ML20087M498

Monthly Operating Rept for Feb 1984

ML20087M498
Person / Time
Site:	Oyster Creek
Issue date:	02/29/1984
From:	Baran R, Fiedler P GENERAL PUBLIC UTILITIES CORP.
To:	NRC OFFICE OF RESOURCE MANAGEMENT (ORM)
References
NUDOCS 8403300001
Download: ML20087M498 (8)

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MONTHLY OPERATIONS REPORT FEBRUARY 1984 Throughout the report period, the Oyster Creek Station remained shutdown for the current Refueling and Maintenance Outage. There is no fuel in the reactor.

Local Power Range Monitor (LPRM) replacement was completeo except for LPRMs 28-41 and 20-49. LPRM 28-41 is stuck in the core and crnnot be freed. A new LPRM could not be inserted in the LPRM housing 20-49.

Maintenance ano Construction and Plant Engineering have initiated an investigation to determine the cause. LPRM replacement was subsequently placed "on hold" to facilitate draining of the cavity for feedwater valve maintenance.

The plant experienced difficulty in draining the cavity due to the inability to establish a positive seal on the equipment pool blocks.

Af ter nunerous unsuccessful attempts to seal the blocks, the decision was made to remove the equipment pool blocks, place the steam separator in the vessel ano install the reactor head (ALARA considerations). The cavity and then the reactor was drained to below the feedwater sparger, at which tine, repair to feeowater isolation valve V-2-36 was started. -

In conjunction, replacement of Cleanup System valve V-16-2 started along with repairs to V-16-1. By the end of the report period, repairs to V-2-36 were completed and reactor water level was raised to just below the reactor head flange.

01 February 1,1984, diesel generator No. 2 was released for its annual inspection. At the end of the report period, the plant was preparing to perform an operability test on the diesel generator (subsequently, D.G.

No. 2 became operable on Wrch 3,1984).

Nmerous problems were encountered with air compressor No. 2. The air compressor was out of service from January 4,1984 to February 12, 1984 while waiting for special gasket material. On February 18, a recurring inter-stage relief problem was again experienced. The air compressor was returned to an operable status on February 27, 1984.

Dilution pump No. 2 overhaul was completed. However, various problems were encountered during acceptability testing. The major problem was i

identified as a failure of its drive motor (ground fault). The drive motor from No. 3 dilution purrp was installed on No. 2 purrp and tested successfully. No. 3 dilution pump has been released for its scheduled overhaul and inspection.

It was discovered that the dry tube for Intermediate Range mnitor-(IRM) 12 is crackeo. Plant Engineering, along with General Electric, is addressing the problem. The dry tube must be replaced - prior to plant I startup. An inspection of all IRM dry tubes .has been scheduled for the  !

week of March 12, 1984.

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' Monthly Operations Report Page 2

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The inspection, painting and hydro of "B" isolation condenser was completed. Work on "A" isolation condenser is presently in progress.

4 On February 26, 19 84, Standby Gas Treatment System No. 2 failed its operability test on hicp HEPA filter differential pressure. The HEPA 4

filters were replaced and a satisfactory D.O.P. test (efficiency test) was performed on February 29, 1984.

The inspection required by NRC Eblletin 84-04 (" Inspection of the Torus Vent Headers for Cracks") was satisfactorily completed.

Repairs to condensate transfer punp 1-1 were completed.

The cleaning of "C" hotwell was completed. The water in "A" and "B" hotwell has been transferred to "C" hotwell to facilitate cleaning and expansion joint replacement of A and B.

The main lube oil tank (Turbine) was refilled at the end of the report period.- Presently, the plant is in the process of cleaning the oil prior to the start of setting the turbine controls.

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The following Licensee Event Report was submitted during February 1984:

ReportaDie Occurrence No. SU-219/83-26/0lT Over the past several years the additibn of lead, for the purpose of radiation snielding, on two of three fuel pool cooling heat exchangers has created a situation where the heat exchangers' foundation bolts would be overstressed during a seismic event. In addition, wnile investigating this situation, it was discovered that the original portions of the fuel pool cooling piping system are supported only by dead weight supports and therefore, may not be a seismic Class I system as stated in the station's

" Facility Description and Safety Analysis Report" (FDSAR). Tne cause of the  ;

occurrence was attributed to lack of procedural controls in the past when  !

applying lead shielding to piping systems. Tne exact cause of the discrepancy between the FDSAR and the installation specifications could not be determined but is believed to be due to lack of control of changes during the construction phase of the plant. The following corrective actions have been initiated:

1. A decontamination effort has been completed which reduced the levels of radiation in the vicinity of the heat exchangers. All lead will be removed prior to startup. If, for ALARA reasons, lead shielding is still required, a safety evaluation will be performed before adding any shielding.

2. A walk-down of the plant will be conducted to insure tnat similar situations do not exist which might interfere witn the functioning of safety-related equipment. This will be completed prior to plant startup.

3. A seismic analysis has been conducted for the fuel pool cooling piping system in its present configuration and it was found that the original fuel pool cooling system is not seismic Class 1; however, the augmented cooling system whicn was added as part of the fuel pool expansion described in Amenament 78 to the FDSAR is a seismic Class 1 system. To satisfy original licensing criteria, changes will be'made to the return piping system to ensure a_ seismically qualified flow

. path can be established between the fuel pool and the seismically qualified portion of the cooling system. This will be accomplished prior to the next core offload. Seismic qualification will be based upon operational criteria _ consistent with ASME Section III, Division-I, Appendix F. An assessment of the entire system will then be made-to determine if further upgrading is appropriate.

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UNITS!!UTDOWNS AND POWER REDUCTIONS ETNO.  %-M UNITNAME Ovster Creek y DATE 3/5/R4 M DBY R- Ravan REPORTMONUI _ Februa rv 1984 TELEPIIONE 971-4640 n

m o E Dde o $"E };; .Y 3 Licensee E*, {*,

' No.- g Eg jg5 Cause & Corrective E

$E E j~ g g Event Report a p

mo g o

Action to Prevent Recurrence 4 , u

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-31 2-11-83 S 9192 C 1 N/A ZZ ZZZZZZ Start of the 1983 Refueling and Maintenance Outage.

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3 F: Ferced 4

Reason: Method:

.S; Sd.edeled A.Equipraent Failure (Explain)

Exhibi! G-Instrucrions t

I Manu:1 for Preparation of Data

' B-Mainterance ciTest 2-Manual Scram. EntrySheets for Licensee

C.Refucting 3-Autornatk Scram. Event Report (LER) Fite (NUREG-D-Regulatory Restriction 4-Osher (Explain) i -

E4perator Training & Ucense Examination 0161)

!' F-Administratise -

i 5 Goperatienal Error (Explain) .

II-Orher(Explain) E !dbit 1 S::ne Source

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i OPERATING DATA REPORT OPERATING STATUS ,

1. DOCKET: 50-219

2. REPORTING PERIOD: Februa ry , 1984

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 696.0 1440.0 124368.0

13. HOURS RX CRITICAL 0.0 0.0 84623.9

14. RX RESERVE SHIDWN HRS 0.0 0.0 468.2

15. HRS GENERATOR ON-LINE 0.0 0.0 82693.8

16. UT RESERVE SHTDWN HRS 0.0 0.0 0.0

17. GROSS THERM ENER (MWH) 0.0 0.0 136224729

18. GROSS ELEC ENER (MWH) 0.0 0.0 46056905

19. NET ELEC ENER (MWH) -1895 -3886 '44281797

20. UT SERVICE FACTOR -0.0 0.0 66 5

21. UT AVAIL FACTOR 0.0 0.0 66.5

22. UT CAP, FACTOR (MDC NET) 0.0 -0.4' 57.4

23. UT CAP FACTOR (DER NET). 0.0 -0.4 54.8'

24. UT FORCED OUTAGE RATE 0.0 0.0 9.7

25. ' FORCED OUTAGE HRS 0.0 0.0 8916.8

26. . SHUTDOWNS SCliEDULED OVER NEXT 5 MONTHS (TYPE, _DATE, DURATION): 'N/A

27. IF CURRENTLY SHUTDOWN ESTIMATED STARTUP TIME: 6/11/84 4

4 AVERAGE DAILY POWER LEVEL '

NET MWe l DOCKET #. . . . . . . . 50-219 UNIT.'. . . .. . . . . 0yster Creek #1

. REPORT DATE . . . . . . . MARCH 5, 1984 COMPILED BY . . . . . . . DONALD V. NOTIGAN TELEPHONE # . . . . . . 609-971-4695 MONTH FEBRUARY, 1984 DAY MW DAY MW

1. 0 16. 0

2. 0 17. 0

3. 0 18. 0

4. 0 19. 0

5. 0 20. 0

6. 0 21. 0

7. 0 22. 0

8. 0 23. 0

9. 0- 24. 0

10. O' 25. 0

11. 0- 26. 0

12. 0 27. 0

13. 0 28. 0

14. 0 29. 0 15.: 0 t

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Docket No. 50-219 REFUELING INFORMATION - February,1984 Name of Facility: Oyster Creek Station #1 Scheduled date for next refueling shutdown: Presently shutdown for Refueling Scheduled date for restcrt following refueling: June 11,1984 Will refueling or resumption of operation thereaf ter require a Technical Specification change or other license amendment?

Technical Specification Change Request No. 96 was submitted on August 31, 1982 for ' incorporation of GE assemblies into the Cycle 10 core.

Scheduled date(s) for submitting proposed licensing action and supporting - '

information:

i October 28, 1983 - The final supplement to the reload analysis, delineating the specific core configuration for Cycle 10 operation, was submitted.

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 = O' (b) in the spent fuel storage pool = - 1375 The present; licensed spent fuel pool storage capacity and the'sizeL 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.

The projected date of the last refueling' that can be discharged 'to' the 'apent -

fuel' pool. assuming 'the present licensed ' capacity:- ,

Full core offload capability will be lost af ter the 1985: outage.' Batch..

discharge capability will be lost af ter' the 1987Eoutage. l Expanded?

spent fuel pool rack capacity;(2,600)'is scheduled for -1984.;

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GPU Nuclear Corporation Nuclear  := gar 388 Forked River New Jersey 08731-0388 609 971-4000 Writer's Direct Dial Number:

March 15, 1984 Director Office of Management Infonnation U.S. Nuclear Regulatory Commission Washington, D.C. 20555

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. Michael Laggart at (609) 971-4643.

Very truly yours,

)) l W.

ter B. Fiedler 6 ce President aM Director ster Creek PBF: dam Enclosures cc: Director (10)

Office of Inspection and Enforcement U.S. Nuclear Regulatory Commission Washington, DC 20555 Dr. Thomas E. Murley, Administrator '

Region I U.S. Nucle ar Regulatory Conmission l 631 Park Avenue King of Prussia, PA 19406 NRC Resident Inspector Oyster Creek Nuclear Generating Station Forked River, NJ 08731 I

GPU Nuclear Corporation is a subsidiary of the General Public Utilities Corporation