ML19294A435

Monthly Oper Rept for Oct 1978

ML19294A435
Person / Time
Site:	La Crosse File:Dairyland Power Cooperative icon.png
Issue date:	11/06/1978
From:	Papworth L DAIRYLAND POWER COOPERATIVE
To:
Shared Package
ML19294A433	List: ML19294A432 ML19294A435
References
NUDOCS 7811130209
Download: ML19294A435 (14)

Text

OPERATING DATA REPORT DOCKET NO.

L) ATE 11-6-78 COMPLETED BY L.G.Papworth TELEPilONE 608-689-2331 OPERATING STATUS Notes

1. Unit Name: La Crosse Boilinn Water Reactor

2. Reporting Period: _0000 78-01-10 to 2400 78-31-10 165

3. Licensed Thermal Power (MWt):

4. Nameplate Rating (Gross MWe):

65.3 50

5. Design Electrical Rating (Net MWe):

6. Maximun ependable Capacity (Gross MWe): 50

7. Maximum Dependable Capacity (Net MWe):

48

8. If Changes Occur in Capacity Ratings (Items Number 3 Through 7) Since Last Report. Gise Reasons:

NA

9. Power Lesel To which Restricted.lf Any (Net MWe):

48 Net MWe

10. Reasons For Restrictions. If Any: Self-imposed restriction due to nuclear instrumentation noise at higher power levels (voids in steam separators).

This Month Yr.-to-Date Cumulative

11. Hours in Reporting Period 745 7.296 78,891

12. Number Of liours Reactor Was Critical 411.9 4,861.1 50,039.6

13. Reactor Reserve Shutdown Hours 0

0 478

14. Hours Generator On-Line 411.8 4.413.7 45.704.0

15. Unit Resene Shutdown Hours 0

0 7S

16. Gross Thermal Energy Generated (MWH) 52.510 570,856 6,454,156

17. Gross Electrical Energy Generated (MWH) 15.434 165.531 1.958.675

18. Net Electrical Energy Generated (MWH) 14.270 152,875 1,810,455

19. Unit Service Factor 55.3 60.5 57.9

20. Unit Availability Factor 55.3 60.5 58.0

21. Unit Capacity Factor (Using MDC Net) 39.9 43.7 47.8

22. Unit Capacity Factor (Using DER Net) 38.3 41.9 45.9

23. Unit Forced Outage Rate 0.0 15.3 5.2

24. Shutdowns Scheduled Over Next 6 Months (Type, Date, and Duration of Each):

1) Fuel Shipment Shutdown, December 2, 1978 Tentative Shutdown Date, 2-Week Duration.

2) Refueling Shutdown, February 10, 1979 Tentative Shutdown Date, 8-Week Duration.

25. If Shut Down At End Of Report Period. Estimated Date of Startup:

11-07-78

26. Units in Test Status (Prior to Commercial Operation):

Forecast Achiesed INITIA L CRITICALITY INITI AL ELECTRICITY COM\\lERCI A L OPER ATION 4

<"A 7 811130M

INSTRUCTIONS FOR CONIPLETING OPERATING DAT A REPORT Thu report should be furnished each month by licensees. The name and telephone number of the preparer should be provided in the designated spaces. The instructions below are provided to assist licensees in reporting the data consistently. The number of the mstruction corresp mds to the nem number of the report format.

1. UNIT NASlE. Self-explanatory.

or of commercial operation, whichever comes last, to the end of the reriod or decommissioning, whichever comes

2. REPORTING PERIOD. Designate the month for which first. Adjustments in clock hours should be made in the data are presented.

which a change from standard to daylight. savings time (or vice versa) occurs.

3. LICENSED tiler 51AL POWER ( %IW:)is the maximum thermal power, expressed m megawatts, curiently auth.

12. NU5f BER OF IIOURS REACTOR WAS CRITICAL.

orized by the Nuclear Regulatory Commission.

Show the total number of hours the reactor was critical during the gross hours of the reporting period.

4. NAh!EPLATE RATING (GROSS AlW ).

The nameplate e

power designation of the rurbine. generator in megavoit

13. REACTOR RESERVE SilUTDOWN 110URS. The total amperes (hlVA) times the r ameplate power factor of the number of hours during the gross hours of reporting turbine generator.

period that the reactor was removed from service for administrative or other reasons but was available for

5. DESIGN ELECTRICAL RATING (NET SIW ) is the operation.

e nominal net electrical output of the unit specified by the utility and used for the purpose of plant design.

14. IIOU IS GENERATOR ON LINE.

Also called Service liours. The total number of hours expressed to the near-

6. 51AXIh!U51 DEPENDABLE CAPACITY (GROSS S!W,)

est tenth of an hour during the gross hours of the re-is the gross elcetncal output ~,ieasured at the output portmg period that the unit operated with breakers terminals of the turbine-generator during the most re-closed to the station bus. These hours, plus those !isted strictive seasonal conditions.

n Unit Shutdowns for the generator outage hours, should

7. SIAXI51Uhl DEPENDABLE CAPACITY (NET NIW

).

e hlaximum dependable capacity (gmss) less the normal

15. UNIT RESERVE SilUTDOWN 110URS. The total num-statiori service loads.

ber of hours e pressed to the nearest tenth of an hour during the gmss hours of the reporting period that the

8. c lf-explanatory.

e crat was remosed from service for economic or similar

• *""' "I**"*"

• "' P" " " '

9. POWER LEVEL TO WillCil RESTRICTED, IF ANY (NET hlW ).

Note that this item is applicable only if e

16. GROSS TilERNIAL ENERGY GENERATED (SIWII).

restrictions on the power level are in effect. Short-tenn The thermal output of the nuclear steam supply system (less than one month) limitations on power level need not be presented in this item.

during the gross hours of the reporting period, expressed ia megawatt hours (no decimals).

Since this information is used to develop figures on capa.

city lost due to restrictions and because most users of the

17. GROSS ELECTRICAL ENERGY GENERATED (htWil).

" Operating Plant Status Report" are primarily interested The electrical output of the unit measured at the output in energy actually fed to the distribution system. it is terminals of the turbine-generator during the gross hours requested that this figure be expressed in N1We-Net in of the reporting period, expressed in megawatt hours (no spite of the fact that the figure must be derived from decimals).

SlWt or percent power.

18. NET ELECTRICAL ENERGY GENERATED (SIWil).

10. REASONS FOR RESTRICTIONS. IF ANY. If item 9 The gross electrical output of the unit measured at the is used, item 10 should explam why. Bnef narrative is output termmals of the turbine-generator minus the nor-acceptable. Cite references as appropriate. Indicate mal station service loads during the gross hours of the whether restrictions are self. imposed or are regulatory reporting period, expressed in megawatt hours. Negative requirements. Be as specific as possible within space linn-quantities should not be used. If there is no net positive tations. Plants in startup and power ascension test phase value for the period, enter zero (no decimals).

should be identified here.

11. IIOURS IN REPORTING PERIOD. For units in power

19. For units still in the startup and power ascension test ascension at the end of the period, the gross hours from

23. phase. items 19 23 should not be computed. Instead, enter the beginning of the period or the first electrical produe-N/A in the current month column. These five factors tion, whichever comes last. to the end of the period.

should be computed starting at the time the unit is de-clared to be in commercial operation. The cumulative For units in commercial operation at the end of the figures m the second and third columns should be based period, the gross homs from the beginning of the period on commercial operation as a starting date.

(9/77)

DOCKET NO. 50-409 UNIT SilUTDOWNS AND POWER REDUCTIONS LACBWR UNIT NAME DATE 11-06-78 072'Bc4 /7/f' COMPLETED BY L.G.PAPWORTH REPORT MONT11 TELEPif0NE 608-689-2331

~..

Ij

}

[

Licensee

,E g L

Cause & Conective No.

Dite i

eg 4

.5

e Eve nt u?

o" Action to 3E 5

jg; Report =

nV U

Present Recurrence

.J 78-08 Continued F

NA A

4 NA CB PUMPXX INCREASED VIBRATION READINGS ON T'IE from LOWER RADIAL BEARING AND THRUST BEAR-September ING OF THE FLUID COUPLING ON FORCED 1978 CIRCULATION PUMP 1A REQUIRED CONTIN-UED REDUCED POWER 01 ERATION. REPAIRS WERE EFFECTED DURING MAINTENANCE OUT-AGE 78-14.

78-14 78-10-17 S

333.2 B,E 1

NA CB PUMPXX THE VIBRATION SYMPTOMS OF FORCED CIR-CULATION PUMP 1A RESULTED IN A SCHED-ULED MAINTENANCE OUTAGE FOR INSPEC-TION AND REPAIRS. REPAIRS INCLUDED REPLACEMENT OF THE 1A PUMP FLUID COUPLING LOWER RADIAL BEARING AND UPPER THRUST BEARING, MACHINING OF RADIAL BEARING HOUSING AND REBUILDING OF UPPER SECTION OF SHAFT SEAL.

CON-DUCT OF PRIMARY REACTOR CONTAINMENT INTEGRATED LEAKAGE TESTING (TYPE A) om OPERATOR LICENSE EXAMINATIONS WERE ALSO PERFORMED.

I 2

3 4

F: Forced Reason :

Method:

Exhibit G - Instructions S: Sched uled A-Equipment Failure (Explain) 1 -Manual for Preparation of Data B Maintenance or Test 2-Manual Scram.

Entry Sheets for Licensee C Refueling 3-Automatic Scram.

Event Report (LER) File (NURI G-D-Regulatory Restriction 4-Ot her ( Explain )

0161)

E-Operator Training & License Examination F-Admmistrative 5

G-Operational Error (Explain)

Exhibit 1 Same Source (9/77)

Il-Other ( E xplain)

UNIT SilUTDOWNS AND POWER REDUCTIONS INSTRUCTIONS This report should desenbe all plant shutdowns during the in accordanc; with the table appearmg on the report fornt report period. Iri addition, it should be the source of explan.

If category 4 must be used, supply brief comments.

ation of sienificant dips in average power levels. Each signi-ficant reduction in power level (greater than 20% reduction LICENSEE EVENT REPORT :. Reference the applicab'.

in average daily power level for the preceding 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />) rep rtable occurrence pertainmg to the outage or pow er should be noted, even though the unit may not have been red uction. Enter the first four parts (event year. sequential shut down completelyl For such reduction's in power level, rep rt number, occurrence code and report type) of the five the duration should be hsted as zero, the method of reduction part designation as desenbed in item 17 of Instructions for shou 1J be iisted as 4 (Other), and the Cause and Corrective Preparation of Data Entry Sheets for Licens e Event Report Action to Prevent Recurrence column should explain. The (LER) File (NUREG-0161). This information may not be C tuse and Corrective Action to Prevent Recurrence column i

ediately evident for all such shutdowns. of course. since should be used to provide any needed explanation to fully further tnvestigation ma> be required to ascertam whether or describe the circumstances of the outage or power reduction.

n t a reportable occurrence was invohed.) If the outage or power reduction will not result in a renortable occurrence.

NUMBER. This coiumn should indicate the sequential num, the positive indication of this lack of correlation should be ber assigned to each shutdown or significant reduction m power n ted as not applicable (N/A).

for that calendar year. When a shutdown or signifie.:nt power SYSTEM CODE. The system v which the outage or power reduction begins in one report period and eads in another.

an entry should be made for both report periods to be surc reduc tion originated sh' uld '

ated by the two digit code of o

Exhibit G. - Instructions for a reparation of Data hntry Sheets d shutdowns or significant power reductions are reported.

Until a unit has achieved its first power generation, no num-f r Licensee Event Report (LER) File (NUREG.Olnl).

ber should be assigned to each entry.

Systems that do not fit any existmg code should be designa-ted XX. The code ZZ should be used for those esents where DATE. This column should tndicate the date of the sta t a system is not applicable.

of each shutdown or significant power reduction. Re port as year. month, and da3:. August 14,1977 would be reported COMPONENT CODE. Select the most appropriate component as 770814. When a shutdown or significant power reduction from Exlubit I instructions for Preparation of Data Entrv beginsin one report period and ends in another, an entry should Sheets for Licensee Esent Report (LER) File (NURI G-0161).

be made for both report periods to be sure all shutdowns usine the followine critieria:

or significant power reductions are reported.

TYPE. Use "F" or "S" to mdicate either " Forced" or " Sche-duledf respectively, for each shutdown or significant power

11. If not a component failure, use the related component:

reduction. Forced shutdowns include those required to be e.g., wrong valve operated through error; list valve as initiated by no later than the weekend following discovery component.

of an off. normal condition. It is recognized that some judg-ment is required in categorizing shutdowns in this way. In C.

If a chain of failures occurs. the first component to mal.

genera!, a torced shutdown is one that would not bave been function should be listed. The sequence of events.includ-completed in the absence of the condition for which corrective ing the other components which fail. should be descnbed action was taken.

under the Cause and Corrective Action to Present Recur-rence column.

DURATION. Self-explanatory. When a shutdown extends beyond the end of a report period, count only the time to the Components that do not fit any existmg code should be de-signated XXXXXX. The code ZZZZZZ should be r'd f or end of the teport period and pick up the ensumg down time events where a component designation is not appheable.

m the followmg report periods. Report duration of outages rounded to tbe nearest tenth of an hour to facilitate summation.

The sum of the total outage hours plus the hours the genera-CAUSE & CORRECTIVE ACTION TO PREVENT RECUR-tor was on hne should equal the gross hours in the reportmg RENCE. U>e the column in a narratise fasluon to amphis er pe rioJ '

explain the circumstances of the shutdown or power reduction.

The column should include the specific cause for each shut.

down or significant power reduction and the immediate and REASON. (.ategori/c by letter designation in accordance with the table appeanng on the report form. If category 11 contemplated long term corrective action taken. if appropri-ate. This column should also be used for a descnption of the must be used, supply boet comments.

or ufety.related corrective maintenance performed dunng METilOD OF SilUT TING DOWN Tile REACTOR OR the stap m power redusnon including an idenuficanon of REDUCING PO%ER.

Cateponze by number designation the entical path aetmt> and a report of any smple release et radioactivity or single radianon exposure speaftally asso t-s INote that this dif fers imm the Edison Llectric Institute ated with the outage which accounts for more than 10 percent (ELI) detinitions of " Forced Partial Outage - and " Sche.

of the allowable annual values Juled Partial Outage.

For these terms. El-l uses a change of For long textual reports continue narrative on separate paper 30 MW as the break pomt. For larger power rea< tors. 30 MW and referente the shutdown or power reducnon tm thn a too small a change to warrant explananon.

narrative.

pF7 3

AVERAGE DAILY UNIT POWER LEVEL 50-409 DOCKET NO.

LACBWR WIT 11-06-78 DATE L.G.PAPWORTH COMPLETED BY 608-689-2331 TELEPHONE OCTOBER 1978 MONT!I DAY AVERAGE DAILY POWER LEVEL DAY AVER AGE DAILY POWER LEVEL (MWe-Net)

(Mwe-Net) 1 36 35 37 2

36 o

i3 36 3

in 0

4 36 0

20 5

36 0

21 36 0

6 22 36 0

7 23 8

36 0

24 9

36 0

25 10 36 26 0

11 36 0

27 35 o

12 73 36 0

13 29 14 36 0

30 15 36 o

3, 36 16 8

INSTRUCTIONS On this fonnat, list the average daily unit power level in MWe-Net for each day in the reporting month. Compute o the nearest whole megawatt.

P1/77)

OCTOBER 1978 INSTRUMENT AND ELECTRICAL MAINTENANCE LER OR NATURE OF OUTAGE MALFUNCTION EQUIIMENT MAINTENANCE hUMBER CAUSE RESULT CNRECTIVE ACTION Radiation Monitoring New Installation NA New Equipment Test / Operation /on-Completed Installation Line Security Equipment Preventive NA Improper Operation Battery Charger Adjusted Unit and Instructed Inoperative Guard Force on Proper Oper-ation LPSW Pump 1B Preventive NA Preventive Maint-Megger Motor Completed Test enance Due i

Control Switches Preventive NA Preventive Maint-Clean and Lubricate Completed Preventive Mainten-enance Due Control Switches ance Work Security Equipment Corrective Outage Improper Alignment No Alarm Realigned Bias Magnet MR 2240, 2241,2210 78-14 Control Rod Drive Corrective Outage Incorrect Set Point Incorrect Light Completed Switch Adjustment MR 2239 78-14 Sequence for CRD #18 Security Equipment Corrective NA Defective Unit No Alarm Reset Installed Spare Unit MR 2226 Emergency Power Facility Change Outage Required Alarm Alarm Installed, Completed FC-78-10 FC-78-10, MR 2223 78-14 Installation Tested Satisfactory Nuclear Instrumentation Corrective Outage Defective Capacitor Intermittent Spike Replaced Capacitor MR 2201 78-14 Nuclear Instrumentation Corrective Outage Defective Tube Downscale Spike Replaced Tubes MR 2177 78-14

OCT01.;

..,0 INSTRUMENT At!D ELECTRICAL MAINTENANCE LER OR NATURE DE OUTAGE MALFUtiCTI0ti EQUIT" Erit MAlf!TENANCE t,Ut>B E R CAUSE RESULT CnRRECTIVE ACTIC'4 Forced Circulation System Corrective Outage Instrumentation Improper Indication Calibrated Differential MR 2228 78-14 Drift Pressure Cells L

Control Rod Drive Corrective Outage Defective Unit Improper Indication Replaced Transducer with MR 1842 78-14 Spare Unit Nuclear Instrumentation Preventive Outage Preventive Tube Replacement Completed Tube Replacement MR 2177 78-14 Maintenance I

!SecurityEquipment Corrective NA Defective Alarm Alarm Would Not Replaced Circuit Board l

MR 2208 Unit Clear Primary Purification Corrective Outage Defective Thermo-Low Temperature Replaced Thermoccuple System MR 2230 78-14 couple Indication Primary Purification Corrective Outage Defective Thermo-Low Temperature Replaced Theruccouple Systen MR 2230 78-14 couple Indication t

OCTOBER 1978 MECllANICAL MItINTENANCE LER OR f1ATURE OF OUTAGE MALFUNCTION EQUIPMENT MAINTENANCE NUMBER CAUSE RESULT CORRECTIVE ACTION 1B Low Pressure Service Corrective NA Nomal Wear Mechanical Seal Overhauleci Pump - Replaced Water Pump (LPSW)

MR 2199 Failure Bearings, Wear Rings, Mechanical Seal and Upper Shaft Section Primary Purification System Corrective Outage NA NA Removed Blank Flange In-Regenerative Cooler Shell MR 2214 78-14 stalled Previously and Side Relief Valve, Installed Rebuilt Relief 51-27-003 Valve 1A and IB Control Rod Drive Preventive Outage Nomal Wear NA Overhauled Pumps. Replaced Effluent Pumps MR 2105 78-14 Bearings and Impellers.

Lower Control Rod Drives, Corrective /

Outage Normal Wear Oil Leaks Perfomed 2-Year Preventive Positions 9, 4, 11, 12, &

Preventive 78-14 Maintenance and Repaired Oil 29.

Frame Nos. 10, 13, 11, MR 2042 Leaks on Frames 12, 11, 4, 4, & 29 Respectively

& 29.

Removed Frame 10 for Torque Test on Upper Drive No. 1 Auxiliary Oil Pump Preventive Outage NA NA Checked Pump for Wear for 1A Forced Circulation MR 22N 78-14 Pump (FCP)

Coupling Oil Pumps Nos. 1 Preventive Outage Normal Wear Reduced Pumping Overhauled Pumps and 2 for 1B FCP MR 1991 78-14 Capacity - No. 2 Pump 1B Control Rod Drive Hy-Corrective Outage Normal Wear Oil Leak on Valve Installed New 0-Ring Seal draulic Charging Pump Dis-MR 2104 78-14 Stem on Valve Stem charge Isolation Valves I

i t

OCTOBER 1978 MECHANICAL MAINTENANCE LER OR NATURE OF C4UTAGE MALFUNCTION EQUIPMENT MAINTENANCE NUMBER CAUSE RESULT CORRECTIVE ACTION Hydraulic Valve Accumulator Corrective Outage Normal Deteriora-Leakage through Replaced Leather Check Valve (HVA) System 1B Pump Suc-MR 2060 78-14 tion Valves Disc Inserts with Rubber tion and Discharge Check Inserts Valve, IA Pump Suction Check Valve 1A Seal Injection Pump Corrective Outage Normal Wear Excessive Leakage Repacked Plungers MR 2234 78-14 Past Plungers 1A Forced Circulation Corrective Outage Lower Radial Bear-Excessive Vibration Rcplaced Bearing. Mach-Pump (FCP) Fluid Coupling MR 2221 78-14 ing in Liquid ined Bearing Housing for Drive Failed Looser Fit.

Rebuilt Upper Portion of Shaft Seal Iligh Pressure Service Water Corrective Outage Undetermined Water Leak in 6" Welded Patch Over Pipe (HPSW) Piping MR 2250 78-14 Header 1A Emergency Diesel Gener-Corrective Outage In Leakage of Lube Oil Sample Checked Possible Source of ator MR 2220 78-14 Fuel Oil into Analysis Indicated Fuel Oil Leakage. Found Lube Oil Fuel Oil Dilution No. 2 Injector Nozzle Cracked. Replaced, i

Containment Building Ventil-Corrective Outage Normal Wear and Excessive Air Leak-Repacked Dampers and Re-ation Exhaust Dampers MR 2251 78-14 Deterioration age Through Dampers placed Seats. Also Re-LER 78-11 During Type A Test versed Each Damper and Packing on Downstream Damper per FC-78-19 to Improve Leak Tightness of Dampers I

I j

r

OCTOBER 1978 MECHANICAL MAINTENANCE LER OR NATURE OF OUTAGE MALFUNCTION EQUIPMENT PAINTENANCE NUMBER CAUSE RESULT CORRECTIVE ACTION 1A Air Compressor Corrective Outage Wear Caused by Leak in Capper Renlaced Copper Tubing MR 2253 78-14 Rubbing Contact Tubing Line to Un-With Adjacent Loading Solenoid Piping Valve Main Steam Pipe Hanger Preventive Outage NA NA Inspected Pipe Hanger MS-100 MR 2259 78-14 Clamp for Possible Loose-ness.

Found OK.

f

NARRATIVE

SUMMARY

OF OPERATING EXPERIENCE OCTOBER 1978 At the onset of the October reporting period, power generation was continuing at a reduced output of 36 MWe-Net (78 % reactor rated thermal power).

Operation at this reduced level was due to continued indications of increased vibration of the lower radial bearing and thrust bearing of the fluid coupling on Forced Circulation Pump 1A (see June, July, August and September 19*,8 narratives).

Reactor power continued at the above level until 2130 hours0.0247 days <br />0.592 hours <br />0.00352 weeks <br />8.10465e-4 months <br /> on October 17, 1978 when a scheduled plant shutdown was initiated for the primary purpose of inspection and necessary repair of the Forced Circulation Pump 1A fluid coupling.

The plant was removed from the DPC grid at 0348 hours0.00403 days <br />0.0967 hours <br />5.753968e-4 weeks <br />1.32414e-4 months <br /> on Octobe-18 and the reactor shut down at 0352 hours0.00407 days <br />0.0978 hours <br />5.820106e-4 weeks <br />1.33936e-4 months <br /> the same day.

Upon inspection of the Forced Ci' culation Pump 1A fluid coupling, repairs were effected including replacement of the lever radial bearing and upper thrust bearir.g, machining of the radial bear-ing housing and rebuilding of the upper section of the shaft seal.

These repairs are expected to resolve the increased vibra-tion indications experienced during the munths of June-October 1978.

Reactor Operator / Senior Operator examinations, including reactor criticality demonstrations, were also conducted during the October maintenance outage.

Additionally, periodic prirary reactor containmen integrated leakage testing (Type A) was per-formed during this outage and was in effect at the end of the reporting period.

Othel maintenance performed during the reporting period are indi--

cated on attached Instrument and Electrical Maintenance and Mechanical Maintenance schedules.

The maximum power level at which the reactor was operated during October 1978 was 36 MWe-Net (78% reactor rated thermal power).

The off-gas activity levels, as measued at the 150 ft3 holdup tank effluent monitor (prior to entry into the augmented of f-gas holdup system) did not exceed 568 curies per day (this at 78%

power) during October 1978 and the alpha activity in the primary coolan' Cid not exceed 3.5 x 10-7 uri/gm during the reporting pericJ.

REFUEL 1NG INFORMATION REQUEST 1.

Name of Facility La Crosse Boiling Water Reactor (LACBWR) 2.

Scheduled date for next refueling shutdoun.

The tentatively scheduled date for the next refueling shutdown (EOC-V) is February 10, 1979.

3.

Scheduled date for restart follouing refueling.

The tentatively scheduled date fc subsequent reactor startup is April 10, 1979.

4.

Will refueling or resumption of operation thercafter require a technical specification change or other license amendment?

If ansuer is yes, uhat, in general, vill these be?

If ansver is no, has the reload fuct design and core configur-ation been revicued by your Plant Safety Revicu Cc mmittee to determine whether any unrevieued pafety questions are assoc-iated with the core reload (Ref. 10 CFR Section 50. 59) ?

If no such revieu has taken place, when is it scheduled?

It is prsently believed that refueling or subsequent operation will not require a license amendment or technical specification change.

The reload fuel design will not be different than that licensed for Cycle V.

The reload core configuration has not yet been reviewed by LACBWR Safety Review Committee; it is anticipated this will be done in December 1978.

5.

Schedated date (s) for submitting proposed licensing action and supporting informa tion.

Not applicable.

6.

Important licensing considerations associated uith refueling, e.g.,

new or different fuel design or supplier, unreviewed design or performance analysis methods, significant changes in fuel design, neo operating procedures.

None anticipated.

_ y _

7.

The numb"r of fuct acecmblice (1) in the core and (b) in the opent fuct etorage pool.

Core loading (as of October 1, 1978):

72 fuel assemblies.

Spent fuel storage pool loading (as of October 31, 1978):

113 irra6iated fuel assemblies.

One dummy fuel assembly is stored in the spent fuel pool.

B.

The preacnt licenced opent fuct pool storage capacity and the size of any increase in licensed storage capacity that has been rcquested or is planned, in number of fuct assemblies.

Presently licensed storage capacity:

134 fuel assemblies.

Planned storage capacity:

440 fuel assemblies.

9.

The projected date of the last refueling that can be diccharged to the spent fuct pool accuming the preacnt licensed capacity.

Refueling discharge capacity unavailable since EOC-IV, May, 1977.

19. UNIT SERVICE FACTOR. Compute by dividing hours the generator was on line (item 14) by the gross hours in the reporting period (item 11). Express as percent to the nearest tenth of a percent. Do not include sesene shut-down hours in the calculation.

20. UNIT AVAILABILITY FACTUR. Compute by dividing the unit available hours (item 14 plus item 15) by the gross hours in the reporting period (item 11). Express as percent to the nearest tenth of a percent.

21. UNIT CAPACITY FACTOR (USING MDC NET). Com-pute by dniding net electrical energy generated (item IS) by the product of maximum dependable capacity (item

7) times the gross hours in the reporting period (item iI).

Express as percent to the neare-t tenth of a percent.

22. UNIT CAPACITY FACTOR (USING DER NET). Com-pete as in item 2!. substituting design e!ectrical rating (item 5) for maximum dependable capacity.

2.i. UNIT FORCED OUTAGE RATE. Compute by disiding the total forced outage hours (from the table in Unit Shutdowns and Power Reducumn) by the sum of hou s generator on line (item 14) plus total forced outage hours (from the table in Unit Shutdow ns and Power Reductions)

Express as percent to the nearest tenth of a percent.

24. SilUTDOWNS SCilEDULED OVER NEXT 6 MONTilS (TYPE, DATE, AND DURATION OF EACll). Include type (refueling, maintenance, other), proposed date of start of shutdown, and proposed length of shutdown.

It is recogni/ed that shutdowns may be scheduled between rei nts and that tlus item may not be allinclusive. Be as accurate as possible as of the date the report is prepared.

This item is to be prepared each month and updated if appropriate until the actual shutdown occurs.

25. Self<xplanatory.

26. Self-explanatory. Note, however, that this information is requested for all units in startup and power ascension test status and is not required for units already in com-mercial operation.

TEST STATUS is detined as that period following mi-tial enticality during which the unit is tested at succes.

sively higher outputs, culminating with operation at full power for a sustained period and completion of war-ranty suns. Following this phase, the unit is generally considered by the utility to be available for commercial ope rat ion.

Date of CO\\l%IERCI\\L OPERATION is defined as the date that the unit was declareJ by the utthty owner to be available for the regular production of electiieity.

usually related to the satisfactory completion -of quali-ticanon tests as specified in the purchase contract and to the accounting policies and practices of the utility.

g - i