ML17318A678

Monthly Operating Rept for Mar 1980

ML17318A678
Person / Time
Site:	Cook
Issue date:	04/02/1980
From:	Gillett W INDIANA MICHIGAN POWER CO. (FORMERLY INDIANA & MICHIG
To:
Shared Package
ML17318A677	List: ML17318A676 ML17318A678
References
NUDOCS 8004150371
Download: ML17318A678 (10)

Text

OPERATIC DATAREPORT DOCK:-7 YO.

CO.l!PLE T

50-315

~80 M.

lett 6-~901

'P=P Donald C.

Cook RO~~Pe ov'a)"Ch S. Lic ns tf The.."~J PovIer (iaaf)Yt)t 4, N rneplate R in'Gross-.'iDYe}:

5.

Desi@a Be".M Ra:in'Yet Ifhe):

6. Nfmrnv~ Dependable C pacity (Gross!Sf Vie)r 7

Nfaxlt tnn Den A~b)

C pac't

(;ii r.V Y S. !iCh~~ges Occar in Capa"'.y Rat ny (Items lvab

'i iotas 3250 1089 1080 1044

> T l ovzh /) Sine "st Repoi

. Give asors'

9. Powe. L vei To which Res~'c'. ', IfAry ( iet XIVr'e):

10. R~ons For Rest;.'ctiors, IfAny.

This!sfonth Yr.-to-Dat Cunlulative 744 2,184

11. Hov=s ln Repo"ing Period IZ. ill'ri.bei Of Houo Reactor Yras Ca.tie

13. Re"ctor Rese<'e Silvitdovv'0 Ho~s I4. Hoes Gerer tor On-Line

15. Unit R~ve Shtttdown Hove

16. Gross Theta) En"~y Cene.=te" {MNH)

)'7. Gross Elec ical Energy Generate"','if)YH)

IS. Yet Elect>~I Ene:>y Gener" if'iYH)

19. Unit Service Factor

20. Urit Avaiiabi)ia Factor "1. Uni. Capacit; 'actor (Usin~ il1DC Yet) 2". Unit Capacity. actor(Usin~ DER *'-t)

"S. Unit Forced Ovt ge Rat" "4. Shl:tdownis Sch>vied Over Next 6 ~fonths 0

0 744 1 780.6 0

0

, 00, 94 775 515 1

7 5 577 100 81.5 100 81.5 0

18. 5 (Type. Date. an"'v="sion of each):

46 008 3

94,667,099

77. 3

77. 3 7.6 7.6

5. li Sh"t Do'-nA t End Of Re"ort

~ eriod. "s!!nlatcd D te oi Start p:

S. Vni(s ln Test S:att.'s (Poor to Ce...;.ierci'l 0" r"tion):

For c"st Acnleved I i)TIALCRITI ALITY IY)TIAL-L=CTRIC TY f:lr,. )

st)t)4150 57/

ERAGE DAILY UNIT POWER LEVEL DOCKET NO. '0-315 UNIT 1

DATE 4-2-80 COMPLETED 8Y TELEPHONE 616-465-5901 MONTH March 1980 DAY AVERAGE DAILY POWER LEVEL (MWE-Net) 1,042 DAY AVERAGE DAILY POWER LEVEL (MWe-Net) 1,047 17 10 12 13 14 15 16 1,044 1,045 1,045 1,044 1,044 1,045 1,029 1,044 1,044 1,015 1,048 1,045 1,046 1,034 1,045 18 19 20 21 22 23 25 26 27 28 29 30

'31 1,045 1,046 1,047 1,045 1,045 1,026 1,045 1,046 1,045 1,045 1,046 1,046 1,033 1,046 INSTRUCTIONS On this format list the average daily unit power level in MWe-Net for each day in the reporting month.

Compute to the nearest whole megawatt.

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UNITSIIUTDO)VNS AND POIUER REDUCTIONS REPORT MONfll DOCKET NO. IIIII TELEPII ONE

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I'ale Pl

~II PJ Licensee Event Rcport Jf c )

e)

CID E ~

O Cr CJusc &. Cofrcctlvc Action Io Pfcvcnt Rccurfcocc NONE There were no Unit shutdowns or significant power reductions.

The Unit operated, at essentially 1001 reactor power for the entire month.

I: Forced S: Schcllulcd I')/77)

Reason:

A-EIIuipn)ent Failure (Explain)

I).hlalotcn;ulcc or Test C.Rct'uclioi, D.RCIIulatory Restriction I.Operator Trainiol, &. License Exaolioation F.Adnlinist rat ivc G.Opera tlonal LIlof (I:xplaol)

II Otilcr (Explaul) hlethod:

I Manual 2 hiaoual Scfanl.

3.Autolnatic Scr;lln.

4.0lhcf (ExplJol) 4 Exhibit G - Instructions for Preparation of Data Lotry Sheets for Licensee Event Report (LER) File (NURI:G-OI 6I )

Exhibit I - Salne Source

UNITSHUTDOWNS AND POWER REDU NS INSTRUCTIONS This report should describe all plant shutdowns during the report period.

In addition. it should be the source ofexplan-ation of significant dips in average power levels.

Each signi-ficant reduction in power level (gr ater than 207o reduction 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 />) should be noted, even though the unit may not have been shut down completelyi.

For such reductions in power level, the duration should be listed as zero, the method of reduction should be listed as 4 (Other), and the Cause and Corrective Action to Prevent Recurrence column should explain.

The Cause and Corrective Action to Prevent Recurrence column should be used to provide any needed explanation to fully describe the circumstances of the outage or power reduction.

NUMBER.

This column should indicate the sequential num-ber assigned to each shutdown or significant reduction in power for that calendar year.

When a shutdown or significant power reduction begins in one report period and ends in another.

an entry should be made for both report periods to be sure all shutdowns or significant power reductions are reported.

Until a unit has achieved its first power generation, no num-ber should be assigned to each entry.

DATE.

This column should indicate the date of the start of each shutdown or significant power reduction.

Report as year. month. and day.

August i4. 1977 would be reported as 770814.

When a shutdown or significant power reduction begins in one report period and ends in another, an entry should be made for both report periods to be sure all shutdowns or significant power reductions are reported.

TYPE.

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

duled," respectively, for each shutdown or significant power reduction.

Forced shutdowns include those required to be initiated by no later than the weekend following discovery of an oif.norlnal condition.

It is recognized that some judg-ment is required in categorizing shutdowns in this way.

In general.

a forced shutdown is one that would not have been completed in the absence of the condition for which corrective action was taken.

DURATION.

Self~xplanatory.

When a shutdown extends beyond the end oi a report period, count only the time to the end ot the-report period and pick up the ensuing down time in the following report periods.

Report duratil>n of outages rounded to the nearest tenth ofan hour to faciTitate summation.

The sum of the total outage hours plus the hours the genera-tor was on line should equal the gross hours in the reporting period.

REASON.

Categorize by letter designation in accordance with the table appearing on the report form. Ifcategory H must be used. supply brief comments.

~ METHOD OF SHUTTING DOWN THE REACTOR OR REDUCING POWER.

Caieaorize by 'umber designation Note that this differs irom the Edison Electric institute IEEI) definitions ot'Forced Partial Outage" and

-Sche.

duled Partial Outage."

f>>r these tern>i. I;Fl uses J change oi

0 ~IW as the break pl>int.

F>>r larger po>>er reactors. SO MW ls n>l> slnJII J change tl> WJfl'Jlii cxplanatil>>>.

in accordance with the table appearing on the report form.

Ifcategory 4 must be used, supply brief comments.

LICENSEE. EVENT REPORT. Reference the applicable reportable occurrence pertaining to the outage or power reduction.

Enter the first four parts (event year. sequential report number, occurrence code and report type) of the five part designation as described in Item 17 of Instructions for Preparation of Data Entry Sheets for Licensee Event Report (LER) File (NUREG4161).

This information may not be immediately evident for all such shutdowns, of course, since further investigation may be required to ascertain whether 'or not a reportable occurrence was involved.) Ifthe outage or power reduction will not result in a reportable occurrence.

the positive indication of this lack of correlation should be noted as not applicable (N/A).

SYSTEM CODE.

The system in which the outage or power reduction originated should be noted by the two digit code of Exhibit G - Instructions for Preparation of Data Entry Sheets for Licensee Event Report (LER) File (NUREG4161).

Systems that do not fit any existing code should be designa-ted XX. The code ZZ should be used for those events where a system is not applicable.

, COMPONENT CODE.

Select the most appropriate component from Exhibit I - Instructions for Preparation of Data Entry Sheets for Licensee Event Report (LER) File {NUREG4161).

using the followingcritieria:

A. Ifa component failed, use the component directly involved.

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

e.g..

wrong valve operated through error: list valve as component.

C.

If a chain of failures occurs, the first component to mal-function should be listed. The sequence of events. includ-ing the other components which fail, should be described under the Cause and Corrective Action to Prevent Recur-rence column.

Components that do'ot fit any existing code should be de-signated XXXXXX. The, code.ZZZZZZ should be. used for events where a

component designation is not applicable.

CAUSE &, CORRECTIVE ACTION TO PREVENT'RECUR-RENCE.

Use the column in a narrative fashion to amplify or 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 contemplated long term corrective action taken. ifappropri-ate.

This column should aiso be used for a description of the major safety. related corrective maintenance performed during the outage or power reduction including an identification of the critical path acti~sty and a report of any single release of radioactivit> or single radiation exposure speciti<<ally asso<JffJtlve.

(~)I77

Doc No.:

Uni Name:

Completed By:

Telephone:

Date:

Page:

50-315 D.

C.

Cook Unit 81 R. S.

Lease (616) 465-5901 April 9, 1980 10f 2'ONTHLY OPERATING ACTIVITIES -- MARCH, 1980 Hi hli hts The Unit operated at 100/ power the entire reporting period except as detailed in the summary.

Total electrical generation for the month was 803,710 tlwh.

~Summa r 3/5/80 -- The South half of "B" Condenser was out of service for a 5.5 hour5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br /> period for checking of tube leakage.

3/6/80-- The East Centrifugal Charging Pump was inoperable for a 30.75 hour8.680556e-4 days <br />0.0208 hours <br />1.240079e-4 weeks <br />2.85375e-5 months <br /> period starting at 1533 hours0.0177 days <br />0.426 hours <br />0.00253 weeks <br />5.833065e-4 months <br />.

During this time the Outboard Bearing Vibration was reduced to normal limits..

3/7/80--

3/8/80--

The North half of "C" Condenser was out of service for a 3.5 hour5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br /> period for checking of tube leakage.

Power was reduced to 90Ã for testing of Turbine Valves.

Total time below 100% was 3.25 hours2.893519e-4 days <br />0.00694 hours <br />4.133598e-5 weeks <br />9.5125e-6 months <br />.

3/10/00 -'- The Reciprocating Charging Pump was inoperable for a 6 hour6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> period to repair a leak on the pump head.

3/15/80 -- Power was reduced to 90K for testing of Turbine Valves.

Total time below 1005 was 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />.

The 69/4KV Reserve Off-site Power Source was out of service for a 6.25 hour2.893519e-4 days <br />0.00694 hours <br />4.133598e-5 weeks <br />9.5125e-6 months <br /> period for preventive mainten-ance.

3/16/80 -- The Wall Fire Spray. System around Unit 1 t1ain Transfor-mer operated at 0832 hours0.00963 days <br />0.231 hours <br />0.00138 weeks <br />3.16576e-4 months <br />.

No reason for operation was found and the system was reset.

3/18/80 -- Radiation Monitor R-31 and R-32 were inoperable for a 6.75 hour8.680556e-4 days <br />0.0208 hours <br />1.240079e-4 weeks <br />2.85375e-5 months <br /> period for replacement of the sample pump.

The South half of "C" Condenser was out of service for a 4.5 hour5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br /> period for checking of tube leakage.

Doc~ No.:

Untame:

Completed By:

Telephone:

Date:

Page:

50-315 D.

C.

Cook Unit ¹1 R. S.

Lease (616) 465-5901 April 9, 1980 20f 2 3/23/80 -- Power was reduced to 90Ã for testing of Turbine Valves.

Total time below 1005 was 7 hours8.101852e-5 days <br />0.00194 hours <br />1.157407e-5 weeks <br />2.6635e-6 months <br />.

3/24/80 -- The High Demand Fire Pump was inoperable for a 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> period starting at 2150 hours0.0249 days <br />0.597 hours <br />0.00355 weeks <br />8.18075e-4 months <br /> for repairs to the pump str ainer.

3/25/80 -- Safeguard Fan 1-HY-AES-1 was inoperable for a 26 hour3.009259e-4 days <br />0.00722 hours <br />4.298942e-5 weeks <br />9.893e-6 months <br /> period starting at 0520 hours0.00602 days <br />0.144 hours <br />8.597884e-4 weeks <br />1.9786e-4 months <br />.

This was to make repairs to a binding damper.

3/30/80 -- Power was reduced to 905 for testing of Turbine Valves.

Total time below 100% was 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

The Automatic Fire Protection Spray System operated on Transformer 1-AB at 2340 hours0.0271 days <br />0.65 hours <br />0.00387 weeks <br />8.9037e-4 months <br />.

As a precautionary measure Auxiliary Power Feed to 4KV Buses 1-A and 1-B was transferred to the Reserve Off-site Source.

After checking and finding no reason for spray actuation the water was valved off at 2340 hours0.0271 days <br />0.65 hours <br />0.00387 weeks <br />8.9037e-4 months <br />.

The cause of the actuation was traced to a failed relay.

Repairs were made and the circuit returned to normal.

3/31/80 -- Buses 1-A and 1-B were returned to normal supply at 0744 hours0.00861 days <br />0.207 hours <br />0.00123 weeks <br />2.83092e-4 months <br />.

DOCKET NO.

UNIT NAME DATE COMPLETED BY TELEPHONE PAGE 50 - 315 D.

C.

Cook Unit No.

1 4-8-80 B. A. Svensson 616 465-5901 of 2 MAJOR SAFETY-RELATED MAINTENANCE MARCH 1980 During operation of the motor driven auxiliary feedpump, higher than normal vibration and temperature indications were observed on the outboard pump bearing.

The bearing was replaced and the pump tested.

A damper on the spent fuel area exhaust ventilation unit was binding.

Repaired damper and had unit tested.

Higher than normal vibrations were experienced on the east centrifugal charging pump.

Checked pump bearings, checked runout on thrust runner, aligned gear case to pump, aligned motor to gear case, adjusted bal-ance weight on bearing housing," lubricated couplings and had pump tested.

The reciprocating charging pump head gasket leaked.

Replaced head gasket and had pump tested.

The face damper air cylinder for ESF ventilation unit HV-AES-.l was sticking.

Replaced broken coupling on damper linkage and disassembled,

cleaned, lubricated and reassembled damper air cylinder.

Checked operation.

Flux mapping system detector E indicated a shorted condition, and the position decoder was not functioning properly.

Detector D was located at the bottom of core position thimble C7 (Detector D opera-tion in emergency mode) and would not move.

The D and E detector ten path transfer selector boxes were inspected.

The ten path for detector E was found shifted and the'imit switch for path C7 had misaligned.

The switch and transfer device was repositioned.

Detector E was withdrawn from the detector E ten path and placed into detector D normal position 7.

Detector E was placed into the storage location.

The detector A drive wheel was inspected and appeared to be scarred.

The detector current of E returned to normal, and the system was placed into service.

Flux mapping system detector A, located 25 inches from the top of

core, could not be moved.

The drive wheel was inspected and found damaged.

The detector cable helix was dislocated.

The detector drive wheel and the detector were replaced with spares.

The drive wheel clutch was adjusted to the proper torque.

Normal operation of detector A and drive system was verified.

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0 DOCKET NO.

UNIT NAME DATE COMPLETED BY TELEPHONE PAGE 50 - 315 ook - Unit No.

1 4-8-80

'B. A. Svensson 616 465-5901 20f 2 MAJOR SAFETY-RELATED MAINTENANCE MARCH, 1980 Detectors number 1 and number 2 of the axial power distribution mon-itoring system would not complete scans as required.

The system's operation was observed, and the flux mapping system selected path for the detectors indicated different top of core limits and bottom of core limits.

Nuclear section personnel corrected the limit adjustments.

Normal system operation returned.

The axial power distribution monitoring system would not initiate scans at the proper time period.

The detector drive systems were verified operational on manual scans.

The K3G auto start relay was replaced with a spare relay.

The system was cycled through the time sequence.

The 1AB transformer trouble alarm was received.

The relay, coil had failed.

The relay was replaced with a new type.

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