ML20072C163

Monthly Operating Rept for Dec 1982

ML20072C163
Person / Time
Site:	Oyster Creek
Issue date:	01/06/1983
From:	Baran R GENERAL PUBLIC UTILITIES CORP.
To:
Shared Package
ML20072C144	List: ML20072C141 ML20072C163
References
NUDOCS 8303080347
Download: ML20072C163 (15)

Text

..

MONTHLY OPERATIONS

SUMMARY

DECEMBER 1982 At the beginning of the report period, the Oyster Creek Station was operating at 290 gross MWe.

Due to the increasinp trend in Drywell unidentified leak rate, a Reactor shutdown was initiated on December 9.

After achieving a cold shutdown condition and making a Drywell entry, the source of the increased leak rate was determined to be a worn seal on "A" Reactor recirculation pump.

This seal was replaced and other unrelated required maintenance was performed as well.

On December 13, a Reactor start-up was commenced.

During the start-up, the Reactor operator withdrew CR 06-31 from position "04" to "06",

which caused a rapid power increase (Reactor period was less than 30 seconds) and resulted in a Reactor scram.

CR 06-31 had a very high rod worth (approximately 1.13%

reactivity).

On December 14, a Reactor start-up was recommenced.

The Reactor achieved criticality at 0311 and a normal Plant heat-up/ start-up continued.

At approximately 0617 on December 15, 1982, C" Feedwater Pump was placed in service.

Approximately ten minutes later, severe pipe movement was observed in the 16" condensate line connecting low pressure (LP) heater lAl to intermediate pressure (IP) heater 1A2 in the Feedpump Room.

In response to this occurrence, the operating shift tripped "C"

Feedpump and a Reactor shutdown was ccamenced.

The amplitude of pipe movement was observed to decrease, but the repetition rate remained constant at approxinately nine cycles per minute.

To further reduce pipe movement, the operator scrammed the Reactor and subsequently opened the "A"

feedwater string outlet and inlet isolation valves.

The nine cycle per minute rate was observed to stop only after opening the inlet isolation valve.

Following a manual Reactor scram, the Group Shift Supervisor (GSS) declared an

" unusual event" at 0650 and made all of the proper notifications.

The

" unusual event" was terminated at 0805.

An analysis of the event sequence indicates that the observed pipe movement resulted from water hammer in the condensate piping interconnecting the 1Al LP Heater and 1A2 IP Heater. The lAl LP Heater is located in the neck of the "A" Condenser.

The heating steam to the lAl LP Heater is provided by the 13th stage extraction and the steam unloaded by the steam seal regulator.

These steam sources heated the water in the lAl Heater and the "A" Turbine exhaust 0

hood, until the hood spragF bypass valve was opened at 175 F.

The "A" hood was at approximately 200 at the time of this event.

Because the "A"

string was isolated from the Condensate Pump and the Feedpump Minimum Flow Valve was open, the pesure in the "A" String Condensate Piping was under vacuum.

This caused bolloff of some of the heated water in the LP heater which filled piping adjacent to the heater with steam.

This resulted in a condition whereby the heater and piping system were filled with a mixture of 8303000347 830118 PDRADOCK05000g9 R

steam and water.

When the "C" Feedwater Pump was started at D517, there was increased back leakage through the "A"

String Heater Outlet Valve, "A"

Feedpump Flow Regulating Valve, ano "A" Feedpump Check Valve.

This cooled the condensate piping which in turr, caused the water hammer.

As the steam condensed in the piping, heated water moved further out from the LP heater to fill the spaces previously occupied by the steam.

This explains the sudden increase in the indicated 1A1 Heater Outlet temperature to approximately 2120 shortly after the ater hammer event started.

Procedure revisions were made to assure that the condensate piping remains pressurized during the start-up process.

Procedure changes require cracking open the "A" ano "B" String Inlet Isolation Valves to maintain the Feedwater Pump suction pressure at approximately Reactor pressure.

When Reactor pressure resches 250 psig, the Inlet Isolation Valves will be fully opened.

Maintaining feedpump suction pressure above 70 psig should prevent boiling in the condensate piping.

A complete inspection was performed on the affected section of pipe, pipe hangers, and associated equipment.

Engineering analysis for stress was also conducted.

One hanger support was damaged during the incident.

Repairs were completed prior to start-up.

After inspecting the appropriate piping, etc. and completing an analysis of this event, Plant start-up was recommenced on December 17.

While performing the required inspection and testing during the start-up process, pressure oscillation problems were experienced with the Reactor Clean-up System.

The pressure oscillations caused the Clean-up System to trip and isolate several times during the day (December 18).

Subsequently, the Clean-up System tripped on high pressure due to failure of Pressure Regulating Valve ND-ll.

While attempting to restart the system, the Reactor scrammed due to Reactor low water level.

The low water level was caused by level oscillations while attempting to refill and restart the Clean-up System.

A restart of the Reactor was commenced on December 19.

Load was increased to 310 MWe on December 20.

On December 21, 1982, prior to taking a Torus water chemistry sample, the Containment Spray System was placed in " Dynamic Test Mode" to recirculate and mix Torus water.

The operator in st+ ting up the Containment Spray System placed Containment Spray System I in Dynamic Test Mode instead of Containment Spray System II which contains the sampl}ng connection.

He then started the appropriate Containment Spray System II pump which was lined up to spray the Drywell.

The duration of the spray was approximately 30 seconds and resulted in spraying approximately 2,200 gallons of chromated water into the Drywell.

A complete evaluation of the event was performed by the combined efforts of Plant Engineering, Technical Functions and General Electric Corporation.

A series of tests and/or surveillances of equipment in the Drywell were successfully completed to demonstrate operability.

The evaluation of this event concluded that there was no reason that the Plant could not continue in operation.

In addition, maintaining an elevated temperature and a nitrogen atmosphere in the Drywell was also recommended.

Containment Spray System I was temporarily declared inoperable on December 30 due to heat exchanger high differential pressure during surveillance testing.

The system was returned to operation on Decembere 31 after opening, cleaning, and retesting the heat exchangers.

At the end of the report period, OC Station was operating at 27L MWe, For the month of December, the availability and capacity factors were 67.4% and 27%

respectively.

l l

l l

l I

l l

l l

The following events were identified as potential Reportable Occurrences:

On December 5, Dilution Pump No. 3 tripped and was not started within 15 minutes per the Tec.ce,1 cal Specifications.

On December 8, the Discharge Canal Temperature Overall System accuracy between the primary and redundant sensors was not within the limits allowed by the Technical Specifications.

On December 10, two IRM channels were out of service in the same system with the Reactor mode switch in the " Refuel" mode.

On December 16, Off-Gas Isolation Valve V-7-31 failed to close during routine surveillance testing in preparation for Plant startup.

On December 27, it was discovered that the CRD Pump Operability Test was not performed within the time allowed by the Technical Specifications.

On December 30, Containment Spray System I failed the In-Service Test when the differential pressure acceptance criteria for Heat Exchanger 1-2 was exceeded.

l i

L

UNIT SilUTDOWNS AND POWER REDUCTIONS DOCKET NO. 50-2-19 UNITNAME Ovster Creek DATE l-6-82 REPORTMONTil December 1982 COMPLETED BY R. Baran TELEPHONE 609-971-4640 "L

o2 g

c n

S _t' 8

g5g Licensee g*t Cause & Corrective No.

Date

.t gg

,, g ;

Event u3 Action to i

$3 5

ji2g Repori*

NO Psevent Recurrence S

29 12-10-82 F

243 A

1 NA ZZ ZZZZZZ Manual shutdown caused by increasing trend in Drywell unidentified leak rate due to a worn Reactor Recircula-tion Pump Seal.

30 12-21-82 F

0 H

4 NA ZZ ZZZZZZ A Reactor shutdown was commenced due to an inadvertent oartial wet down of the Drywell. The shutdown was ter-minated after a power reduction of 100 MWe over a 2.5 hour5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br /> period.

L i

I 2

3 4

F: Forced Reason:

Method:

Exhibit G-Instructions S: Scheduled A Equipment Failure (Explain)

I Manual for Preparation of Data B Maintenance or Test 2-Manual Scram.

Entry Sheets for Licensee C Refueling 3 AutomaticScrain.

Event Repor (LER) File (NUREG.

D Regularory Resisktion 4-Other (Explain) 0161)

E-Operator Training & Ucense Exandnation F-Administrative 5

Goperational Error (Explain)

Exhibit I-Same Source (9/77) llorher(Explain)

1 PACE 1

i 1

UNIT NAME: OYSTDL CREIZ

1. DOCKET: 50-219

2. REPORTING PERIOD:

12/82

3. UTILITY CONTACT: MARK J. MCFADDEN 609-971-4637

4. LICENSED THERMAL POWER (MWt):

1930

5. NAMEPLATE ILiTING (CROSSIMWe): 68745

• 0.0

6. DESICN ELECTRICAL RATINC (NET MWe): 6U0

7. l'L1XIMUM DEPENDABLE CAPACI*G' (CROSS MWe): 650

8. MAXIMUM DEPENDABLE CAPACITY (NET MWe): 620 9.

IF CII ANCES OCCUR ABOVE SINCE LAST. REPORT, CIVE REASONS:

NONE

10. POWEli LEVEL TO hTIICII RESTRICTED, IF ANY (NET MWe): 270

11. RF/ SON F0lt RESTIIICTION,.IF ANY:

7UEL DEPLETION MONTH YEAR CUMULATIVE

12. REPORT PEhlOD IIRS 744.0 8760.0 114168.0

13. IIOURS RX CRITICAL 551.9 56G6.8 85363.9

14. RX RFSERVE SIITDWN RRS 0.0 0.0 468.2

15. IIRS CENERATOR ON-LINE 501.3 5482.3 82502.8

16. UT RESEltVE SIITDWN IIRS 0.0 0.0 0.0

17. CROSS TilERM ENER (MWH) 481700.0 6787700.0 136345000.0-i

18. CROSS ELEC ENER (MWH) 135470.0 2126300.0 46042520.0

19. NET ELEC ENER (MWil) 124540.0 2002700.0 44243540.0':

0-

-l E

1

~9.y, t4 l3n Id, s

Li D

viN k$

Vl f

9b'll' d

e, J

W U

S*

e.

am h;

g c1 e.

t.

o.

es.

c:

sf N

to L1

=

b

)

.ila I!

o 5

(

f;'

li";

e.i n.

e.

e Cl C1 LS N

+

b f

N I}

M O

C CO g**

p-a ein

(;

um Im ao 6

Ik W 2:

e.,

9-hd w

c1 d

+

t.

C.

C3 CO.

CA CO I}

s-N 6#

N N

N LS C3 el Cl 13 o

e es es a

t el CN W

1. 1 is cw 6

J!

W 3

u

• g

[6 a

a b

13 ti w

s 5

o{i

=

x s

E o

+

1. d O

d o~

i.

O Q

W ra w

w U

Ca

=

['i do e

WE r.n d

d W

=<

I$

U o

o o

u n

w 4

o

/

TL 0 d

i

[)

W A

E H

U at C

f4 -

2 1

4 N

W G

EW W

r U

c W 6

0 C.

O C

C ;3 3

o W

c4 p

7J U

d W

U W

U e

d y

S 5

h fj a

03 CS t

ti N

g4 C

04 01 C3 C1 C3 C3 71 CJ J

+

IL S

M

.c

1 PACE 1

1 AVERACE DAILY POWER LEVEL NET MWe DOCKET #...... 50219 UNIT...........O.C.#1 REPORT DATE.... JANUARY 11, 1983 COMP 1 LED BY.... MARK J. MCFADDEN TELEPHONE..... 609-971-4637 MONTil: DECEMBER, 1982 DAY MW DAY MW I

269 17 0

2 264 18 0

3 264 19 0

4 261 20 206 5

259 21 257 6

255 22 219 7

257 23 269 8

228 24 259 9

212 25 260 10 0

26 257 11 0

27 257 12 0

28 254 13 0

29 253 14 0

30 252 15 0

31 231 16 0

1 c.

e a

Pega 1 of 1 December SUl4%RY OF QASL Mechanical R N CE EQUII4HT

!%IFUNCTION CDimFLnVE /CTION Emergency Service Water Pump Verify pump impeller to casing clear-Reset or verified clearance on all pumps.

Systems I and 11 ance on Emergency Service Water Pumps A, B, C end D Control Rod Drive Systems - Hydrau-Valve stem rpunded off Installed new valve stem.

Replaced handwheel.

lic Control Unit 06-19, Valve 107 Reactor Recirculation Pump "A" Seal leakage Replaced seal cartridge with rebuilt seal.

Mechanical Seal Control Rod Drive System Hydrau-Valve stem broken Replaced valve stem and handwheel.

lic Control Unit 06-27, Valve 107 Drywell Airlock Door Outside door control arm bent Fabricated and installed new control arm.

Pcgn 1 of 2-December SUP9WC( OF QASL Electrical MAIN'IENANCE EQUIIYENT MAIMINCITON CORRECTIVS ACTICN Ot? Gas Sample Pump Pump would not start Reset breaker,and unplugged non-essential loads from receptacle.

"B" Stack Gas Sample Pump Insufficient pressure Rebuild pump. Tested satisfactorily.

Refueling Platform - Trolley Aux.

DirtJ air solenoid Cleaned solenoid. Tested satisfactorily.

Hoist Reactor Building 51' Elev. Air Interlock circuitry intermittent Replaced outside door micro-switch. Tested Lock malfunction satisfactorily.

Augmented Off Gas "A" Recombiner Motor shorted Replaced stator and bearings. Tested satis-factorily.

Replaced loose wire lugs and retightened nuts.

Off Gas Sample Pump Motor Breaker tripped Tested satisfactorily.

Emergency Service Water Valve Breaker tripped Aligned close/open key lock switches to the V-3-87 proper position - both were in manual.

Fire Detection System - New Continuous falso alarm in zone 10 Adjusted sensitivity of Ion detector. Tested Rastaste satiefactorily.

"A" Electromatic Relief Valve Actuation circuit resistance too Cleaned shorting bar surface. Tested satis-high factorily.

"B" Electromatic Relief Valve Actuation circuit resistance too Cleaned shorting bar surface. Tested satis-high factorily.

Pc g 2 of 2

, December SUhtW W OF Q/GL Electrical MAINTENM'3:

EQUIPMENT

_MATRJNCTION m RRECTIVE ACTION "E" Electromatic Relief Valve Actuation circuit resistance too hicA Cleaned shorting bar surface. Tested satis-factorily.

Main Steam Isolation Valve NSO4-B Intermittent open limit switcb indica-Replaced contact sub-assembly. Tested tion satisfactorily.

Main Steam Isolation Valve NS03-B Intermittent open limit switch indica-Replaced contact sub-assembly. Tested tion satisfactorily.

"A" Recirculation Discharge Valve Failed to open fully Tightened loose wire terminal connections on open/close torque switch.

Reactor Building Air Lock Door -

Emergency release light defective Replaced 3 lights and 1 pushbutton switch.

23' NE Tested satisfactorily.

"A" Isolation Condenser Valve Conduit hanger broken Rehung conduit and tightened clamps.

V-14-31 Straightened bent rod.

I Fire Detection System - New Rad-Continuous false alarm in Zone 5 Adjusted sensitivity of Ion detector. Tested waste satisfactorily.

Off ~as Bypass Valve V-7-31 Crimp connections in terminal box Recrimped connections. Replaced one connector.

appears to be loose Tested satisfactorily.

O

Peg,1 of 3 DecembsrSUMMIN OF QASL Instrument MAIN'IENANCE EQUIPMENT MALFUNCI' ION CORREC'IIVE 1CTION New Radwaste Area Radiation Moni-High Range not indicating properly Installed new high range card and detector tors RB-RM-007 and RB-RM-009 in RB-RM-009, cleaned pins on high range card in RB-RM-007.

Tested satisfactorily.

Local Power Range Monitor Flux Indication upscale Replaced flux amplifier with operational Amplifier 04-25D spare. Tested satisfactorily.

Source Range Monitor Channel 23 Retract permit light failure Replaced 28V retract permit light. Tested satisfactorily.

Fuel Pool Gate Leak Rate Detector No indication of flow with observed Flushed rotameter. Verified operability of flow thru drain line High Flow Alarm.

Traversing In-Core Probe Machine

" Core top" light e> ming in early Cleaned indexer position switch and tightened No. 3 connections on logic boards. Operation checked satisfactorily.

Service Water Pressure Indicator Transmitter frozen, pegged upscale Thawed transmitter and calibrated satisfactorily.

In Control Room Repaired heater.

Control Rod Drive 22-31 No "45" position indication Replaced bad position indicating probe. Opera-tion tested satisfactorily.

Accoustic Valve Monitoring System Low direct current bias voltage Replaced line driver pre-amplifier. Tested Channel 28B satisfactorily.

Replaced defective detector. Tested satis-Area Radiation Monitor R014A-4 Failed downscale factcrily.

T,emperature Indicating Switches On Faulty switches Replaced two switches and calibrated.

1-3 Emergency Service Water Pump Motor

. _ _ _ _ ~ _ _ _ _. _ _ _ _ _ _. _ _ _ _ _.. _ _ _ _.. _ _

Pags'2 of 3 December SUlHARY OF QASL Instrument MAIN'JENANCE EQUIPfeTP MP.IITNCITON 00RRBCTIVE ACTION Clean-Up System Temperature Faulty thermocouple switch Replaced and calibrated Thermocouple Switch.

Indicator IJ34 Intermediate Range Monitor Failed downscale Replaced amplifier. Tested satisfactorily.

Channel 17 Control Rod Drive 30-11 No "03" position indication Replaced position indicating probe. Operation checked satisfactorily.

Main Steam Radiation Monitor Causing half scrams Installed 8 MF capacitor in base of Q28 to Channel 4 suppress spikes generated by test switch.

Tested satisfactorily.

New Radwaste Fire Protection Failed to alarm in Main Control Room Rescated alarm card in New Radwaste Annunciator Panel Panel. Tested satisfactorily.

Reactor Manual Control System Skips " insert" step Cleaned logic timer. Operation checked satisfactorily.

Drywell High Pressure Alarm Alarm comes in low Adjusted setpoint to 1.30 pounds per square inch. Tested satisfactorily.

Rod Worth Minimizer Parity error Replaced XBAAl bit amplifier. Tested satis-factorily using system diagnostics.

Isolation Condenser Temperature Illegible printout Cleaned ink wheel and calibrated.

Recorder 9

Pag 3 of 3 December SUhtWW OF QASL Instrument M11NIENANG EQUIPbENT FRIEUNCITON mRRECTIVE 1CTION Intermediate Power Range Monitor Erratic Replaced defective ARll module, installed jumper Channel 16 from Cl3 and C14 to ground to eliminate oscilla-tion in pre-amplifier. Tested satisfactorily.

Control Rod Drive 18-15 Position "10" position blinking Cleaned connector.

Indicator Total Recirculation Flow Re-Mismatch with computer Replaced Summer 1A72C with operational spare.

corder Tested satisfactorily.

t

Oystor Crcck Stat *on #1 Docket No. 50-219 REFUELING INFORMATION -

Name of Facility:

Oyster Creek Station #1 Scheduled date for next refueling shutdown:

February 12, 1983 Scheduled date for restart following refueling:

Early - 1984 refueling or resumption of operation thereaf ter require a Technical Will Specification change or other license amendment?

Technical Specification Change Request No. 96 was submitted on August 31, 1982 for incorporation of CE fuel assemblics into the Cycle 10 core.

Scheduled date(s) for submi tt ing proposed I icens ing act ion and '.upport ing in fo rma t ion :

June 1, 1983 - The final supplement to the reload analysis, delineating the specific core configuration for Cycle 10 operat ion, will he submit ted.

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 numcer of fuel assembiics (a) in the core

- 560 (b) in the spent fuel storage pool -781 I

the presec.t 1icensed 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:

1,800 Planned:

2,600 l

The projected date of the last refueling that can be discharged to the spent fuel pool assuming the present licensed capacity:

The Spring 1987 Outage.*

• NOTE: This is for a normal refueling.

Full core off-load, however, can only be accommodated through about 1983 or 1984 with 1800 licensed locations.

,