ML20138B367
| ML20138B367 | |
| Person / Time | |
|---|---|
| Site: | Oyster Creek |
| Issue date: | 09/30/1985 |
| From: | Emrich W, Fiedler P GENERAL PUBLIC UTILITIES CORP. |
| To: | NRC OFFICE OF RESOURCE MANAGEMENT (ORM) |
| References | |
| NUDOCS 8512120276 | |
| Download: ML20138B367 (8) | |
Text
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MONTHLY OpIRATING REIORT - SEPTEMBER 1985 At the beginning of the report period, Oyster Creek was operating at 640 MWe.
On September 1, Containment Spray System I was declared inoperable after linergency Service Water (ESW) pumps 52A and 52B failed their operability surveillance tests due to low discharge pressure.
A test of System II was then performed, as required by technical specifications, and ESW pump 52D failed its test, also due to low discharge pressure, making both Containment Spray Systems inoperable.
Reactor shutdown comenced as required by technical specifications.
As the shutdown was in progress, a system flow test was performed on System I in accordance with the In-Service Test (IST) procedure and the 52A and 52B pumps met the acceptance criteria for discharge pressure.
Investigation into the mtter revealed that the IST procedure was recently revised to reflect new limits, which were not reflected in the operability surveillance procedure.
System I was then declared operable and reactor shutdown was terminated.
During the month, GPU System Operations issued two (2) minimum generation orders which required load reductions to approximtely 600 MWe.
On September 6, power was reduced to 330 MWe to perform a control rod sequence change.
hhile at reduced
- power,
'B' and
'D' reactor recirculation pump Motor Generator (MG) Set brushes were replaced.
Ib110 wing completion of brush mintenance and core flux profile checks, power was increased to 630 MWe on September 9.
On September 10 at 0236 hours0.00273 days <br />0.0656 hours <br />3.902116e-4 weeks <br />8.9798e-5 months <br />, a half-scram signal was received on APBf System I flow comparator.
The hal f-scram could not be reset until recirculation flow was reduced by approximtely 2%.
It was confirmed fra recirculation flow that a flow comparator trip was not warranted.
hhen the half-scram in APBf System I flow comparator occurred, the ApRM upscale light, the inop and flow comparator lights also illuminated.
Addi tionally, the inop and comparator lights for System II illuminated.
Plant shutdown comenced at 0338 hours0.00391 days <br />0.0939 hours <br />5.588624e-4 weeks <br />1.28609e-4 months <br /> due to the initial uncertainty regarding System II response and its state of operability.
During the shutdown process, all setpoints, alarms and trip responses were verified appropriate.
It was also verified that a flow mismtch from one system will produce an inop and comparator light on the opposite system. Based on this informtion, reactor shutdown was terminated at a plant load of 530 MWe and load was increased to 625 MWe.
On September 12, following replacenent of the flow comparator, another half-scram signal was received on APRM System I.
The flow summatica modules were subsequently exchanged and to date the event has not recurred.
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MONTHLY OPIRATING REIORT - SEPTINBER 1985 On September' 26,.second stage steam reheaters were removed from service after second stage steam reheater relief valve (V-1-133) was declared inoperable.
This caused a reduction in load to approximately 610 We.
The reheaters will remain out-of-service.pending an Engineering evaluation that verifies the three (3) renaining operable valves can provide sufficient relief capacity, consistent with applicable pressure vessel code.requiranents.
A hurricane warning was issued on September 26 at 1730 hours0.02 days <br />0.481 hours <br />0.00286 weeks <br />6.58265e-4 months <br /> and an thusual Event-was declared.
On September 27, power was reduced to 190 We, thus reducing the effects of a possible generator trip. The lhttsual Event was terminated at 1428 hours0.0165 days <br />0.397 hours <br />0.00236 weeks <br />5.43354e-4 months <br />. and. power, was increased to 580 We.
On September 28, power was ' increased to '620 MWe and maintained between 620 and 625 We for the balance of the report period.
Ioad continued to be limited by second stage steam reheaters being out-of-service.
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i Monthly-Operating R:p:rt The following Licensee Event Reports were submitted during the month of September 1985:
Licensee Event Report 50-219/85-014 As a
result of preventive maintenance testing for potential hot spots on switchgear connections, infrared scanning was performed that indicated uneven heat distribution in one station transformer.
Further testing indicated that two unit substation transformers (lA2 and 182) did not have sufficient cooling oil.
Botn transformers were considered to be in a degraded mode since the transfonners may not have been able to perform their intended function during an emergency condition.
Plant shutdown was initiated and the reactor was placed in cold shutdown in accordance with Technical Specifications.
Replacement oil was procured and the required amount added.
The plant was returned to normal operation without incident.
Licensee Event Report 50-219/85-016 - During a plant shutdown on August 9, 1985, the reactor scrammed on coincident signal s of Average Power Range Monitors (APRMs) downscale and Intennediate Range Monitors (IRMs) hi-hi.
The
- ctor scramed properly, all plant systems responded as required, and
.,. ators.took actions to stabilize the reactor.
The cause of this event has been determined to be operator error by the inadvertent insertion of all eight IRMs simultaneously with the APRMs downscale.
The IRM operating procedure for plant shutdown has been revised and the IRM drive select switch will be relabeled in order to preclude a similar event in tne future.
Licensee Event Report 50-219/85-019 - A di',crepancy was identified in the established setpoints of the main steam line high flow detectors (RE-22) in a non-conservative direction.
The calculated differential pressure equivalent to the Technical Specification limit for 120% steam flow, in the main steam lines, was found to be incorrect.
The correct value was calculated, reviewed and implemented.
Previous surveillances were reviewed against the new value and are discussed in this report.
Oyster Cresk Station #1 Docket No. 50-219 REFUELING INFORMATION - September, 1985 i
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
$60
=
(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,11cersed capacity: s2,600
.TheJprojected 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 la completed, discharge capacity to the spent fuel pool will be available until 1990 refueling
-outage..
F
OPERATING DATA REPORT OPERATING STATUS 1.
DOCKET:
50-219 2.
REPORTING PERIOD:
September 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 11.
REASON FOR RESTRICTION, IF ANY: NONE MONTH YEAR CUMULATIVE 12.
REPORT PERIOD HRS 720.0 6552.0 138265.0 13.
HOURS RX CRITICAL 720.0 5420.7 91048.6 14.
RX RESERVE SHTDWN HRS 0.0 0.0 469.7 15.
HRS GENERATOR ON-LINE 720.0 5198.9 88735.6 16.
UT RESERVE SHTDWN HRS 0.0 19.6 22.3 17.
GROSS THERM ENER (MWH) 1323000 9149140 146411469 18.
GROSS ELEC ENER (MWH) 441320 3086090 49469085 19.
NET ELEC ENER (MWH) 424780 2960639 47523204 20.
UT SERVICE FACTOR 100.0 79.3 64.2 21.
UT AVAIL FACTOR 100.0 79.6 64.2 22.
UT CAP FACTOR (MDC NET) 95.2 72.9 55.4 23.
UT CAP FACTOR (DER NET) 90.8 69.5 52.9 24.
UT FORCED OUTAGE RATE 0.0 20.4 10.4 25.
FORCED OUTAGE HRS 0.0 1333.5 10284.6 26.
SHUTDOWNS SCHEDULED OVER NEXT 6 MONTHS (TYPE, DATE, DURATION):
MAINTENANCE, OCTOBER 18, 1985 - (1 Month) 27.
IF CURRENTLY SHUTDOWN ESTIMATED STARTUP TIME:
N/A
- .4
.g AVERAGE DAILY POWER LEVEL NET MWe DOCKET f........
50-219 UNIT.......... 0yster Creek fl REPORT DATE.......0CTOBER 02, 1985 COMPILED BY....... WILLIAM J. EMRICH, JR.
TELEPHONE f......
609-971-4637 MONTH' SEPTEMBER,.1985'
. DAY W
DAY MW 1..
603 16, 626 2.
605 17.
624 3.
616 18.
624 i
4.
612 19.
622 5.
608 20.
619 6.
605 21.
619 7.
366 22.
615
[
8.
409 23.
619 9.
566 24.
616 10.
599 25.
611 11.
611 26.
613 12.
618 27.
413 13.
622 28.
587 14.
627.
29.
602 15.
621 30.
601
50-219 DOCKET NO.
UNITSilUTDOWNS AND POWER REDUC 110NS UNIT NAME Oy n t-o r rvnnic DATE Sect. 1985 Sept. 1985 COMPLETED BY R.
Baran REPORT MONIff TELEPHONE 471-464n o
c Eg "g
gIj Licensee Eg, Cause & Corrective 3 g a:
Event 3,7 Eu Prevent Recurrence No.
Date
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8 40.
8/9/85 F
39.0 B
1&3 LER 85-014 ZZ ZZZZZZ Note 1: 36% power reduction LER 85-016 Sept. 7 for Rod Sequence Change Increase Rx power to 98% over next two day period.
Note 2: 60% power reduction on Sept 27 due to hurricane
" Gloria". Plant load back to normal on Sept. 28.
I 2
3 4
F: Forced Ressor.:
Method:
Exhibit G Instsuctions S: Scheduled A-Equipment Failure (Explain) l Manual for Prepasation of Data B-Maintenance of Test 2-Manual Scram.
Entry Sheets for Licensee C. Refueling 3 Automatic Scram.
Event ReporI(LFR) File (NUREG-D-Regulatory Rest:iction 4-Other (Explain) 0161)
E Operator Training a Ucense Examination F Administrative 5
G-Operational Errus (Explain)
Exhibit I Same Source (9/77) llother(Explain)
t ENuclear f a" e m ""-
Route 9 South Forked River. New Jersey 08731-0388 609 971-4000 Writer's Direct Dial Number:
October 16, 1985 Director Office of Management Information U.S. Nuclear Regulatory Comission Washington, DC 20555
Dear Sir:
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, BL An b
)
M ed15r ~
Vice President and Director Oyster Creek PBF:KB: dam (0170A)
Enctosures cc: Director (10)
Office of Inspection and Enforcement U.S. Nuclear Regulatory Comission Washington, DC 20555 Dr. Thomas E. Murley, Administrator Region I U.S. Nuclear Regulatory Comission 631 Park Avenue King of Prussia, PA 19406 Mr. Jack N. Donohew, Jr.
rb U.S. Nuclear Regulatory Comission 7920 Norfolk Avenue, Phillips Bldg.
Bethesda, MD 20014 NRC Resident Inspector Oyster Creek Nuclear Generating Station GPU Nuclear Corporation is a subsidiary of the General Pubhc Utilities Corporation
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