ML19345A800
| ML19345A800 | |
| Person / Time | |
|---|---|
| Site: | Oyster Creek |
| Issue date: | 11/19/1980 |
| From: | Sklar J JERSEY CENTRAL POWER & LIGHT CO. |
| To: | |
| Shared Package | |
| ML19345A798 | List: |
| References | |
| NUDOCS 8011250214 | |
| Download: ML19345A800 (9) | |
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9 CPERATICNS SC+!ARY Octcher 1980 At the beginning of the reporting period, the Oyster Creek Nuclear Generating Staticn was operating at full lead (648 MWe). Cn October 14, lead was r
- cM 84 MWe te rencvs cerdete deineralizer 45 fmu service for 13.5 hcurs for a resin cleaning operaticn. Cn Octcber 26, Icad was r
- cM to 215.We in pr=A mtion for a centrol mi withirawal sequence change ard cleaning of the EECN heat exchanger, after fouling resulting frem a severe ster:n. 2xa m' W eent return to power was a.xtert.ed to per: nit core pcwer rMistribcticn to preclude future power reduc-i~.s to correct core flux shape i s lances. Cn Oct ber 27, a direct buried cable failed, resulting in a forced shutdown of the Augmented Offgas Anilaing ard Staticn Ifeating Boiler. 211s also shut down Radwaste concentratcr c W mtiens which rely on steam frem the heating boiler. Power was restered en Cc~, ber 28.
At the erd of the repcrting period, load was again limited by condensate deineralirer differential pressure at 96.3% carsity (628.We). t w ultirate cause of the differential pressure limitaticn is the i:: ability of the w Badaste System to process concentrated ligaid waste as desigrad.
'IWo Feportable Occurrences and one Ncn-Ibutine Dwim.ntal Cperating Pepcrt were identified during Cctcber:
PC# S0-45 cccurred on Cc ber 2 when Cbre Spray System #1 was.h fmn service to repair a leak on CSS Ptr:p "C".
PC$ 80-46 cc=rred en Cc*a.ler 16 when Stanc2:y Gas Treat:nent System #2 was taken cut of service for high filter differential pressure.
NRECR$ S0-09 cccurred en Cc~ ber 26 when urr_e ally large nu: ers of crabs irpacted u;cn plant intake myr.ts resultir.g in an estirated 111 fatality rate. Ulis is an th ='ai Envircomental Em nt as defined by Technical Specificat:.cns AWiv 8, paragraph 4.5.
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OPERQTING DATA' REPORT OPERATING STATUS om o-n g
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m UNIT NAME.. 0YSTER CREEK DOCKET NUMBER.. 50-219 UTILITY DATA PREPARED BY...
J.B. SKLAR 609-693-6013 REPORTING PERIOD... October 1980 LICENSED THERMAL POWER (MWT).. 1930
. NAMEPLATE RATIN0(GROSS MWE).. 450 DESIGN ELECTRICAL RATING (NET MWE).. 650 MAXIMUM DEPENDABLE CAPACITY (GROSS MWE).. 650 MAXIMUM DEPENDABLE CAPACITY (NET MWE).. 620 IF CHANGES OCCUR IN CAPACITY RATING SINCE LAST REPCRT, GIVE REASON...
NONE POWER LEVEL TO.WHICH RESTRICTED, IF ANY(NET MWE)...
650 REASON FOR RESTRICTION, IF ANY...
CONDENSATE DEMINERALI!ER DIFFERENTIAL PRESSURE LIMITATIONS MONTH YEAR CUMULATIVE
'OURS IN PERIOD 744.0 7319.0 95183.0 H
HOURS RX CRITICAL
'744.0
~2482.4 7 t.121. 7 RX RESERVE SHUTDOWN HRS.
0.0 0.0 '
468.2 HRS. OEN ON LINE 744.0 2333.2 69688.7 UT RE!ERVE SHUTDOWN HR0 0.0 0.0 0.0 GROSS THERMAL ENERGY 1354012.3 4015633.2 117894792.5 GROSS ELEC ENERGY 448060.0' 1294690.0 4016700y.0 NET ELEC ENERGY 431387.0 1226148.0 38707161.0 UT SERVICE FACTOR 100 0 32.6 73.2-
-s UT. AVAILABILITY FACTOR
, 100.0, 32.6 73.2 UT CAPACITY FACTOR MDC 93.5 27.*
'67.1 UT CAPACITY FACTOR DER 89.2 25.8 62.6
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FORCED CUTAGE FACTOR 0.0 8.5 6.5
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THE NEXT SCHEDULED QUTAGE IS TO BEGIN ON SPRING Oc 1,981
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t AVERAGE DAILY POWER LEVEL DOCKET 3...... 50-219 UNIT..........
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41 REPORT DATE... November 17. 1980 COMPTtF3 BY...
J.S.
SKLAR 4
TELEPHONE..... 609-693-6013 MONTH October 1980*
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50-219
. UNIT SIIUIDOWNS AND PolVER REDUC 110NS DOCKETNO.
UNIT NAME UC I 1 DATE tbymirr 19. 1980 REPORT MONill rrtrJer.1980 09-69 6b13 El 3-l I'
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ee Lkensee E *,
Cause & Corrective 3 _c 8
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j15g Repo,e s Au Psevent Recurrence 8
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10:04 B
1 N/A ZZ ZZZZZ Fouling of 'IUCCW llent Excinnger l
was curtbeted by cleartian crera-
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4 F: Foeced Reason:
Method:
Eshlble G. Instsuctions i
S: Scheduled A.Ergulpment Failure (Expl In) 1 Manual for Prepsesilim of l>sta B-Maintenance of Test 2 Manual Scisen.
Entry Sheets for I.kensee C Refueling 3 Automslie Scians.
Event Repost (LER) FRe INUREG-11 Regulsiory Restilethm 4 Othes (Emplain) 0161)
E-Operatos Tisining A IJcense Ensndnethm F.Administistive 5
G-Operational Es rue (Explain)
Ezhibit 1.Some Source (9/77)
Il-Other (Explain) j, i.
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MONillLY MECilANICAL HAINTENANCE PROGRAM Job Order System Mal function Solution 4065M Fire Protection Control fitting leak Add teflon tape to all non-flare fittings.
6518M fire Protection Relief valve for 1-1.
Replace adjusting screw on valve.
Fire pump has broken stem.
I 7002M isolation Condenser Packing leak on Valve V-14-19.
Replace packing.
6920M Control Room Repair ventilation and electrical Added silicon foam.
l 6558M Drywell Purge Valve V-27-4 stuck in closed position. Move valve off seat and adjusted stroke.
j 6939M Core Spray Remove nipple on "D" core spray Replaced pump casing vent piping.
booster pump.
7006M Isolation Condenser Valve V-14-57 packing leak.
Repacked valve.
7005M Reactor Feedwater Valve V-2-10 packing leak.
Replace packing.
7015M Diesel Generator Add oil to f20.9.
345AM Old Radwaste Ventilation Ventilation duct work split near the Repaired ductwork.
1-16 exhaust fan.
i 6171M Isolation Condenser Replaced chromated water in shell side ---
of isolation condensers with i
demineralized water and morpholine.
i 6602M CRD liydraulic Filter "B" fouled.
Replace filter element.
7030M Shutdown Cooling Leak on head of "B" lleat exchanger 7031M Shutdown Cooling Leap. on head of "C" heat exchanger Tighten bolts.
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6851M Stack Gas Sample Stack Gas Sample Pump tripped.
Tighten fan to shaf t.
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7007M Feedwater Drain line from F.W. check valve Install cap on drain valve.
l V-2-73 leaks.
6954M Isolation Condenser Valve V-14-19 packing leaks.
Adjust packing.
l 7073M Core Spray Vent valve V-20-49 on pump "C" leaks.
Removed valve and plugged piping.
7109M CRD llydraulic Filters "A" and "B" are fouled.
Replace filter elements.
7105M Shutdown Cooling "A", "B",
and "C" pumps leaking.
Tighten existing plugs.
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Electrical Corrective Maintenance Summary of QA Systems - October Item
- Equipment Malfunction Corrective Action i
- 1) 2324E Core. Spray System I Circuit breaker not fully racked in Re-aligned racking guide g
20.18018.4201 l
- 2) 2321E Core Spray System I Motor connections wet Dried connections 1801.4331 (A & C Booster Pumps)
- 3) 2140E Safety 8 Relief Valve Annunciators Wiring errors Performed special procedure
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80-116 2101.4820
- 4) 2322E Reactor Bldg. Fire Protection Sys. Alarms & trouble conditions were Replaced 3 modules with j
2125.5100 present spares 7
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Instrumentation Corrective Maintenance Sunmary of QA Systems - October Item
- Equipment Mal function Corrective Action 1) 2357E Fire System - 480 Y Room Continuous Alarm Replaced a fire detection 1404.5430 sensor.
2) 3404 Standby Gas Treatment Alarm was in for high differential Evaluated alarm setpoint 1804.5100 pressure.
reset alarm to 8".
3) 3247 Shutdown Cooling Flow switch was leaking (FS-488) 0 ring seal replaced.
1902.5150 4) 3318 Control Rod Drive 42-07 N2 gage broken Calibrated gage and returned 2002.2105 Accumulator to service.
5) 3245 SRM Selector Switch liard to turn Lubricated shaf t and 2003.5100 tightened set screws.
6) 3226 SRM Channel 23 Survelliance dsicrepancy Not substantiated by 2003.5100 Instrument Department.
4 7) 3393 SRM Channel 23 Meter read 7 x 10 on 105 position Not substantiated by 2003.5100 Instrument Department.
t 8) 3380 SRM Channel 23 Period indication unstable Replaced feedback module.
2003.5100 9) 3372 SRM Recorder (RG05)
Didn't function on channel 24 Replaced switch 10510.
I 2003.5100
- 10) 3229 SRM Channel 23 Survelliance discrepancy Performed front panel 2003.5100 adjustment, g
- 11) 3364 SRM Channel 23 Period light didn't indicate Adjusted module Z18A.
2003.5100 2
- 12) 3336 IRM Channel 16 & 18 Out of calibration Not substantiated by l
2004.5100 instrument Department.
- 13) 3239 IRM Channel 15 Failed upscale (15 minutes)
Perforned megger test and 2004.5100 visually inspected connections.
Loose connection tightened.
- 14) 3240 IRM Channel 18' Spiking upscale Not substantiated by i
2004.5100 instrument Department.
- 15) 3227 Yarway Level Indication Read 10" apart Performed surveillance and 2008.5210 calibrated.
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- 16) 3338 Barton Level Indication Range not ' rge enough Added 56"-206" range 2008.5210
- 17) 3346 Feedwater Flow Indication Computer & meter in disagreement Calibrated MV panel meter.
2014.5150 (MV Meter)
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- 18) 32921 Neutron Monitoring System -
Channels 1-4 higher than 5-8 Checked calibration of 2016.5150 Flow Converter related instrumentation.
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Paga 2 Instrumentation Corrective Maintenance Summary of QA Systems - October item
- Equipment Mal function Corrective Action i
- 19) 3333 Main Steam Line Radiation Monitor #4 Alarm setpoint excessive Calibrated monitor.
2101.5315
- 20) 3248 Augmented Of f Gas Bldg. - Vent Monitor local annunciator was Replaced trl-aux unit 2401.5315 inoperative
- 21) 3367 Augmented Off Gas Monitor 0G-RI-082 Failed downstale Turned range switch to proper i
2401.5315 position.
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- 22) 3366 Augmented Off Gas Bldg. - Vent Monitor Trouble alarm won't clear Replaced particulate paper 2401.5315 onto spool.
- 23) 3302 Augmented Of f Gas B1dg. - Vent Monitor Erratic movement in monitor Perfonned complete system 2401.5315 exceeds alcrm setpoint.
calibration with manufacturer's !
field representative. Problems were eliminated.
- 24) 3374 Augmented Of f Gas Bldg. Area Radiation Spiking Tightened loose connection on 2401.5315 Honitor OG-RE135
- 25) 3243 Stack Gas Sampler - B Source check gave e low Cleaned motor and electronics -
2523.5315 reading no problem found.
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- 26) 3316 Event Recorder First bank not tracing Tightened connections on f
2528.5100 trans fonner.
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- 27) 3250 Event Recorder First bank not tracing Tightened screws on bus bar.
I 2528.5100 t
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- 28) 3328 Event Recorder left side not printing Tightened screw on bus bar.
+
2528.5100
- 29) 3398 Event Recorder left side not printing Replotted and tightened bus bar. l l 2528.5100 i.
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- 30) 3399 Drywell liydrogen Alarm Alarm would not clear Tightened a PCB connector 2529.4820 inside control box.
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- 31) 3369 Stack Base flydrogen Alann ill-lli alarm in continuously Recrimped connector on control 2529.1934 unit.
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- 32) 2230 Fire Detection System -NRW Alarm would not clear Installed 2 new fire detectors.
i 2725.5430 Note: Due to the expansion of the Fire Protection Department, few fire prevention job t
orders will appear in the instrument or electrical sunenaries.
- 33) 3355 Diesel. Generator #2 E.T.S. Switch bad Replaced switch.
3009.5350 l
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Oyster Creek Statien #1 Oceke No. 50-119 ag. RUE!. LNG IWORMATICN -
Name of Facility:
Cyster Creek Sca:icn il Seneduled date for nex refueling shutdcwn:
Novecber 28,1981 Scheduled cace for restart following refueling-Ma.y 30, 1982.
will refueling or resumation of ocera:fon :hereaf ter require a Technical Scecifica:icn change or other license amencment?
No Ta+ri m i Specification change relative to the refuelLg is anticipated.
Scheduled ca:e(s) for sucmi::Ing procosed licensing action and sucporting in fo rma:lon:
No submittals are scheduled.
imcortant licensing considerations associated wi:5 refueling, e.g., new or differen fuel design or suoplier, unreviewed design or performance analysis methods, significant changes in fuel design, new coerating procedures:
1)
General Electric fuel====mh14a= - fuel design & perfc:: nance analysis :nethods have been owwvoi by the NRC. New operatir.g procedures, if necessary, *4.11 be submittad at a later date.
2)
Docn Fuel M-wh1ies - No :najer changes have been made nce are there any a W 4 pated.
The numcer of fuel asse.eblles (a) in the core 560 (b) in :he scent fuel s:orage pool -
781 The cresen: licensed scent fuel pool storage cacacity anc' :he si:e of any increase in licensed storage capacity :Mac has been requested or is clanned, in numoer of fuel assemelles:
Present: 1,800 Planned:
2,600 The projected date of :he last refueling that can be discharged to the scent fuel pool assuming the present 1icensed cacacI:y:
tw Spri:q 1987 Outage 5740 t-yp%p
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