ML20133A065
| ML20133A065 | |
| Person / Time | |
|---|---|
| Site: | Oyster Creek |
| Issue date: | 07/31/1985 |
| From: | Emrich W, Fiedler P GENERAL PUBLIC UTILITIES CORP. |
| To: | NRC OFFICE OF RESOURCE MANAGEMENT (ORM) |
| References | |
| NUDOCS 8510020124 | |
| Download: ML20133A065 (7) | |
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MON'll!!,Y 0 PIRATING rep 0RT - JULY 1985 At the beginning of the report period, Oyster Creek was operating at approximately 645 We, with load restricted by intake temperature and its effect on condenser vactnn.
On July 1, Core Spray System No. 2 snubber hanger No. 2138 was found to be cracked.
Regiirs were completed July 3,
satisfying a 72-hour Technical Specification limit.
Core Spray System No. 2 was tested and returned to service July 4.
On July 8, an automatic reactor scram occurred due to low condenser va ctn n.
'Ihe low vacuta condition was caused by a cracked casing on No.
1-1 steam jet air ejector (SJAE) drain tank pimp which resulted in excessive drain tank levels and flooding of the SJAEs.
At the time of i
the scram, No. 1-2 SJAE drain tank pump was tagged out-of-service in preparation for seal replacement.
I Following completion of repairs and survelliances, reactor startup commenced on July 9.
No. 1-1 SJAE drain tank prmp remained out of i
service pending replacement.
Reactor and generator startup was completed and power subsaluently increased to approximtely 515 We by July 10.
On July 13, power was reduced to 350 We to facilitate cleaning of No.
1-2 'nirhine niilding Closed Cooling Water (TBC00 heat exchanger, power was increased to 500 We later that day subsaluent to cicaning the heat exchanger.
On July 15, after removing Containment Spray System II from service to l
determine the cause of increased water (ESW) emergency ) service (System I bearing temperature differential pressure, ESW pump 52A increased during operation.
The ptap was considered inoperabic and in accordance with Tech Spec requirements, a reactor shutdown commenced.
Shutdown was terminated a f ter returning System II to service and verifying system operability, power was mintained at approximately 500 We with load restricted by I
high drain tank levels due to the degraded performance of No. 1-2 SJAE drain tank pimp.
Subsoluent to replacement of No.1-1 SJAE drain tank pimp, power was increased to 615 We on July 16.
On July 17, inspections of Containment Spray System II heat exchangers l
revealed pieces of black brittle m terial suspected to be interior coa ting from FSW system piping.
Upon completion of inspections and cicaning, the heat exchangers were returned to service to conduct a test run.
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50NTIILY 0 PIRATING REPORT - JIILY 1985 On July 20, Containment Spray System II was removed from service to facilitate a heat exchanger inspection subsequent to a test run wherein a high heat exchanger differential pressure condition developed.
FSI pump 52A (System I) failed its associated surveillance test due to low discharge pressure. De pump was considered inoperable and in accordance with Tech Spec requirements, reactor shutdown commenced.
On July 21, sufficient flow was verified for FSV pump 52A and shutdown was terminated with plant load at 404 We.
On July 22, due to increasing containment spray heat exchanger differential pressure, the decision was mde to proceed to cold shutdown to inspect and clean all containment spray heat exchangers, hydrolaze sections of ESW piping, flush the system and perform post-mintenance testing.
%e plant remined in cold shutdown for the balance of the report period.
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OPERATING DATA REPORT OPERATING STATUS 1.
DOCKET:
50-219 2.
REPORTING PERIOD:
July 1985 3.
UTILITY CONTACT:
JOSEPH R. MOLNAR 609-971-4699 4.
LICENSED THERMAL POWER (MWt):
1930 5.
NAMEPLATE RATING (GROSS MWe):
687.5 X 0.8 = 550 6.
DESIGN ELECTRICAL RATING (NET MWe):
650 7.
MAXIMUM DEPENDABLE CAPACITY (GROSS MWe):
650 8.
MAXIMUM DEPENDABLE CAPACITY (NET MWe):
620 9.
IF CHANGES OCCUR ABOVE SINCE LAST REPORT, GIVE REASONS:
NONE 10.
POWER LEVEL TO WHICH RESTRICTED, IF ANY (NET MWe): N/A j
11.
REASON FOR RESTRICTION, IF ANY:
NONE MONTH YEAR CUMULATIVE 12.
REPORT PERIOD llRS 744.0 5088.0 136801.0 13.
HOURS RX CRITICAL 495.3 4043.4 89671.3 l
14.
RX RESERVE SilTDWN HRS 0.0 0.0 469.7 15.
HRS GENERATOR ON-LINE 486.4 3858.9 87395.6 16.
UT RESERVE SitTDWN HRS 0.0 19.6 22.3 17.
CROSS TilERM ENER (MWil) 813200 6695140 143957469 18.
CROSS ELEC ENER (MWil) 273330 2275190 48658185 19.
NET ELEC ENER (MWH) 260541 2181479-46744044 20.
UT SERVICE FACTOR 65.4 75.8 63.9 21.
UT AVAIL FACTOR 65.4 76.2 63.9 22.
UT CAP FACTOR (MDC NET) 56.5 69.2 55.1 23.
UT CAP FACTOR (DER NET) 53.9 66.0 52.6 24.
UT FORCED OUTAGE RATE 34.6 23.9 10.4 i
25.
FORCED OUTAGE HRS 257.6 1209.5 10160.6 26.
S!!UTDOWNS SCllEDULED OVER NEXT 6 MONTilS (TYPE, DATE, DURATION):
OCTOBER 1, 1985 - (1 Month) 27.
IF CURRENTLY SHUTDOWN ESTIMATED STARTUP TIME:
N/A
AVERAGE DAILY POWER LEVEL NET MWe DOCKET f........
50-219 UNIT..
.0yster Creek #1 REPORT DATE....... AUGUST 06, 1985 COMPILED BY....... WILLIAM J. EMRICH, JR.
TELEPHONE f...... 609-971-4637 MONTH JULY, 1985 DAY MW DAY MW 1.
623 16.
549 2.
621 17.
583 3.
618 18.
597 4.
616 19.
603 5.
612 20.
604 6.
610 21.
448 7.
609 22.
264 8.
74 23.
0 9.
78 24.
0 10.
481 25.
O I
11.
474 26.
0 12.
487 27.
0 13.
412 28.
0
'14.
474 29.
0 15.
477 30.
0 31.
0
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Oyster Creek Station #1 Docket No. 50-219 REFUELING INFORMATION - July, 1985 Name of Facility:
Oyster Creek Station #1 Scheduled date for next refueling shutdown: April 12, 1986 Scheduled date for restart following refueling: October 13, 1986 Will refueling or resumption of operation thereafter require a Technical Specification change or other license amendment?
Yes Scheduled date(s) for submitting proposed licensing action and supporting information:
December, 1985 Important licensing considerations associated with refueling, e.g., new or different fuel design or supplier, unreviewed design or performance analysis methods, significant changes in fuel design, new operating procedures:
- 1. General Electric Fuel Assemblies - fuel design and performance analysis methods have been approved by the NRC.
New operating procedures, if necessary, will be submitted at a later date.
- 2. Exxon Fuel Assemblies - no major changes have been made nor are there any anticipated.
The number of fuel assemblies (a) in the core 560
=
(b) in the spent fuel storage pool = 1204 (c) in dry storage 4
=
The'present licensed spent fuel pool storage capacity.and the size of any increase in' licensed storage capacity that has been requested or is planned, in number of fuel assemblies:
Present licensed capacity:
2,600 The projected date of the last refueling that can be discharged to the spent fuel pool assuming the present licensed capacity:
Reracking of the fuel pool is'in progress. Four out of ten (10) racks have been installed to date. When reracking is completed, discharge capacity to the spent fuel' pool will be available until 1990 refueling
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Monthly Opsrating Report The following Licensee Event Reports were submitted during the. month of July 1985:
Licensee Event Report 50-219/85-012 - On June 12, 1985, a mechanical failure of the plant's Electric Pressure Regulator (EPR) resulted in a decrease in reactor pressure.
This pressure drop caused automatic closure of the Main Steam Isolation Valves, resulting in an automatic reactor scram.
Although all rods inserted to shutdown the reactor, one of tne two Scram Discharge Volumes (SDVs) did not fully isolate.
The resulting flow of hot water through the volume caused steam and paint fumes to be emitted in tne Reactor Building. This in turn caused activation of the deluge fire system on the 51' elevation of the Reactor Building.
The Isolation Condensers were not initially used for plant cooldown due to high reactor water level.
While attempting to place the Reactor Water Cleanup System in service to lower reactor water level, a cleanup system isolation valve failed to open due to its breaker tripping.
The Electromatic Relief Valves (EMVs) were used to control pressure until reactor water. level wcs reduced (by letdown via the Cleanup System) to the point wnere the Isolation Condensers could be used.
Reactor pressure was then controlled througn manual actuation of tne Isolation Condeners and pressure was reduced to less than 600 psig.
The scram signal
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was reset, and the plant was placed in the cold shutdown condition.
Repairs to the EPR, the two SOV valves, and the cleanup system valve were completed prior to plant startup following this event.
Licensee Event Report 50-219/85-013 On Saturday, June 29, 1985 at approximately 0020 hours2.314815e-4 days <br />0.00556 hours <br />3.306878e-5 weeks <br />7.61e-6 months <br />, Drywell to Torus differential pressure was found to be below the minimum value of 1.0 psid as specified in Technical Specifications.
At 1130 hours0.0131 days <br />0.314 hours <br />0.00187 weeks <br />4.29965e-4 months <br /> on June 26, 1985, the pen which records torus pressure on Control Room recorder 12XR6 was turned off.
When the pen was returned to service (at 0020 hours2.314815e-4 days <br />0.00556 hours <br />3.306878e-5 weeks <br />7.61e-6 months <br /> on June 29, 1985), the Torus to Drywell differential pressure was 0.89 psid.
Within 10 minutes after discovery, the required Torus to Drywell differential pressure was restored by purging the Torus.
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a GPU Nuclear Corporation gggf Post Office Box 388 Route 9 South Forked River.New Jersey 08731-0388 609 971-4000 Writer's Direct Dial Number:
August 14, 1985 Director Office of Management Infonnation U.S. Nuclear Regulatory Commission Washington, DC 20555
Dear Sir:
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Subject:
Oyster Creek Nuclear Generating Station Docket No. 50-219 Monthly Operating Report In accordance with the Oyster Creek Nuclear Generating Station Operating License No. DPR-16, Appendix A, Section 6.9.1.C. enclosed are two (2) copies of the Monthly Operating Data (gray book information). for the Oyster Creek Nuclear Generating Station.
If you should have any questions, please contact Mr. Drew Holland at (609) 971-4643.
Very truly yours, l
>J
. 'iedler Vice President and Director Oyster Creek PBF:KB: dam (0170A)
Enclosures l
cc: Director (10) l Office of Inspection and Enforcement U.S. Nuclear Regulatory Commission Washington, DC 20555 Dr. Thomas E. Murley, Administrator Region I l
U.S. Nuclear Regulatory Connission 631 Park Avenue King of Prussia, PA 19406 NRC Resident Inspector Oyster Creek Nuclear Generating Station I
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l GPU Nuclear Corporation is a subsidiary of the General Public Utilities Corporation
.