ML19259A871

Monthly Operating Rept for Dec 1978

ML19259A871
Person / Time
Site:	La Crosse File:Dairyland Power Cooperative icon.png
Issue date:	01/07/1979
From:	Papworth L DAIRYLAND POWER COOPERATIVE
To:
Shared Package
ML19259A868	List: ML19259A867 ML19259A871
References
NUDOCS 7901110107
Download: ML19259A871 (12)

Text

___

OPERATING DATA REPORT DOCKET NO.

50-409 DATE 01 07 79 COMPLETED BY L.C. PAP _ ORTH W

TELEP110NE 6ng.A90-2331 OPERATING STATUS N"I

1. Unit Name: La Crosse Boiline Water Reactor

2. Reporting Period:

0000 78-01-12 to 2400 78-31-12 165

3. Licensed Thermal Power (MWt):

65.3

4. Nameplate Rating (Gross MWe):

50

5. Design Electrical Rating (Net MWe):

50

6. Maximum Dependable Capacity (Gross MWe):

48

7. Maximum Dependable Capacity (Net MWe):

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

NA 48 Net MWe

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

10. Reasons For Restrictions,1f Any:

Self-imposed restriction due to Nuclear Instrumen-tation noise at higher ' power levels (voids in steam separators).

This Month Yr.-to.Date Cumulatise 744 8760 80,355 i1. Ilours in Reporting Period

12. Number Of flours Reactor Was Cr'.ical 744 6000.7 51.179.2

13. Reactor Reserve Shutdown "Nrs 0

0 478

14. Ilours Generator On.Line 744 5427.8 46,718.1

15. Unit Reserve Shutdown flours 0

0 79

16. Gross Thermal Energy Generated (MWil) 61,880 653,942 6,537,242

17. Gross Electrical Energy Generated (MWil)

?7,964

,_, 189,165 1,982,309

18. Net Electrical Energy Generated (MWil) 16,598 174,223 1,831,803

19. Unit Senice Factor 100 62.0 58.1 100 62.0 58.2

20. Unit Availability Factor

21. Unit Capacity Factor (Using MDC Net) 46.5 41.4 47.5 44.6 39.8 45.6

22. Unit Capacity Factor (Using DER Net)

23. Unit Forced Outage Rate 0

15.7 5.5

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

RFFUELING SHUTDOWN. MARCH 15. 1979. TENTATIVE SHUTDOWN DATE, 8-WEEK DURATION.

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

NA

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

Forecast Achiesed INITIA L CRITICALITY INITIA L ELECTRICITY COMMERCI AL OPER ATION 79011106/1 mm

i INSTRUCTIONS FOR COSIPLETING OPERATING DATA REPORT Tim 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 corresponds to the item number of the report format.

1. UNIT NAhlE. Self-explanatory.

or of commercial operation, w hiehever comes last, to the end of the period or decommissioning, whichever comes

2. RI: PORTING PERIOD. Designate the month for which first. Adjustments in clock hours should be made in the data are presena d.

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

1 LICENSED tiler 51AL POWER (5tW )is the maximum t

thermal power, expressed in megawatts, currently auth-

12. NUhlllER OF fl0URS 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. NA51EPLATE RATING (GROSS SlW,). The nameplate power designation of the turbine-generator in megavolt

13. REACTOR RESERVE SklUTDOWN 110URS. The total amperes (51VA) times the nameplate power factor of the number of hours during the gross hours of reporting turbine generator.

pericd that the reactor was removed from service for administratne or other reaans but was available for DESIGN ELECTRICAL RATING INET SlW ; is the operation.

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

14.110URS GENERATOR ON.LINE.

Also called Service llours. The iotal number of houis expressed to the near-

6. 5t AX151U51 DEPENDABLE CAPACITY (GROSS SlW,)

est tenth of an hour during the gross hours of the re-is the gross electrical output as measured at the output porting 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 listed strictive seasonal conditions.

n Unit Shutdowns for the gencrator outage hours, should

7. SIAXI51U51 DEPENDAllLE CAPACITY (NET 51W,).

Sta$ mum dependable capacity (gross) less the normal

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

ber of hours expressed to the nearest tenth of an hour during the gross hours of the reporting period that the

8. Self. explanatory.

unit was removed from service for economic or similar "I******

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

Note that this item is applicable only if

16. GROSS TIIERSIAL ENERGY GENERATED (51With e

restrictions on the power level are in effect. Short term (less than one month) hmitations on power level need The thermal output of the nuclear steam supply system during the gross hours of the reporting period, expressed not be presented in this item.

in megawatt hours (no decimals)

Since this information is used to develop figures on capa-city lost due to rettrictions and because most users of the

17. GROSS ELECTRICAL ENERGY GENERATED (51Wil).

" 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 SIWE. Net in of the reportmg penod, expressed in megawatt hours (no spite of the fact that the figure 'nnst be derived from decimals).

SlWt or percent power.

18. NET ELECTRICAL ENERGY GENERATED (SlWil).

10. REASONS FOR RESTRICTIONS, IF ANY. If item 9 The gross electrical output of the unit measured at the is used, item 10 should explain why. Brief narrative is output terminals 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 inegawatt hours. Negative requirements. Be as specific as possible within space limi-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. Il0URS IN REPORTING PERIOD For units in power

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

23. phase items 19-23 should not be computed. Instead.cnter the beginning of the period or the first electrical produc, 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-l clared to be in commercial operation. The cumulative For units in commercial operation _at the end of the figures in the second and third columns should be based i

period, the gross hours from the beginning of the period on commercial operation as a starting date.

(9/77 )

s AVERAGE DAILY UNIT POWER LEVEL 50-409 DOCKET NO.

LACBWR g.lT 01-07-79 DATE L.G.PAPWORTH COMPLETED BY

~

~

TELEPilONE DECEMBER 1978 MONT11 DAY AVER AGE DAILY POWER LEVEL DAY AVER AGE DAILY POWER LEVEL (MWe-Net)

(MWe-Net) 1 27 22 j7 29 gg 22 3

31 jn 22 21 22 4

20 21 22 3

2, 21 22 3

3 7

21 22 23 21 3

24 22 21 22 9

25 JO 21 26 22 gg 22 22-27 22 22 12 23 21 22 13 29 14 22 30 22 15 22 22 3,

to 22 INSTRUCTIONS On this format,hst the average daily unit power levelin MWe Net for each day in the reporting month. Compute to the nearest whole megawatt.

(9/77 )

50-409 l' Nil ~ SliUlDOWNS AND POWER REDUCTIONS DOCKETNO.

UNIT NAME LACBWR DATE 01-06-79 L. G. I' AlWORTII REPORT MONTil DECEMBER 1978 COMPLETED BY DW-DD N JJA TELEPil0NE E

E 5?

"h

_j E "j 1 itenset j e,

{g Crae & Correttive Date 7

3g j

jg5 Event

7 n3 Action to

$5 s

35:

Report =

SV E'

Pievent Recurrente O

e 6

78-17 78-12-03 F

NA A

4 NA CB PUMPXX EXCESSIVE INDICATED WEAR ON lA FORCED CIRCULATION PUMP FACE SEAL PROMPTED SECURING OF TliE PUMP.

PLANT OPERATIOT: CONTINUED AT A REDUCED POWER LEVEL WITil IB FORCED CIRCULATION PUMP PROVIDING CORE FLOW. REPAIRS WILL BE EFFECTED IP.

Tile NEAR FUTURE.

I I

2 3

4 i: l'orced Reason:

Methm!:

INlubit G - Instructions S St hed uled A l:quipment I adure (I splain) l Manual for Prep. nation of Dat.

Il Maintenance or Test 2 Manual Scrain.

l.ntr> Sheets for lacensee C-Refueling 4-Automatic Strain.

Isent Report tI.1 R)l'ile (NilRI G-D-Regulatory Restriction 4 Other (laptain) 0161) 1 -Operator Training & IJcense liannnation I Adntinntratise 5

G. Operational I.iror (laplain )

I sinbit 1 Saine Source 19/77) 11 Other (INplam)

e UNIT SilUTDOWNS AND P0hER REDUCTIONS INSTRUCTIONS This report should describe all plant shutdowns during the in accordance with the table appearing on the report form.

report period. In addition, it should be the source of explan-If category 4 must be used, supply brief comments.

ation of significant dips in average power levels. Each signi-ficant reduction in power level (greater than 20% reduction LICENSEE EVENT REPORT #

"eference the appbcable 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 />) reportable occurrence pertaining to the outage or power should be noted, even though the unit may not have been reduction. Enter the first four parts (event year, sequential l

shut down completely. For such reductions in power level, rep rt number, occurrence code and report type) of the five the duration should be listed as zero, the method of reduction part designation as described in item 17 of Instructions for should be hsted as 4 (Other), and the Cause and Corrective Preparation of Data Entry Sheets for Licensee Event Report Action to Prevent Recurrei ce column should explain. The (LER) File (NUREG.0161). This information may not be Cause and Correctise Action to Prevent Recurrence column immediately evident for all such shutdowns, of course, since snould be used to provide any needed explanation to fully further investigation may be required to ascertain whether or describe the circumstances of the outage or power reduction.

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

NUMilER. This column should indicate the sequential num-the positive indication of this lack of correlation should be ber assigned to each shutdown or signilleant reductionin power noted as not applicable (N/A).

for that cale idar year. When a shutdown or significant power SYSTEM CODE. The system in which the outage or power reduction begins in one report period and ends in another' an entry should be made for both report renods to be sure reduction originat:d sh'ould be noted by the two didt code of I

all shutdowns or sigmficant power reductions are reported.

Exhibit G - Instructions for Preparation of Data Entry Sheets Untd a unit has achieved its first power generation, no num-f r Licensee Event Report (LER) File (NUREG.0lol).

ber should be assigned to each entry.

Systems that do not fit any existing code should be designa-ted XX. The code ZZ should be used for those events where DATE. This column should indicate the date of the start a system is not applicable.

of each shutdown or significant power reduction. Report as year, month, and day. August 14,1977 would be reported COMPONENT CODE. Select the most appropriate component as 770814. When a shutdown o: significant power reduction fiom Exhibit I instructions for hcpeation of Data Entry beginsin one report period and ends in another, an entry should Sheets for Licensee Event Report (LER) File (NUREG-0161).

be made for both report periods to be sure all shutdowns using the following critieria:

or signifteant power reductions are reported.

TYPE. Use "F" or "S" to indicate either " Forced" or " Sche.

duled,' respectively, for each shutdown or significant power B.

If not a component failure, use the relat6d component.

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

of an of f 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.

general, a forced shutdown is one that would not have been function should be listed. The sequence of events. includ-completed in the absence of the condition for which corrective ing the other coraponents which fail, should be described action was taken.

under the Cause and Corrective Action to Prevent 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 existing code should be de.

s gnated XXXXXX. The code ZZZZZZ should be used for end of the report period and pick up the ensuing down time events where a component designation is not applicable.

in the followmg report renods. Report duration of outages rounded to the nearest tenth of an hour to facilitate summation.

t USE & r?ORRECTIVE ACTION TO PREVENT RECUR-The sum of the total outage hours plus the hours the genera-dENCE. Use the column in a narrative fashion to amplify os for was on line should equal the gmss hours in the reporting explain the circumstances of the shutdown or power reduction.

penod-The toiumn should include the specific cause for each shut-down or significant power reduction and the immediate and REASON,. Categort/e by lettei deugnation in accordance with the table appeanng on the repor form. It category 11 contemplated long term corrective action taken, if appropn-must be used, supply bnei comments.

ate. This column should also be used for a <leseription of the niaior safety-related corrective maintenance performed during METilOD OF SilUTTING DOhN Tile REACTOR OR the outan' or power reduction including an identification of REDUCING POhER.

Catecou/e b3 number designation the entical path aetmty and a report of any single release of radioacuvity or single radiation exposure specifically associ.

INote that tlus ditters f rom the Edison Electric Institute ated with the outage which accounts for more than 10 percent IEI D definitions of " Forced Partial Outage" and " Sche.

of the ailowable annual values.

Juled Painal Outage. I of these termt I i i uses a change of For long textual reports continue narrative on separate paper 30 MM as the break pomt. I or larger power reactors.30 M%

anJ reference the shutdown or power red us uon toi ihn is f a t smJll J chJflge lo w JilJnt e splJnJlloH.

nJ r ra tiv7 (o'77

NARRATIVE

SUMMARY

OF OPERA'"ING EXPERIENCE DECEMBER 1978 At the onset of the December reporting period, reactor power escalation was continuing from a level of 59% of rated thermal power (27 MWe-Net).

Reactor escalation continued until December 3, 1978 when a power level of 70% of rated thermal power (32 MWe-Net) was achieved.

At 2232 hours0.0258 days <br />0.62 hours <br />0.00369 weeks <br />8.49276e-4 months <br />, indications of excessive degradation of the upper face seal on Forced Circulation Pump 1A prompted securing of the pump and reduction of thermal power level to 49%

(22 MWe-Net).

Reactor operation continued at dus power level through the end of the reporting period with Forced Circulation Pump 1B providing total core flow.

The exact cause of the abnormalseal wear degradation is continuing to be investigated.

The face seal which is part of a buffer seal assembly, was replaced just recently (see November 1978 Narrative) when the face seal was found to be badly worn and was replaced.

It is planned that plant operation will continue in the present mode until such time that, electrical power demands allowing, the plant can be shut down for inspection and repair of the subject purp.

The maximum power level at which the reactor was operated during December was 70% (rated thermal power) and the maximum net electrical generated power developed was 32 MWe-Net.

The off-gas activity levels, as measured at the 150 ft3 holdup tans effluent monitor (prior to entry into the augmented off-gas holdup system) did not exceed 665 curies / day during December 1978 and the alpha activity in the primary coolant did not exceed 5.6 x 10-7 pCi/gm during the reporting period.

Significant maintenance items performed during the reporting period are indicated on attached Instrument and Electrical Maintenance and Mechanical Maintenance listings.

I!JSTRUMENT At!D ELECTRICAL MAINTENANCE DECEMBER 1978 LER OR NATUPE OF OUTAGE MALFUf;CTION EQUIr MEilT MAItJTEtiANCE

t. UMBER CAUSE RESULT CnRRECTIVE alt 10!i l

SECURITY SYSTEM CORRECTIVE NA LOW CURRENT NO ALARM ZONE 1 ADJUSTED LINE CURRENT MR 2355 l

SECURITY SYSTEM CORRECTIVE NA LOW CURliENT NO ALARM ZONE 3 ADJUSTED LINE CURRENT MR 2332 RADIATION MONITORING CORl!ECTIVE NA BROKEN CABLE NO READING REPAIRED CABLE AUTOMATIC GAIN SYSTEM CORRECTIVE NA NO SIGNAL SPARE UNIT INOPER-REPAIRED DEFECTIVE SOLDE'R ABLE JOINT ON P.C. BOARD l

SECURITY SYSTEM CORRECTIVE NA HIGH SENSITIVITY CONTINUOUS ALARM ADJUSTED SENSITIVITY FIRE DETECTOR SYSTEM PREVENTIVE NA TECHNICAL SPECIF-TEST SCHEDULED COMPLETED TESTING ICATION TEST DUE DIESEL 1B GENERATOR CORRECTIVE NA GOVERNOR TRIP OVERSPEED TRIP READJUSTED GOVERNOR SET TOO LOW TRIP SETTING RADIATION MONITORING CORRECTIVE NA DEFECTIVE SWITCH PAPER ALARM REPLACED ALARM SWITCH HPSW lA DIESEL PUMP CORRECTIVE NA LINKAGE LOOSE FUEL LEVEL READS RECALIBRATED GAUGE MR 2359 LOW I

s o

MECIIANICAT. MAINTENANCE TCEMBER '.978 LER OR NATURE OF A EQUIPMENT MAINT:'iif M

~

OUTAGE MALFUNCTION Nv?SER CAUSE RESULT CORRECTIVE ACTION CONT ((NMENT'nUILDING MAIN CORRECTIVE LER-INNER DOOR CASKET EXCESSIVE LEAKAGE INSTALLED NEW CASKET.

AIRI OCt-

MR 2329 78-13 BLEW OUT DURING RETESTED SATISFACTORII.Y.

TYPE "B" LEAK TEST I

CON 14 tNMENT Bt'ILDING CORRECTIVE NA CAM ROLLER ON IN-INNER DOCR WOULD INSTALLED NEW CAM ICENCY AIRJ0CK MR 2334~

NER DOOR,BRCRE NOT OPERATE ROLLER.

{P -

OFF PROPERLY I

CONTAINMENT BUILDING CORRECTIVE NA POSSIBLE DEFEC-STRONGBACK BOLTING STRAICitTENED BRACKET j MAIN AIRLOCK MR 2343 TIVE WELD BRACKET WELD ON AND REWELDED TO DOOR.

l INNER DOOR FAILtr i

i l

I a.,

i l

1, l

l 4

REFUELING INFORMATION REQUEST 1.

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

Scheduled date for next refueling shutdour..

The tentatively scheduled date for the next refueling shut-down (EOC-V) is March 15, 1979.

3.

Scheduled date for restart following refueling.

The tentatively scheduled date for subsequent reactor startup is May 15, 1979.

4.

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

If answer is yes, what, in general, vill these be?

If ansuer is no, has the reload fuel design and core configur-ation been zevieced by your Plant Safety Revieu Committee to determine uhether any unreviewed safety questions are assoc-ia ted with the core reload (Ref. 10 CFR Section 50. 59) ?

If no euch revieu has taken place, when is it ccheduled?

It is presently believed that subsequent operation after re-fueling will require a license amendment and technical specifi-cation changes.

It is anticipated that the core loading for the coming fuel cycle VI will include several Allis-Chalmers Core I (Type I) fuel assemblies which are a type used previously but are not presently incorporated into technical specifications addressing APLHGR,MCPR, LHGR, etc.

5.

Scheduled date (s) for submitting proposed licensing action and supportin] information.

February 1, 1979.

6.

Important licensing considerations aesociated with refueling, e.g., new or different fuel design or supplier, unrevieved design or performance analysis methode, significant changes in fuel design, new operating procedures.

See 4. above.

REFUELING INFORMATION REQUEST - (Cont ' d) 7.

The number of fuel assemblies (1) in the core and (b) in the spent fuel storage pool.

Core loading:

72 fuel assemblies.

Spent fuel storage pool loading:

113 irradiated fuel assemblies.

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

8.

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 assemblics.

Presently licensed storage capacity:

134 fuel assemblies.

Planned storage capacity:

440 fuel assemblies.

9.

The projected date of the last refueling that can be dis-charged to the spent fuel pool assuming the present licensed capacity.

Refueling discharge capacity unavailable since EOC-1V, 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 reserve shut-down hours in the calculation.

20. UNIT AVAILABILITY FACTOR. Compute oy 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 SIDC NET). Com-pute by dividing net electneal energy generated (item 18) by the product of maximum dependable capacity (item

7) times the gross hours in the reporting period (item 11).

Express as percent to the nearest teth of a percent.

22. UNIT CAPACITY FACTOR (USLNG DER NET). Com-pute as ir. ac...

• 1. substituting design electrical rating (item 5) for maximum dependable capacity.

23. UNIT FORCED OUTAGE RATE. Compute by dividing the total forced outage hours (from the table in Unit Shutdowns and Power Reductions) by the sum of hours generator on line (item '4) plus total forced outage hours (from the table in Unit shutJowns and Power Reductions).

Express as percent to the nearest tenth of a percent.

24. SilUTDOWNS SCllEDULED OVER NEXT 6 510NTilS (TYPE, DATE, AND DURATION OF EACil). Include type (refueling. maintenance, other), proposed date of start of shutdown, and proposed length of shutdown.

It is recognized that shutdowns may be scheduled between reports and that this item may not be allinclusive. Be as accurate as possible as cf 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-explanatory.

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 defined as that paiod following ini-tial criticality during which the unit is tested at succes-sively higher outputs. culminating with opeation at full power for a sustained period and completion of war-ranty runs. Following this phase, the unit is gene ally considered b) the utihty to be available for commercial operation.

Date of C0%1NIERCIAL OPERATION is defined as the date that the unit was declared by the uti:ity owner to be available for the regular production of electricity.

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

go-,