVICE INSPECTION MAI!frENANCE & CONSTRUCTION l
0 0
0 l
0.000
.118
.190 OPERATIONS 0
0 0
0.000
.011
.005 HEALTH PHYSICS & IAB l
0 0
0 l
0.000 0.000
.011 SUPERVISORY & OFFICE STAFF 0
0 0
.005
.079
.050 ENGINEERING STAFF l
0 0
0 l
.003
.038
.005
_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ =
SPECIAL PLANT MAItrPENANCE l
l MAItfrENANCE & CONSTRUCTION O
0 0
0.000
.081
.059 OPERATIONS l
0 0
0 l
0.000
.007 0.000 HEALTH PHYSICS & LAB 0
0 0
0.000
.048
.093 SUPERVISORY & OETICE STAFF l
0 0
0 l
0.000
.007
.006 ENGINEERING STAFF 0
0 0
0.000
.005 0.000
______________._____________l WASTE PROCESSING MAItfrENANCE & CONSTRUCTION l
0 0
0 l
0.000
.017
.022 OPERATIONS 0
0 0
0.000
.004 0.000 HEALTH PHYSICS & IAB l
0 0
0 l
0.000
.025
.019 SUPERVISORY & OETICE STAFF 0
0 0
0.000 0.000 0.000 ENGINEERING STAFF l
0 0
0 l
0.000 0.000 0.000 REFUELItG l
l MAINTENANCE & CONSTRUCTION 0
0 0
0.000 0.000 0.000 OPERATIONS l
0 0
0 l
0.000 0.000 0.000 HEALTH PHYSICS & IAB 0
0 0
0.000 0.000 0.000 SUPERVISORY & OFFICE STAET l
0 0
0 l
0.000 0.000 0.000 ENGINEERING STAET 0
0 0
0.000 0.000 0.000
_______...________________..__p_____________________...______p________.._____________
wrALS MAItfrENANCE & CONSTRUCTION l
0 0
5 l
0.000
.868
.892 OPERATIONS 0
1 0
0.000
.242
.030 HEALTH PHYSICS & [AB l
0 4
10 l
0.000 1.305 3.143 SUPERVISORY & OETICE STAET 0
0 1
.011
.221
.153
.00 2.8M 4.3@
GRAND TOTALS 0
5 16 l
l
1 B.
PERSONNEL MONITORING REPORT 1.
In 1985, 1574 individuals were provided personnel monitoring devices. This information is provided in accordance with paragraph (a) (2) of 10CFR 20.407. 'Ihis total includes the ntaber of individuals required to be reported under paragraph (a)(1) of this section.
2.
Below is a statistical st unary report of the personnel monitoring information recorded for individuals for whan personnel monitoring was provided in 1985 in accordance with the requirements of 10CFR 20.407(b).
z Number of Estimated whole body exposure range individuals in (rems) each range No measurable exposure............................................
1404 Measurable exposure less than 0.1.................................. 155 0.1 to 0.25......................................................... 11 0.25 to 0.5.......................................................... 4 0.5 to 0.75..........................................................
0 0.75 to 1............................................................
0 1 to 2...............................................................
0 2 to 3...............................................................
0 3 to 4............................................................... 0 4 to 5...............................................................
0 5to6...............................................................0 6 to 7............................................................... 0 7 to 8............................................................... 0 8 to 9............................................................... 0 9 to 10..............................................................
0 10 to 11.............................................................
0 11 to 12.............................................................
0 12+..................................................................
0
C.
SOURCE OF DATA The information provided in Section 3.A is based on estimated exposures obtained from Pocket Ionization Chamber readings. The information provided in Section 3.B.2 is obtained fran Thermal Ltuninescent Dosimeter (TLD) readings which is the official record of exposures. There is a discrepancy in the total number of personnel having received greater than 100 mran exposure during 1985 in the two sections. This discrepancy resulted from the two different sources of exposure information utilizal to determine the totals.
4.
INDICATIONS OF FAILED FUEL During 1985, there were no indications of failed fuel. No examinations of irradiated fuel have been performed.
5.
CHALLENGES TO THE PORV'S AND SAFETY VALVFE On April 28, 1985, a Safety Injection and Main Steam Isolation occurred. The initiating signal was low steanline pressure on Steam Generator "D".
At the time of the event, the reactor was in Mode 3, Hot Standby, prior to initial criticality. Testing of the Main Stean Isolation Valves (MSIV's) was in progress, and all four MSIV's were closed. The M3IV bypass valves had just been reopened when an operator initiated reopening one MSIV. The Safety Injection and Main Steam Isolation occurred shortly thereafter due to low steamline pressure.
Subsequent investigations concluded that the MSIV had been opened prior to the equalization of pressure through the MSIV bypasses. The rate of the resultant decrease in steamline pressure (10-15 psig) was sufficient to reach the low steanline pressuto setpoint due to the rate sensitive nature of the circuitry.
Duriw; this event, approximately 2000 gallons of water were injected into the Reactor Coolant Systen and primary pressure increased to approximately 2340 psig. One Centrifugal Charging Pump was secured during this event to limit this pressure increase. Nevertheless, the pressure reached the setpoint of the Power Operated Relief Valves (PORV) and both PORV's did lift.
This event is also discussed in Licensee Event Report 85-021-00.
KANSAS GAS AND ELECTRIC COMPANY THE ELECT 54C COMPANv
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February 28, 1986 Mr. R. D. Martin, Regional Adninistrator U.S. Nuclear Regulatory Conmission Region IV 611 Ryan Plaza Drive, Suite 1000 Arlington, Texas 76011 Mr. R. B. Minogue, Director Office of Nuclear Regulatory Research U.S. Nuclear Regulatory Conmission Washington, D.C.
20555 KMLNRC 86-035 Re:
Docket No. STN 50-482 Subj: Annual Operating Report for Wolf Creek Generating Station Gentlanon:
The attached Annual Operating Report is being subnitted pursuant to Wolf Creek Concrating Station Technical Specifications 6.9.1.4 and 6.9.1.5.
This report covers operations for the period of March 11, 1985, to Deconher 31, 1985.
Yours very truly, Glenn L. Koester Vice Prealdent - Nuclear GLK:see Erriosure xc: P0'Connor (2), w/a JCtmnins, w/a f
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l 201 N. Market - WicMa, Kansas - Mail Addres s PO. Don 208 I Wochots. Kansas 67201 - Telephone Area Code (316) 261645 t