Text

Performace Indicators,Dec 1994
	ML20078G854
Person / Time
Site:	Fort Calhoun
Issue date:	12/31/1994
From:	; OMAHA PUBLIC POWER DISTRICT
To:	;
Shared Package
ML20078G851	List: LIC-95-0016, Forwards Fort Calhoun Station Performance Indicators,Dec 1994; ML20078G854;
References
	NUDOCS 9502030300
	Download: ML20078G854 (145)
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v OMAHA PUBLIC POWER DISTRICT FORT CALHOUN STATION PERFORMANCE INDICATORS REPORT Prepared By:

Production Engineering Division System Engineering Test and Performance Group DECEMBER 1994 ggg20ggggggggaggs

4 FORT CALHOUN STATION PERFORMANCE INDICATORS I

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.e' DECEMBER 1994 SAFE OPERATIONS PERFORMANCE EXCELLENCE COST EFFECTIVENESS

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FORT CALHOUN STATION

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DECEMBER 1994 MONTHLY OPERATING REPORT OPERATIONS

SUMMARY

During the month of December 1994, Fort Calhoun Station (FCS) operated at a nominal 100%

power. Normal plant maintenance, surveillance, and equipment mtation activities occurred dur-ing the month, in addition to scheduled online modification activities.

The newl61KV line from Omaha into the Fort Calhoun Station switchyard was energized.

On December 8, diesel generator DG-1 was declared inoperable when damper YCV-871G failed

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to open. The failure was caused by a broken linkage which was attributed to heavy icing of the

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damper. Dampers on diesel generator DG-2 were cycled to verify no common failure mode ex-isted. On December 9, DG-1 was returned to operable status with damper YCV-871H failed to

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the open position pending modifications to improve weather resistance.

I On December 9, HCV-2899B (Raw Water / Component Cooling Water interface isolation valve) failed to make up to its limit switch resulting in control room HVAC unit VA-46B being de-clared inoperable. A 24-hour administrative LCO was entered. The valve was repaired on De-cember 10, the LCO was cleared, and VA-46B was declared operable.

On December 12, DC sequencerlocout relay 86-1/S2-1 failed to operate during its surveillance test. It was declared inoperable during entry into a 48-hour LCO. It was repaired on December 13 and declared operable that day.

4 On December 12, the Personnel Air Lock (PAL) door would not pass its local leak rate test and

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was declared inoperable, requiring entry into a 48-hour LCO. The leakage was traced to a Swagelock fitting on the inner door equalizing valve. Repairs were completed that night and the PAL door was declared operable.

On December 30, component cooling water heat exchanger AC-1B was delcared inoperable and a 14-day administrative LCO was entered. This failure was due to a leak on an air sparge line.

l The leak was temporarily repaired that same day using a soft patch. lenger term repairs are be-(

ing planned for early January 1995.

l l

There were three NRC inspections completed during this reporting period:

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IER 94-04 Service Water Inspection (SWSOPI)

IER 94-22 Monthly Resident Inspection IER-94-24 Control Room HVAC Special Inspection 1

I

FORT CALHOUN STATION DECEMBER 1994 MONTHLY OPERATING REPORT OPER ATIONS

SUMMARY

(continued)

The following Licensee Event Report (LER) was submitted during this reporting period:

I FR No.

LER Date Description 94-008 12M7S4 Potential for Raw Water Pump Room Flooding following a Heavy Load Drop.94-009 12/08 S 4 Inappropriate Use of Auxiliary Building Crane OverIrradiated Fuel.94-010 12/14S4 Potential Accident Scenario Involving Loss of Control Room Air Conditioners.

Soume: Nuclear Licensing & Industry Affairs i

3

f Year-To-Date Value Performance Categories

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g Performance in Industry

~. ~.... ~ - -.

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Unplanned

Thermal Upper 10% and better

Unplann{ty --

Unit JAutomatic:

Performance; than 1994 OPPD goal

~ ~ ':Capabili.

-Scramsa,000-.

Capability Factor Loss Facto {_~-

. Hours Critics L_

Performance Better Than 1994 OPPD Goal

-. ~ ~ ~ ~

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~~

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. H_..P. S.I Sa. N. Y...

AFWSafety:::

EDG Safety :

Fuel)..

Performance Not Meeting

.. System -~

tSystemi Reliabilityf 1994 OPPD Goal

~S stem:;7;;

Y, Nom l Indicators

... Performance-

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Sept.

October Nov.

M M

M

-Chemistry- ~

Collective bVolume of J

. Industrial' Index 1 7_

Radiation iLow-Level

. : Safety '

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Exposure i:Redloactive

. Accident December lWasta 1_

.- Rate !

1994

7 Year-To-Date Best Possible T.

Value 1994 Year-End Performance Performance INPO PERFORMANCE INDICATORS (Performance for the months of January through December 1994) g

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Year-To-Date Value Performance Categories Legend

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Performance Better Than Industry Average Trend Safety.

iSlgrdficant p

- - - EEvents Actuations,.

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Performance Better Than 1994 OPPD Goal p

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] Performance Not Meeting 1994 OPPD Goal or Industry Average Trend Safety Forced System ~

Outage Failuresi Rate Sept.

October November r-w 94 W

December 1994 Equipment Year-To-Date l

Forced Collective Value Best Possible Outages /1, Radiation Performance 1994 Year-End Crtt. Hrs.

Ex Performance NRC PERFORMANCE INDICATORS (Safety System Failures and Signifcant Events ratings are averages for April 1991 through March 1994. Predictor blocks cannot be generated for these performance ind' ators because c

they are based on NRC biannual reports.

A!I other indicator values are for the months of January through December 1994.)

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2

FORT CALHOUN STATION PERFORMANCE INDICATORS REPORT DECEMBER 1994 - CUMMARY POSITIVE TREND REPORT A performance irdcator with data representing three g

consecutive months of improving performance or three consecutive months of performance that is superior to Ratic of Preventive to Tota! Maintenance & Preventava the stated goalis exhibiting a postteve trend por Nuclear Maintenance kams Overdua Operations Division Quainy Procedure 37 (NOO& 37).

(Page 89)

The following performance indicators exhbited positive in-Line Chemistry Instruments Out-of Sannes trends for the reporting rnonth:

(p,9,99) un ants Wodued

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Disabhre iniurv/lunans Frecuency Rata (Lost Time Acci-(Page 101) dent Rata) fd2018miDaladBadiation Controlled Area P age 03)

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Recordable injury /llness Casas Frecuency Rata (Page 7)

End of Positive Trend Report.

Hmh Pressure Safety Iniection System Safety System Performance I

(Page 13) madwater System Safety System Performance ADVERSE TREND REPORT Emercancy Diesef Generator Unit Rehabihty A Performance indicator with data representing 3 con-(p,g, 39) secutive months of declining performance; or four or more consecutive months of performance that is trending Donal Generator Rehabihty (25 Demands) towards declining as determined by the Manager Sta-(Page 21) tion Engineering, constitutes an adverse trend per NOD-OP-37. A supervisor whose performance indicator ex.

Number of Missed Surveillance Tests Ranukino in Lic.

hibits an adverse trend by this definition may specify in anssa Even! Ranorts written form (to be published in this report) why the trend is ret admse.

(Page 37)

Forced Outapa Rata The following performance indicator exhibited an ad-(Page 43) verse trend for the reporting month:

Fuel Rehabihty indcator Unit Canacity Factor (Page 45)

(Page 25)

An adverse trend is indicated based on the FRI value for Unit Canabddy Factor the reporting month exceeding the 1994 Fort Calhoun (Page 49) monthly goal of less than 5.0 X 10*, and the potential for 1 or 2 defective fuel rods in the core.

Unnlanned Can=Niity Loss Factnr i

(Page 51)

End of Adverse Trend Report.

Fnuinment Forced Ootanas Par 1.000 Critieml Hours (Page 65)

Primarv Syntam Chemistrv Pareent of Hours Out of Limit (Page 73)

Sacandary System Chamtstry (Page 75) b V

FORT CALHOUN STATION PERFORMANCE INDICATORS REPORT l

DECEMBER 1994 -

SUMMARY

[

INDICATORS NEEDING INCREASED MANAGEMENT ATTENTION REPORT i

A performance indcator with data for the reporting penod that is inadequate when compared to the OPPD goal is Emercancy AC Power Swatam Safatv Swatam Perfor-dehned as "Needing leeressed Management Attenton*

EIEMit per NODOP 37.

(Pa0e 17)

The year to<iate unavailability value for the reporting The following performance indmetors are cited as need-month (0.029) is above the 1994 year-end goal of a ing increened management attention for the reporting maximum value of 0.025.

month:

Emercancy Donal Generator Unrahabdsv Wge 23)

Industrial Salatv Accident Rate The year-to date unrobabdily value of 0.06 is above the ipa 0e 3) 1994 year-end goalof a maximum value of 0.0.

The year to date industrial accident rate value of 0.55 exceeds the 1994 Fort Calhoun year-end goal of s.50.

Thermal Performance (Page 61)

Initial results.from testing to verify FW flow

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mquimments indicate biased msults from plant

, 27 w total number of control room equipment dehemacies instruments is causing the thermal performance at the end of the reporting month has exceeded the 1994 indicator to be under-reported. Corrections to l

Fort Calhoun monthly goal of $45 since July 1994.

the indicator will be made upon completed of I

Valatons Par 1.000 Inanacten Hours the FW Flow Nozzle Fouling Study.

(Page 33)

The number of NRC violshons per 1,000 inaf=*ian

% of Total MWO's cmmolated oar Month identdied as hours has exceeded the Fort Calhoun goal of s1.4 since g

Mad 1994.

(p g gj) f Unolanned Automatic Raador Scrama Par 7.000 Hourn Gf5EiBI (Pa0e53) i Tamoorary Moddmatens The number of unplanned automahc reactor scrams per 7,000 hours0 days 0 hours 0 weeks 0 months critcal has exceeded the Fort Calhoun goal (Pa0e111) of 0 since February 1994. There have been no The temporary modification==amad with the surface unplanned automatic reactor scrams since February sluice line (which is removable on-line) is greater tha9 6 g 994, months old and, therefore, exceer;s the 1994 goal.

Unclanned Safety Svatam Actuatens - fMPO Definiten)

End of Management Attention Report.

(Page 55)

The number of INPO unplanned safety system actus-tions has exceeded the Fort Calhoun goal of 0 since February 1994. There have been no INPO unplanned safety system actuations since February 1994.

PERFORMANCE INDICATOR REPORT Unclanned Salaty Swatam Actualmns -(NRC Definiten)

(Page 57)

IMPROVEMENTS / CHANGES The number of NRC unplanned safety system actuations has encoeded the Fort Calhoun goal of 0 since February This section lists significant changes made to the report 1994. There have been no NRC unplanned safety sys-and to specific indicators within the report since the pre-tem actuations since February 1994.

vious month.

Maantanance Waridoad Backloon (Page 87)

NRC AnnunciatorWindow The backlog of non outage MWOs for corrective mainte-(Page iv) nance has exceeded the 1994 monthly goal of a maxi.

The block representing equipment forced outa0es per mum of 400 since August 1994.

1,000 critical hours has been revised to show that perfor-mance has been better than the industry average trend for the last 4 months.

VI End of Performance Indicator Report improvements /

Changes Report i

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Tabb of Cont::nts/ Summary

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........ xi SAFE OPERATIONS P.AaE INDUSTRIAL SAFETY ACCIDENT RATE - INPO...... -

3 j

DISABLING INJURY /lLLNESS FREQUENCY RATE..

5 RECORDABLE INJURY /lLLNESS CASES FREQUENCY RATE............-......

..... 7 CLEAN CONTROLLED AREA CONTAMINATIONS 21,000 DISINTEGRATIONSMINUTE PER PROBE AREA 8

PREVENTABLE / PERSONNEL ERROR LERs

-.9 SAFETY SYSTEM FAILURES.....

11

=

SAFETY SYSTEM PERFORMANCE:

HIGH PRESSURE SAFETY IPUECTION SYSTEM........

-..... 13 AUXILIARY FEEDWATER SYSTEM-

... 15

. 17 EMERGENCY AC POWER SYSTEM...

EMERGENCY DIESEL GENERATOR UNIT RELIABILITY.

............ 19 EMERGENCY DIESEL GENERATOR RELIABILITY (25 DEMANDS)

_.... 21

........ ~.

EMERGENCY DIESEL GENERATOR UNRELIABILITY -

23 FUEL RELIABILITY INDICATOR 25 NUMBER OF CONTROL ROOM EQUIPMENT DEFICIENCIES...

- _27 l

COLLECTIVE RADIATION EXPOSURE.

29 i

MAXIMUM INDIVIDUAL RADIATION EXPOSURE...................

- 31

..........................m VIOLATIONS PER 1,000 INSPECTION HOURS......

33 SIGNIFICANT EVENTS...

...................................35 i

i NUMBER OF MISSED SURVEILLANCE TESTS RESULTING IN LERS..

........ 37 PERFORMANCE PAGE STATION NET GENERATION __

,....... 41 FORCED OUTAGE RATE.....

.. -... 43 UNIT CAPACTIY FACTOR......

45 vii

4 PERFORMANCE (continued)

P. AGE EQUlVALENT AVAllABILITY FACTOR..

. ~. 47 '

UNIT CAPA8ILITY FACTOR.......

...............................................-.................... 49 UNPLANNED CAPABILITY LOSS FACTOR........................... -

....................................51 UNPLANNED AUTOMATIC REACTOR SCAAMS PER 7,000 HOURS CRITICAL....

..............53 i

UNPLANNED SAFETY SYSTEM ACTUATIONS - (INPO DEFINITION)..............................................

........ 55 UNPLANNED SAFETY SYSTEM ACTUATIONS -(NRC DEFINITION).......-

=.........................57 OROSS HEAT RATE.............

.. 59 THERMAL PERFORMANCE...........

-61 l

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DAILY THERMAL OUTPUT....... -....................

...... 63 1

EQUIPMENT FORCED OUTAGES PER 1,000 CRITICAL HOURS....,.............

........ 65 COMPONENT FAILURE ANALYSIS REPORT (CFAR)

SUMMARY

- 67

=....

REPEAT FAILURES..............................

69 VOLUME OF LOW-LEVEL SOLID RADIOACTIVE WASTE 71 PRIMARY SYSTEM CHEMISTRY PERCENT OF HOURS OUT OF LIMIT..........-

...........................73 l

CHEMISTRYINDEX/ SECONDARY

......... 75 i

SYSTEM CHEMISTRY.

z........

1 1

M E

l CENTS PER KILOWATT HOUR....

=...,...........79

.... -............. =

STAFFING LEVEL:

............................81 1

SPARE PARTS INVENTORY VALUE.........................

......................83 z-......

DIVISION AND DEPARTMENT PERFORMANCE INDICATORS P. AGE MAINTENANCE WORKLOAD BACKLOGS (CORRECTIVE NON. OUTAGE)......

_ 87 viii

DIVISDN AND DEPARTMENT PERFORMANCE NDICATORS (continued)

EaQE RATO OF PREVENTIVE TO TOTAL MANTENANCE

& PREVENTIVE MANTENANCE ITEMS OVERDUE.......

.,. 89 PERCENTAGE OF TOTAL MWOs COMPLETED PER MONTH IDENTIFIED AS REWORK................... 91 MAINTENANCE OVERTIME.. -

.......... 93 PROCEDURAL NONCOMPLIANCE WCIDENTS (MAINTENANCE)..................

95 PERCENT OF COMPLETED SCHEDULED MAINTENANCE ACTIVITIES (ALL MANTENANCE CRAFTS)..

.97 IN LHE CHEMISTRY INSTRUMENTS

....... 99 OUT.0F. SERVICE......

=

HAZARDOUS WASTE PRODUCED..................... =

=101 CONTAMINATED RADIATON CONTROLLED AREA...~....

.103 RADIOLOGICAL WORK PRACTICES PROGRAM.........

......... 105

.107 DOCUMENT REVIEW...

LOGGA8tE/ REPORTABLE INCIDENTS (SECURITY)............

.109 109 TEMPORARY MODIFICATIONS -

............ =

OUTSTANDING MODIFICATONS

.111 ENGINEERNG ASSISTANCE REQUEST (EAR) BREAKDOWN......

115 ENGINEERING CHANGE NOTICE STATUS......

..... 116 117 ENGINEERING CHANGE NOTICES OPEN.....

LER ROOT CAUSE BREAKDOWN...................

119

............ ~............ -.........

l LICENSED OPERATOR REQUALIFICATION TRANING......

... 121 LICENSE CANDIDATE EXAMS -

.....123 OPEN CORRECTIVE ACTON REPORTS AND INCIDENT REPORTS........

....-....... 125 MWO PLANNING STATUS (CYCLE 16 REFUELING OUTAGE).................

.127 j

OVERALL PROJECT STATUS (CYCLE 16 REFUELING OUTAGE).......

............ 129 PROGRESS OF CYCLE 16 OUTAGE MODIFICATON PLANNING............

... 130 PROGRESS OF 1994 ON-LINE MODIFICATON PLANNING -

...131 l

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l ACTION PLANS. DEFNITIONS. SEP NDEX & DISTRIBUTION LIST g

ACTON PLANS.

133 PERFORMANCE INDICATOR DEFNITIONS

..............................................135 SAFEW ENHANCEMENT PROGRAM WDEX..

........,........................ 142 REPORT DISTRIBUTION LIST..

144 s

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X

OPPD NUCLEAR ORGANIZATION GOALS Vice President - 1994 Priorities MISSION The safe, reliable and cost effective generation of electricity for OPPD customers thmugh the professional use of nuclear technology. The Company shall conduct these operations prudently, efficiently and effectively to assure the health, safety and protection of all personnel, the general public and the environment.

GOALS Goal 1: SAFE OPERATIONS To ensure the continuation of a " safety culture" in the OPPD Nuclear Program and to provide a professional working environment, in the control room and throughout the OPPD nuclear organi-zation, that assures safe operation so that Fort Calhoun Station is recognized as a nuclear indus-try leader.

1994 Priorities:

Impmve SALP ratings.

Improve INPO rating.

Reduce NRC violations with no violations more severe than level 4.

No unplanned automatic reactor scrams or safety system actuations.

GoalL PERFORMANCE To strive for Excellence in Operations utilizing the highest standards of performance at Fort Calhoun Station that result in safe, reliable plant operation in power production.

1994 Priorities:

Improve Quality, Pmfessionalism, and Teamwork.

Impmve Plant Reliability.

Meet or exceed INPO key parameters and outage performance goals.

Reduce the number of human performance errors.

Identify programmatic performance problems through effective self assessment.

Cont 3: COSTS Operate Fort Calhoun Station in a manner that cost effectively maintains nuclear generation as a viable source of electricity.

1994 Priorities:

Maintain total O & M and Capital expenditures within budget.

Streamline work processes to impmve cost effectiveness.

Goals Source: Scofield (Manager) xi

l s

SAFE OPERATIONS Goal: To ensure the continuation of a " safety culture" in the OPPD Nuclear Program and to provide a professional work-ing environment in the control room and throughout the OPPD Nuclear Organization that assures safe operation so that Fort Calhoun Station is recognized as a nuclear indus-try leader.

e 1

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2

+ Year-to-Date INPO Industrial Safety Accident Rate O

Fort Calhoun Year-End Goal ( 0.50) 1.8 -

-D--

Industry Upper 10%

V 1.6 -

-.6--

1995 INPO Industry Goal ( 0.50) 1.4 -

1.2 -

1-0.8 -

0.6 -

0 0

0.4-O O

O O

i i

i -

Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 INDUSTRIAL SAFETY ACCIDENT RATE-INPO As stated in INPO's December 1993 publication ' Detailed Descriptions of World Asso-ciation of Nuclear Operators (WANO) Performance Indicators and Other Indicators for Use at U.S. Nuclear Power Plants': "The purpose of this indicator is monitor progress in improving industrial safety performance for utility personnel permanently assigned to the station."

The INPO industrial safety accident rate value year to date was 0.55 at the end of December 1994. The value for the 12 months from January 1,1994, through December 31,1994, was 0.55.

There was one lost-time accident and no restricted-time accidents in December. There has been 1 restricted-time accident and 3 lost-time accidents in 1994.

The values for this indicator are determined as follows:

(number of restricted-time accidents + lost-time accidents + fatalities) X 200.000 (number of station person-hours worked)

The 1994 Fo:t Calhoun year-end goal is 50.50. The 1995 INPO industry goalis 50.50.

The approximate industry upper ten percentile value (for the period from 7/93 through 6/

94) is 0.12.

Data Source: Sorensen/Skaggs (Manager / Source)

Chase / Booth (Manager / Source)

Accountability: Chase / Conner

~

Adverse Trend: None 3

_ _. _ _.... _ _ 1992 Disabling injury / Illness Frequency Rate (for all Divs.)

lGOODI

--H--

Fort Calhoun Goal (0.30)

V l

1.2 -

1-0.8 -

0.6 -

0.4 -

X X

0.2 -

0 0

O Jan92 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec92 1992 1993 Disabling injury / Illness Frequency Rate lGOODI

-X-Fort Calhoun Goal ( 0.50)

V 1-0.8 -

. ?,,

u u

u,

,u

,, y u

0.2 -

0 0

Jan93 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec93 1993 4

s

1994 Disabling injury / Illness Frequency Rate 1.6 -

1993 Disabling injury / Illness Frequency Rate 1.4 -

-O-Fort Calhoun Year-End Goal ( 0.5) 1.2 -

1-l GOOD l V

0.8 -

0.6 -

C 0.4 -

0.2 -

0 X

m Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 i

DISABLING INJURY /lLLNESS FREQUENCY RATE (LOST TIME ACCIDENT RATE)

This indicator, 'ws the 1994 disabling injury / illness frequency rate. The 1993 dis-abling injury / illness frequency rate is also shown.

The disabling injury / illness frequency rate year to date was 0.41 at the end of December 1994. There was one lost-time accident reported for the month. There have been 3 lost-time accidents in 1994.

The disabling injury / illness frequency rate for the 12 months from January 1,1994, through December 31,1994, was 0.41.

The 1994 Fort Calhoun year-end goal for this indicatoris a maximum value of 0.5.

Data Source: Sorenson/Skaggs (Manager / Source)

Accountability: Chase / Conner Positive Trend SEP 25, 26 & 27 5

l i

i

--G--

1992 Recordable injury / Illness Frequency Rate (for all Divs) lGOODI Y

' ~

-M--

1992 Fort Calhoun Goal (2.0) 4-3.5 -

3-2.5 -

2-X X

X X

1.5 -

^

t s

1-0.5 -

0 Jan92 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec92 1992

-S-1993 Recordab!a injury /luness Frequency Rate 9

e in luness Frgem Rate 5-l GOOD l O

1993 Fort Calhoun Goal ( 2.0) 4.5 -

y 4-3.5 -

3-2.5 -

2-C O

O O

O

^

1.5 -

E E

__M

^

4 1-I O.5 -

0 Jan93 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec93 1993 6

I

1994 Recordable injury / Illness Frequency Rate i GCODI

--H--

1993 Recordable injury / Illness Frequency Rate 2.5 -

V O

1994 Fort Calhoun Year End Goal ( 1.5) 2.25-2-

j 1.75-n n

n n

n q

1.5 -

c 1.25-M 3_

.n 0.75-0.5 -

0.25-0 I

Jan94 Fab Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 hECORDABLE INJURY /lLLNESS CASES FREQUENCY RATE This indicator shows the 1994 recordable injury / illness cases frequency rate. The 1993 recordable injury / illness cases frequency rate is also shown.

A recordable injury / illness case is reported if personnel from any of the Nuclear Divi-sions are injured on the job and require corrective medical treatment beyond first aid.

The recordable injury / illness cases frequency rate is computed on a year-to-date basis.

The recordable injury / illness cases frequency rate year to date was 1.10 at the end of December 1994. There was one recordable injury / illness case reported for the month of December. There have been 10 recordable injury / illness cases in 1994.

The recordable injury / illness cases frequency rate for the 12 months from January 1, 1994, through December 31,1994, was 1.10.

The 1994 Fort Calhoun year-end goal for this indicator is a maximum value of 1.5.

Data ' ource: Sorenson/Skaggs (Manager / Source)

S Accountability: Conner Positive Trend SEP 15,25,26 & 27 i

i Contamination Events

-O-Fort Calhoun Year-End Goal ( 54)

V 60 -

55-C O

O O

50-45-40-uJ 35 -

30-j E-f20-15-10-5-

0 Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 CLEAN CONTROLLED AREA CONTAMINATIONS 21,000 DlSINTEGRATIONS/

MINUTE PER PROBE AREA This indicator shows the Personnel Contamination Events in the Clean Centrolled Area for contaminations 21,000 disintegrations / minute per probe area for the reporting month.

This includes the contamination events associated with the spent fuel rerack project.

There were four contamination events in December 1994. There has been a total of 47 contamination events in 1994.

The 1994 year-end goal for this indicator is a maximum of 54 contamination events.

Data Source: Chase /Little (Manager / Source)

Accountability: Chase /Lovett Adverse Trend: None. To exceed the year-end goal of a maximum of 54 contamination events,13 additional contamination events would have to occur in the last month of 1994. Based on a projected rate of approximately 4 events per month, the Station total will be 46 contamination events at the end of the year and the goal will be met.

8

i

- Preventable (18 Month Totals)

-C}- Personnel Error (18 Month Totals)

Personnel Errors (Each Month) 40-35-30-25-20-E 15-

~

10-5-

0 i

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E$NkkkE kkbh 4

5 4

f PREVENTABLE / PERSONNEL ERROR LERs This indicator depicts 18-month tctals for numbers of " Preventable" and " Personnel Error" LERs.

j The graph shows the 18-month totals for preventable LERs, the 18-month totals for Personnel Error LERs and the Personnel Error totals for each month. The LERs are i

trended based on the LER event date as opposed to the LER report date.

In November 1994, there were three events which were subsequently reported as LERs. One LER was categorized as Preventable or as Ptersonnel Error.

The total LERs for the year 1994 (through November 30,1994)is ten. The total Per-sonnel Error LERs for the year 1994 is two. The total Preventable LERs for the year is three.

The 1994 goals for this indicator are that the year-end values for the 18-month totals be no more than 12 Preventable and 5 Personnel Error LERs. (Note: Because this indica-tor is based on an 18-month period, the 1994 year-end totals will include LERs occur-ring in 1994 and the last 6 months of 1993.)

i Data Source: Trausch/Cavanaugh (Manager / Source)

-l Accountability: Chase Adverse Trend: None SEP 15 9

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10

O startup G

Shutdown 4-Operation y

j 3-

- Industry Average Trend u.

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1-r y

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5 2

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91-2 91 3 91-4 92-1 92-2 92-3 92-4 93-1 93-2 93-3 93-4 94-1 Year-Quarter SAFETY SYSTEM FAILURES This indicator illustrates the number of NRC Safety System Failures as reported by the Nuclear Regulatory Commission's Office for Analysis and Evaluation of Operational Data in the biannual " Performance Indicators for Operating Commercial Nuclear Power Reactors" report.

The following NRC safety system failures occurred between the first quarter of 1993 and the first quarter of 1994:

First Quarter 1993: The SG low pressure scram signal block reset values, for c!I 4 channels of both SGs, were greater than the allowed limits, rendering this scram input inoperable during certain operating conditions.

Second Quarter 1993: A section of the piping configuration for the borated water source of the safety injection system was not seismically qualified. This could have resulted in a failure of the system to meet design requirements during a seismic event.

Fourth Quarter 1993: 1) During surveillance testing, both PORVs for the LTOP system failed to opea during multiple attempts. The failures were a result of differential expan-sion caused by a loop seal, inappropriate venting line back pressure, and cracked valve disks; 2) Calibration errors of the offsite power low signal relays could have prevented offsite power from tripping and the EDGs from starting in the required amount of time during a degraded voltage condition; 3) Both AFW pumps were inoperable when one was removed from service for testing and the control switch for the other pump's steam supply valve was out of the auto position; 4) Only one train of control room ventilation was placed in recirc when both toxic gas monitors became inoperable. Later during surveillance, the other train auto-started and brought outside air into the control room for a six minute period.

First Quarter 1994: A single failure of an ESF relay could result in a loss of safety injection, due to premature actuation of recirculation flow, and a loss of containment spray flow.

Data Source: Nuclear Regulatory Commission Accountability: Chase Adverse Trend: None 33

1992 Monthly High Pressure Safety injection System Unavailability Value 1992 High Pressure Safety injection System Unavailability Value Year-to-Date

-O-1992 Fort Calhoun Goal ( 0.008)

GOOC 1995 INPO industry Goal (0.02)

-D-Industry Upper 10% (0.0012)

V 0.02-A A

A A

A 0.015 -

0.01 -

Cycle 14 O

Refueling C

O O

O 0.005-W r1 t

-C C

C g

i i

i Jan92 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec92 1992 1993 Monthly High Pressure Safety injection System Unavailability Value 1993 High Pressure Safety injection System Unavailability Value Year-to-

[GOODj Date y

-O-1993 Fort Calhoun Goal ( 0.008) 1995 INPO Industry Goal (0.02)

-O-Industry Upper 10% (0.0011) 0.02 -

A A

Cycle 15 0.015 -

Refueling Outage 0.01 -

C C

O O

0.005 -

M O

D-- EL---C D---Jk--C

'"1 l'L o

o 0

i i

- i i

i -- i i

i i

i Jan93 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec93 1993 i

12

E 1994 Monthly High Pressure Safety injection System Unavailability Value 1994 Year-to-Date High Pressure Safety injection System Unavailability Value l GOOD l C

1994 Fort Calhoun Goal ( 0.004) p 1995 INPO Industry Goal (0.02)

-C}- Industry Upper 10% (0.0011) 0.03 q 0.025 -

0.02-a a

a a

a 0.015 -

0.01 -

0.005 -

0.00036 C

=

5 t

0 i

-i-i i-i i

i i

i 1993 Unavailability Value Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 HIGH PRESSURE SAFETY INJECTION SYSTEM SAFETY SYSTEM PERFORMANCE This indicator shows the High Pressure Safety injection System unavailability value, as defined by INPO in the Safety System Performance Indicator Definitions, for the report-ing month.

The High Pressure Safety injection System unavailability value for the month of Decem-ber 1994 was 0.0. There were no hours of planned unavailability for surveillance tests, and no hours of unplanned unavailability, during the month. The 1994 year-to-date HPSI unavailability value was 0 0022 at the er.d of the month. The unavailability value for the last 12 months was 0.0022.

There has been a total of 58.41 hours4.74537e-4 days 0.0114 hours 6.779101e-5 weeks 1.56005e-5 months of planned unavailability and no hours of unplanned unavailability for the HPSI system in 1994.

The 1994 Fort Calhoun year-end goal for this indicator is a maximum value of 0.004.

The 1995 INPO industry goal is 0.02 and the industry upper ten percentile value (for the three year period from 7/91 through 6/94) is approximately 0.001.

Data Source: Jaworski/Schaffer Accountability: Jaworski/Schaffer Positive Trend 13

E 1992 Monthly Auxiliary Feedwater System Unavailability 4 oe 1992 Auxillary Feedwater System Unavailability Value Year-to-date

-O-1992 Fort Calhoun Goal ( 0.01) l GOOD l

--A-1995 INPO Industry Goal j

-O-Industry Upper 10% (0.0(78) i 0.025 -

A A

A 0.02 -

1 Cycle 14 0.015 -

Refueling 00 -

0 i

i i

i Jan92 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec92 1992 E

Monthly Auxiliary Feedwater System Unavailability Value 1993 Auxillary Feedwater System Unavailability Value Year-to-date IGOODl

-O-1993 Fort Calhoun Goal ( 0.01) 9

-A-1995 INPO Industry Goal ( 0.025)

- Industry Upper 10% (0.0029) 0.025 -

A A

A i

0.02 -

Cycle 15 0.015 _

Refueling Outage s

0.01 -

C O

O O

O C

O 0.005-E, 0

ii ii i;i i

i "" i 14 Jan93 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec93 1993

E Monthly Auxiliary Feedwater System Unavailability Value 1994 Year to-Date Auxiliary Feedwater System Unavailability Value

-O-1994 Fort Calhoun Goal ( 0.01)

IGOOol V

- 1995 INPO Industry Goal ( 0.025)

O Industry Upper 10% (0.0021) 0.025 -

A A

0.02-0.015 -

0.01 -

C O

O O

O--C O

O O

O 3

1993 Unavailability Value Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 AUXILIARY FEEDWATER SYSTEM SAFETY SYSTEM PERFORMANCE This indicator shows the Auxiliary Feedwater System Unavailability value, as defined by INPO in the Safety System Performance Indicator Definitions, for the reporting month.

The Auxiliary Feedwater System Unavailability Value for December 1994 was 0.0016.

There were 2.33 hours3.819444e-4 days 0.00917 hours 5.456349e-5 weeks 1.25565e-5 months of planned and no hours of unplanned unavailability during the month. The year-to-date unavailability value was 0.0028 and the value for the last 12 months was 0.0028 at the end of the month.

There has been a total of 31.18 hours2.083333e-4 days 0.005 hours 2.97619e-5 weeks 6.849e-6 months of planned unavailability and 17.26 hours3.009259e-4 days 0.00722 hours 4.298942e-5 weeks 9.893e-6 months of unplanned unavailability for the auxiliary feedwater system in 1994.

The 1994 Fort Calhoun year-end goal for this indicator is a maximum value of 0.01.

i The 1995 INPO industry goal is 0.025 and the industry upper ten percentile value (for the three year period from 7/91 through 6/94) is approximately 0.002.

Data Source: Jaworski/Nay Accountability: Jaworski/Nay Positive Trend 15

i 1992 Monthly Emergency AC Power Unavailabigty Value

-W-1992 Ernergency AC Power Unavailability Value Year-to-Date

-O-1992 Fort Celhoun Goal ( 0.024) l GOOD l

-a-1995 INPO Industry Goal (0.025)

--O-Industry Upper 10% (.0055) 0.03 -

0'025 -

^

O O

O 9

0.02-0.015 -

0.01 -

0.005 -

D C

O D

C D

D D

0-Jan92 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec92 1992 j

Monthly Ernergency AC Power Unavailabilty Value

-te---

Emergency AC Power Unavailability Value Year-to Date

-O-Fort Calhoun Goal ( 0.023) lGOODI t

--6--

1995 INPO Industry Goal (0.025)

-O-Industry Upper 10% (0.004) 0.03 -

^

0.025 -

A A

A a

A C

C C

C 0.02-0.015 -

0.01 -

0.005 -

h" D

0-Jan93 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec93 1993 16

E Monthly Emergency AC Power Unavailability Value

--M-Year-to-Date Emergency AC Power Unavailability Value IEDI O

Fort Calhoun Goal ( 0.025) t -

1995 INPO Industry Goal (0.025) 0.07-sly @dmate Upper W. (0.0035) 0.06-0.05-0.04-0.03 -

0.02 -

0.01 -

R-Fu M-es-m H

Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 EMERGENCY AC POWER SYSTEM SAFETY SYSTEM PERFORMANCE This indicator shows the Emergency AC Power System unavailability value, as defined by INPO in the Safety System Performance Indicator Definitions, for the reporting month.

The Emergency AC Power System unavailability value for December 1994 was 0.029.

During the month, there were 10.95 hours0.0011 days 0.0264 hours 1.570767e-4 weeks 3.61475e-5 months of planned unavailability for testing, and 32 hours3.703704e-4 days 0.00889 hours 5.291005e-5 weeks 1.2176e-5 months of unplanned unavailability. The Emergency AC Power System unavailability value year-to-date was 0.015 and the value for the last 12 months was 0.015 at the end of the month. The large unavailability value for February is due to maintenance outages on both diesel generators.

There has been a total of 219.59 hours6.828704e-4 days 0.0164 hours 9.755291e-5 weeks 2.24495e-5 months of planned unavailability and 43.25 hours2.893519e-4 days 0.00694 hours 4.133598e-5 weeks 9.5125e-6 months of unplanned unavailability for the emergency AC power system in 1994.

The 1994 Fort Calhoun year-end goal for this indicator is a maximum value of 0.025.

The 1994 DG unavailability has increased over 1993 DG unavailability due to changes in operational definitions of out-of-service equipment.

The 1995 INPO industry goal is 0.025 and the industry upper ten percentile value (for the three year period from 7/91 through 6/94) is approximately 0.0035.

Data Source: Jaworski/Ronning

)

l Accountability: Jaworski/Ronning

-)

Adverse Trend: None 17

E DG 1 Unreliability Value 2

DG-2 Unreliability Value 0.003 -

-+-- Station Unreliability Value 0.0025 -

Industry Upper 10% (0.001 for O

lGOODI a Three Year Average) 0.002 -

1r 0.0015 -

0.001 -

C O

O O

0.0005 -

0,0 0,0 0,0 0,0 0,0 0,0 0,0 0,0 0,0 0.0 0,0 0,0 i -

i -

i - i i - i i

- i i

- i Jan92 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec92 1992 E

DG-1 Unreliability Value i

rd DG-2 Unreliability Value 0.003 - -

Station Unreliability Value lGOODI Industry Upper 10% (0.002 for 37 4

0.0025 -

a Three Year Average) 0.002 -

C O

O O

0.0015 -

0.001 -

0.0005 -

0,0 0,0 0,0 0,0 0,0 0,0 0,0 0,0 0,0 0,0 0,0 0,0 i - i -

i

- i -

i -

i - i i - i - i -

i Jan93 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec93 1993 18

E Number of Failures /20 Demands

--M--

Trigger Values for 20 Demands O

Number of Failures /50 Demands

--V-Trigger Values for 50 Demands E

Number of Failures /100 Demands

- - Trigger Values for 100 Demands 8-l GOOD l

+

6-V Y

Y Y

?

Y Y

Y 4-2 2

2-1 1

1 1

1 11 00 00 00 00 00 00 00 00 00 00 00 Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 EMERGENCY DIESEL GENERATOR UNIT RELIABILITY This bar graph shows three monthly indicators pertaining to the number of failures that were reported during the last 20,50, and 100 emergency diesel generator demands at the Fort Calhoun Station. Also shown are trigger values which correspond to a high level of confidence that a unit's diesel generators have obtained a reliability of greater than or equal to 95% when the failure values are below the corresponding trigger val-ues. The Fort Calhoun 1994 goalis to have fewer failures than these trigger values.

The demands counted for this indicator include the respective number of starts and the respective number of load-runs for both Diesel Generators combined. The number of start demands includes all valid and inadvertent starts, including all start-only demands and all start demands that are followed by load-run demands, whether by automatic or manuallnitiation. Load-run demands must follow successful starts and meet at least one of the following criteria: a load-run that is a result of a real load signal, a load-run test expected to carry the plant's load and duration as stated in the test specifications, and a special test in which a diesel generator was expected to be operated for a mini-mum of one hour and to be loaded with at least 50% of design load (see exceptions and other demand criteriain the Definition Section of this report).

Data Source: Jaworski/Ronning (Manager / Source)

Accountability: Jaworski/Ronning

-l Positive Trend 19

O DG-1 Failures /25 Demands I

DI E

DG-2 Failures /25 Demands 5-

-O-Failure Trigger Value for 25 Demands / Fort Calhoun Goal 4-C C

C C

C D

l 3-2-

1 1

1 0

0 0

0+

0 Jan92 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec92 1992 0

DG-1 Failures /25 Demands E

DG-2 Failures /25 Demands lGOODI t

-O-Failure Trigger Value for 25 Demands / Fort Calhoun Goal 5-4-

C O

O

--O O

O O

O 3-2-

1 1

1 0

0 0

00 00 00 00 00 00 00 00 00 0

4 Jan93 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec93 1993 20

l.

l l

O DG-1 Failures /25 Demands lGOODI E

DG-2 Failures /25 Demands y

5-

-e-Fal!ure Trigger Value for 25 Demands / Fort Calhoun Goal

)

4-C O

O O

l 3-2-

l 1-l 00 00 00 00 00 00 00 00 00 00 00 0

1 I

I I

I i

i i

I I

Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 DIESEL GENERATOR RELIABILITY (25 DEMANDS)

This indicator shows the number of failures experienced by each emergency diesel generator during the last 25 start demands and the last 25 load-run demands. A trigger value of 4 failures within the last 25 demands is also shown. This trigger value of 4 failures within 25 demands is the Fort Calhoun goal for 1994.

It must be emphasized that, in accordance with NUMARC criteria, certain actions will

{

take place in the event that any one emergency diesel generator experiences 4 or more j

failures within the last 25 demands on the unit. These actions are described in the i

Definitions Section of this report. A System Engineering Instruction has been approved for the Fort Calhoun Station to institutionalize and formally approve / adopt the required 1

NUMARC actions.

]

Diesel Generator DG-1 has experienced one failure during the last 25 demands on the l

unit. On December 8,1984, DG-1 failed its monthly surveillance test because the inlet air damper would not open. The cause of the failure was found to be ice buildup on the damper louvers from a previous snowstorm.

Diesel Generator DG-2 has not experienced any failures during the last 25 demands on the unit.

Data Source: Jaworski/Ronning (Manager / Source)

Accountability: Jaworski/Ronning Positive Trend 21

E DG-1 Unreliability Value 0.003-2 DG-2 Unreliability Value

--+- Station Unreliability Value 0.0025 -

Industry Upper 10% (0.001 for O

lGOODI a Three Year Average) 0.002-V 0.0015-0.001 -

O O

0.0005-0,0 0,0 0,0 0,0 0,0 0,0 0,0 0,0 0,0 0,0 0,0 0,0 i -

i - i -

- i - i i -

- i -

i Jan92 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec92 1992 E

DG 1 Unreliability Value PA DG-2 Unreliability Value 0.003 -

--+- Station Unreliability Value l GOOD l Industry Upper 10% (0.002 for y

9 0.0025 -

a Three Year Average) 0.002 -

O O

0.0015 -

0.001 -

0.0005 -

0,0 0,0 0,0 0,0 0,0 0,0 0,0 0,0 0,0 0,0 0,0 0,0 i

i - i - i i -

i v

i i - i

- i i

v i -

Jan93 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec93 1993 22

7:

E DG-1 Unreliability Value DG-2 Unreliability Value l GOOD l

--+- Station Unreliability Value

~

Industry Upper 10% (0.002 for 0.07-

-U a Three Year Average) 0 0.06-0.05 -

0.04 -

0.03-0.02-0.01 -

On, o on,oon,oon.

oon, Ono,o o, On _0,n, On, o o o

o o

o n

n.

0 Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 EMERGENCY DIESEL GENERATOR UNRELIABILITY The purpose of this indicator is to monitor the likelihood that emergency AC power generators will respond to off-normal events or accidents. It also provides an indication of the effectiveness of maintenance, operation and test practices in controlling genera-tor unreliability.

The year-to-date station EDG unreliability value at the end of December 1994 was 0.05.

The 1994 goal for this indicator is a maximum value of 0.0.

For DG-1: There was one start demand for the reporting month with one failure.

In addition, there was 1 load-run demand without a failure.

For DG-2: There was 1 start demand for the reporting month without a failure.

In addition, there was 1 load-run demand without a failure.

Emergency diesel generator unreliability is calculated as follows:

value per DG = SU + LU - (SU x LU) where SU = Start Unreliability = number of unsuccessful starts number of valid start demands LU = Load-run Unreliability = number of unsuccessful load-runs number of valid load-run demands Station Value = average of DG-1 and DG-2 values Data Source: Jaworski/Ronning (Manager / Source)

Accountability: Jaworski/Ronning Adverse Trend: None 23 i

l Iti-14-13-E Fuel Reliability Indicator 12-lGOODI 4 (1995 INPO Industry Fuel Defect Referencet 5 X 10-4 Microcuries/ Gram)

-O-1993 Fort Calhoun Goal 1

10-

'~

E E

8-C C

C C

O O

7-2 Cycle 15 g

Refueling Oumge "6-5-

A A

A g

4-3-

0 Jan93 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec93 1993 24 f

1 M

Fuel Reliability indicator h

a 1995 INPO Industry Fuel Defect Reference (5 X 10-4 Microcurie. Gram) lGOODI O

1994 & 1993 Fort Calhoun Goals 15-

,o i

i i

Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 FUEL RELIABILITY INDICATOR The Fuel Reliability Indicator (FRI) value for December 1994 was 14.34 X 10-4 microcuries/

gram. The purpose of the FRI is to monitor industry progress in achieving and maintaining a high level of fuel integrity. The December FRl value, which is greater than the zero defect threshold value, discussed below, Indicates a potential fuel defect in the core. The plant oper-ated at full power during the month. The December FRI was calculated based on the average fission product activities present in the reactor coolant during the steady state full power opera-tion days, December 1 through 31.

i The December FRI value of 14.34 X 10d microcuries/ gram indicated a slight decrease from the November value of 13.72 X 104 microcuries/ gram. The 14.34 X 104 microcuries/ gram FRI value exceeds the 1994 operational goal. The value will not significantly decrease until the leaking pin or pins are removed from the core but may show small monthly changes due to chemistry variability.

Fission product activity data from December full power operation showed a Xenon-133 activity increase but no lodine spiking. The Westinghouse technical expert on fuel reliability has deter-mined that there is a potential for 1 or 2 defective fuel rod (s) in the Cycle 15 core. This predic-tion is based on a change in ine Xe-133 to 1-131 ratio. This prediction has been supported by results from the CHIRON and CADE fuel reliability codes which also Indicate 1 or 2 fuel pins to be failed. The Cesium isotopes will be evaluated during the end of cycle shutdown in an at-tempt to calculate the burnup of the leaking assembly. A request for quotation has been issued to provide falloed fuel inspection servic es should they be required to identify the leaking fuel assembly.

The INPO September 1992 Report " Performance Indicators for U.S. Nuclear Utility Industry" (INPO No.92-011) states that "...the 1995 industry goal for fuel reliability is that units should strive to operate with zero fuel defects. A value larger than 5.0 X 104 microcuries/ gram indi-cates a high probability of reactor core operation with one or more fuel defects. The detemiina-tion of current defect-free operation requires more sophisticated analysis by utility reactor engineers." The value of 5.0 X 10d microcurles/ gram is defined as a " Fuel Defect Reference" number or a "Zero Leaker Threshold". Each utility will calculate whether the core is defect free or not. The 1994 Fort Calhoun Station FRI performance Indicator goalis to maintain a monthly FRl below 5.0 X 10-4 microcuries/ gram.

Data Source: Holthaus/ Weber i

Accountability: Chase /Spilker Adverse Trend: An Adverse Trend is indicated based on not meeting the 1994 goal.

25 l

E Control Room Equpment Deficiencies Repairable On-Line a

Total Number of Control Room Equipment Deficiences

-O-Fort Calhoun Goal For Total Equipment Defeiencies 5

5

?

E 7

e m

.i I

'/

's

/

'0,- l

- ;] -

-D g

o 0 --

n

/

0 -0

?,

/

's

/

h

/

s

/

's

/

's

/

i Jan93 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec93 Control Room Equipment Deficiencies Repairable On Line Total Number of Control Room Equiprnent Deficiencies 80-

-O-1992 Fort Calhoun Goal For Total Equipment Deficiencies 70-60 -

50-C O

O O

-C Q

40-t 30-e 7

p 20-9

=

/

18~

El n

2 r"I FI Fi M

?

4 i

i i

i Jan92 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec92 M

Operator Work Around items Repairable On-Line Total Number of Operator Work Around items

-O-Fort Calhoun Goal for TotalOperator Work Around items 8-6-

C O

O O

O O-C O

O O

4-f 2-0 I

I I

i i

i Jan93 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec93 6

Operator Work Around items Repairable On-Line Total Number of Operator Work Around items 8-

--O-Fort Calhoun Goal for Total Operator Work Around items 6-C O

O O

O 4-2-

M M

0 i

i i

i I

i i

i Mar 92 Apr May Jun Jul Aug92 Sep92 Oct92 Nov92 Dec92 26

D Control Room Equipment Defciencies Repairable On-Line IGOODI O

Total Number of Control Room Equipment Deficiencies V

80-

-O-Fort Calhoun Goal For Total Equipment Derciencies 70-7 60-3 g

-l k

h-@

h-

-U-40

/

s 7

9 a

y' i

e g

4 30-f f

/

a f

i

)#

4 Y

20-b k'

k' I

I E

I I

2 10-f

/

's 9

/

0 Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 2

Operator Work Around items Repairable On-Line O

Total Number of Operator Work Around items 10-

--O-Fort Calhoun Goal for Total Operator Work Around items 8-0 4[

C O

O O

C-0 0

0 7

A A

n n

5 A

n x

1 i

i i

i I

i i

Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 NUMBER OF CONTROL ROOM EQUIPMENT DEFICIENCIES This indicator shows the number of control room equipment deficiencies that are repair-ablo during plant operations (on-line), the number of outstanding control room equip-ment deficie_ncies, the number of Operator Work Around (OWA) Items repairable on-line, the number of outstanding OWAs and the Fort Calhoun goals.

There was a total of 58 control room equipment deficiencies at the end of December 1994.17 of these deficiencies are repairable on-line and 41 require a plant outage to repair.

12 additional OWA items were identified this month as a result of operations' review of existing deficiencies per SOER 94-1. The OWAs were on equipment tags: VA-46A on C/R Panel Al-106A; CH-208, FIA-3115, PT-3196, RC-3A-1, RC-3C and RC-3D on C/R Panel CB-1/2/3; M/0500 on CB-4; and FW-54, HCV-1040, HIC-1180, and MOV-D1 on i

C/R Panel CB-10/11.10 OWAs require an outage to repair.

The 1994 Fort Calhoun monthly goal for this indicator is a maximum of 45 deficiencies and 5 OWAG.

Data Source: Chase / Tills (Manager / Source)

Accountability: Chase /Faulhaber Adverse Trend: None 7

-e-Monthly Personnel Radiation Exposure

-o-Personnel Cumulative Radiation Exposure (Person-Rem)

-e-Fort Ca!houn Annual Goal (250 Person-Rem) 250-C O

O O

0 G

^

O O'

200-150-100-50-5 5

5 E

5 0'

27 Jan92 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec92 1992

-g-Monthly Personnel Radiation Exposure

-e-Personnel Cumulative Radiation Exposure (Person-Rem)

-e-Fort Calhoun Annual Goal ( 200 Person Rem) 250 200-0 0

0 0

0 o

150-1 100-50-O' 5

C 3,5,5,$,

Jan93 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec93 1993 as

E Monthly Personnel Radiation Exposure (Non-Spent Fuel Rerack)

--G--

Personnel Cumuir ve Radiation Exposure (Non-Spent Fuel Rerack)

V

--O-Fort Calhoun Annual Goal ( 44 Person-Rem) b40-C O

O O

U" 30 -

c 20-m

@10-g0 Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 Monthly Personnel Radiation Exposure for Spent Fuel Rerack loooDI

- O -- Personnel Cumulative Radiation Exposure for Spent Fuel Rerack V

--O-Fort Calhoun Annual Goal ( 23 Person-Rem)

C O

O O

e

~

^

O O

O i

i i

Q-Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 COLLECTIVE RADIATION EXPOSURE The 1994 Fort Calhoun goal for collective radiation exposure, excluding the spent fuel rerack, is less than 44 person-Rem.

The exposure for December 1994 was.178 person-Rem.

The year-to-date exposure was 15.835 person-Rem.

The Fort Calhoun goal for collective radiation exposure to complete the Spent Fuel Rerack Is less than 23 person-Rem.

The Spent Fuel Rerack exposure for December was 1.09 person Rem.

The year-to-date Spent Fuel Rerack exposure was 6.994 person Rem.

The collective radiation exposure at the end of December (i.e., the sum of non-spent fuel rerack exposure and spent fuel rerack exposure) was 22.829 person Rem. The collective radiation exposure for the last 12 months was 22.829 person-Rem at the end of the month.

The 1995 INPO industry goal for collective radiation exposure is 185 person-rem per year. The approximate industry upper ten percentile value (for the three-year period from 7/91 through 6/94)is 106 person-rem per year. The yearly average for Fort Cal-houn Station for the three years from 11/91 through 11/94 was 146.158 person rem per year.

Data Source: Chase /Little (Manager / Source)

Accountability: Chase /Lovett Adverse Trend: None SEP54 29

Hshest Expcsur9 for the Month (mrem)

E Highest Exposure for the Year (mrem) l 5000-OPPD 4500 mrem /yr. Limit 3000-2000-1860 fi% ma;' >

^

m

?g

'~

1000-

~. 1,E,. %

^

w c.

374

~ sF 3: >

og

-w p :t: lf(:g;j[

v y,

o I

December 1992 Highest Exposure for the Month (mrem)

O Highest Exposure for the Year (mrem) 5000-OPPD 4500 mrem /yr.Umit 4000-3000-2000-1180 1000-a~ ' yo 596 kN s (. [ j[;4!;F v

, :e n y 0

December 1993 30

O Higheat Exposure for the Month (mrem)

O Highest Exposure for the Year (mrem)

"1 OPPD 4500 mrem /yr. lJmit 4000-3000-E E

2000-

[

Fort Calhoun 1,000 mrem /yr. Goal 1000-

$9sih9$

u?W 8 IW l,p ~ dE 255 Emy ; ;

l O

December 1994 MAXIMUM INDIVIDUAL RADIATION EXPOSURE During December 1994, an individual accumulated 255 mrem, which was the highest individual exposure for the month.

The maximum individual exposure for the year was 712 mrem at the end of December.

The OPPD limit for the maximum yearly individual radiation expcsure is 4,500 mrem /

year. The 1994 Fort Calhoun year-end goalis a maximum of 1,000 mrem.

Date Source: Chase /Little (Manager / Source)

Accountability: Chase /Lovett AdverseTrend: None

\\

- Violations per 1h inspecton Hours

+ Fort Calhoun Goal ( 1.5) l GOOD l 4-g 3-g2-J

[

C O

O O

1-0 Jan92 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec92 1992 l

l Violations per 1,000 Inspection Hours l GOOD l

--O-Fort Calhoun Goal ( 1.5) g 4-3-

.5 2-N J

g C

O O

O 1-f 5

0 Jan93 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec93 1993 32

- Wah per 1 M IWon h 3'03 3-l GOOD I

-O-Fort Calhoun Goal j

2-

=

A

/

vc

=

o-c

=

a l8_

k1-I 0

'92 13 Dec93Jan94 Feb Me Apr May Jun Jul Aug Sep Oct Nov94 VIOLATIONS PER 1,000 INSPECTION HOURS This indicator displays the number of NRC violat;ons cited in inspection reports per 1,000 NRC inspection hours. This indicator is one month behind the reporting month due to the time in-volved with collecting and processing the data.

The violations per 1,000 hspection hours indicator was reported as 1.74 for the twelve months of December 1,993 through November 30,1994.

The following inspections ended during this reporting period:

IER No.

Titig No. of Hours 94-04 NRC review of SWOPl Self Assessment 464 94-23 Special Inspection - CR/AC 40 To date, OPPD has received eleven violations for inspections conducted in 1994:

Level ill Violations (1)

Level IV Violations (7)

Level V Violations (0)

Non-Cited Violations (NCV)

(3)

The 1994 Fort Calhoun goal for this indicator is a maximum of 1.4 violations per 1,000 inspec-tion hours.

Data Source: Trausch/Cavanaugh (Manager / Source)

Accountability: Trausch Adverse Trend: None a

i e

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1 i

1*

l 1

l

g NRC Significant Events IGOODI

(

Industry Average Trend y

(

1 1

1-mgjD 1

gi]

jfg OF o

i i

i 91-2 91-3 91-4 92 1 92-2 92-3 92-4 93-1 93-2 93-3 93-4 94-1 Year - Ouarter l GOOD]

@ INPO Significant Events (SERs)

V 2

2-9 g

3 3

3 WA V4 WA WA,WA

'~

o i

i i

91-2 91-3 91-4 92 1 92 2 92-3 92-4 93-1 93-2 93-3 93-4 94-1 Year - Quarter SIGNIFICANT EVENTS This indicator illustrates the number of NRC and INPO Significant Events for Fort Calhoun Station as reported by the Nuclear Regulatory Commission's Office for Analysis and Evaluation of Operational Data in the biannual " Performance Indicators for Operating Commercial Nuclear Power Reactors" report and INPO's Nuclear Network.

The following NBC significant events occurred between the second quarter of 1991 and the First quarter of 1994:

Second Quarter 1991: Safety related electrical equipment was not adequately protected from a high energy line break.

Third Quarter 1992: The failure of a Pressurizer Code safety valve to reseat initiated a LOCA with the potential to degrade the reactor coolant pressure boundary.

The following JNP_Q significant events, as reported in Significant Event Reports (SERs), oc-curred between the fourth quarter of 1991 and the first quarter of 1994:

Second Quarter 1992: Intake of Transuranics during Letdown Filter Change-out.

Third Quarter 1992: 1) RC-142 LOCA; and 2) Premature Lift of RC-142.

First Quarter 1993: Inoperability of Power Range Nuclear Instrumentation Safety Channel D.

Second Ouarter 1993: SBFU Breaker Relay (Switchyard) Plant Trip Fourth Quarter 1993: Unexpected CEA Withdrawal.

First Quarter 1994: Unplanned dilution of Boron concentration in the RCS.

Data Source: Nuclear Regulatory Commission & INPO Accountability: Chase Adverse Trend: None 35

3-D Number of Missed STs Resulting in LERs 2-

\\

1-0 0

0 0

Jan92 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec92 1992 l

3-1 E Number of Missed STs Resulting in LERs i

2-1-

l 0

0 0

e i

i i

i Jan93 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec93 1993 m

l

3-E Number of Missed STs Resulting r n.

2-1-

0 0

I i

i 8

I i

i I

4 1

4 I

I

'92

'93 Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov DecSt NUMBER OF MISSED SURVEILLANCE TESTS RESULTING IN UCENSEE EVENT REPORTS This indicator shows the number of missed Surveillance Tests (STs) that result in Uc-ennee Event Reports (LERs) during the reporting month. The graph on the left shows the yearly totals for the indicated years.

During the month of January 199J, it was discovered that during December 1992 an ASME Section XI Code required surveillance was not completed nor corrective mainte-nance performed as a result of AC-10A falling into the " Alert Range" (LER 93-003 Fail-ure to Satisfy inservice Testing Requirer.1ents for Raw Water Pump).

On December 28,1994, during M parformae9 of CP-ST-SHIFT-0001, data was not entered for Steam Generator levea per SmyshWr re Requirements.

The 1994 Fort Calhoun monthly goal for this indicator is 0.

Data Source: Monthly Operating Report & Plant Ucensee Event Reports (LERs)

Accountability: Chase /Jaworski Adverse Trend: None SEP 60 & 61 37

l l

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l 30

l PERFORMANCE Goal: To strive for Excellence in Operations utilizing the highest standards of performance at Fort Calhoun Station that result in safe, reliable plant operation in power produc-tion.

i

50-3 Net Generation (10,000 Mw hours) 35.95 36.18 pp 31.88 2

30.68 0-27.2 20-10-Jan92 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec92 0-E Net Generation (10,000 Mw hours) 40-36.12' 35.03 35.12

.m

.mm_

m 4

4.Ar._M Aa Ja s6-.1-

'4.(

Ahh++A- - - :--. - - - - - - -

j E Net Generation (10,000 Mw hours) 40-M6 34.6 34.9 34.85 34.88 8 I 33.91 34 14 33.88 E

p30-27.s I

@d 20-10-0-

4 i

i i

i 1

i i

i Jan94 Feb Mar Apr May Jun Ju!

Aug Sep Oct Nov Dec94 SI ATION NET GENERATION During the month of December 1994 a net total of 362,103.6 MWH was generated by the Fort Calhoun Station. Cumulative net generation for Cycle 15 was 4,454,337.9 MWH at the end of the month.

Energy losses for the menth of February 1994 were attributable to a generator and reactor trip that occurred following the failure of the relay for the Containment High Pressure Signal Supervisory Circuit. Energy losses for the month of January 1994 were attributable to derates to repair condenser tubes and a failed level control valve on a heater dr#n tank.

i Energy losses for the month of December 1993 were a result of a forced outage that began on December 6 and ended on December 7. The outage was caused by an EHC I

test failure. Energy losses for September, October and November 1993 were attribut-able to the shutdown for the Cycle 15 refueling outage, which began on September 25 and ended on November 26.

l Data Source: Station Generation Report i

Accountability: Chase Adverse Trend: None 41

"'r='---e-=

.-Wt---

w

--m--.-.

---w-g-

- Forced Outage Rate GOOC

--O-1992 Fort Calhoun Goal ( 2.4%)

3y 16%-

l 14%-

12%-

10%-

6%-

4%-

C O

O O

3 0%

i i

i Jan92 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec92 1992

- Forced Outage Rate GOOC 16%-

--O-1993 Fort Calhoun Goal ( 2.4%)

1r 14%-

12%-

10%-

8%-

6%-

4%-

C O

O O

3_

0%

i i

i Jan93 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec93 1993 42

Forced Outage Rate IGOODl

--O--

Fort Calhoun Goal ( 2.4%)

y 10.1 9,3 8%-

6%-

4%-

C O

O O

~ [

1.38 h,0%

'91

'92

'93 Jan94 feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 FORCED OUTAGE RATE The forced outage rate (FOR) was reported as 0.56% for the twelve months from Janu-ary 1,1994, thru December 31,1994. The 1994 year-to-date FOR was 0.87% at the end of the month.

A forced outage occurred on February 11,1994, due to a generator and reactor trip that occurred following the failure of the relay for the Containment High Pressure Signal Supervisory Circuit. The generator was off-line for 48.9 hours1.041667e-4 days 0.0025 hours 1.488095e-5 weeks 3.4245e-6 months .

A forced outage occurred on December 6,1993, when the plant tripped during weekly testing of the turbine EHC system. The generator was off-line for 27.1 hours1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

The 1994 Fort Calhoun year-end goal for this indicatoris a maximum value of 2.4%.

The 1993 Fort Calhoun year-end goal was a maximum value of 2.4%.

Data Source: Monthly Operations Report Accountability: Chase Positive Trend 43

Monthly Unit Capacity

-M--

Cycle 14 Unit Capacity 1

110 % -

--+-- Year-to-date Unit Capability Factor 100 % -

'~~

90%-

80%--

70%-

0 0

0 60%-

g M

p 50%-

/

4V 40% ~

2

/

30%-

.Jr 20%-

10%-

0%

Jan92 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec92 1992 O

Monthly unii Capacity

--M--

Cycle 15 Unit Capacity

--+-- Year-todte Unit Capability Factor 110 % -

100% -

"O" T

90%-

80%-

0 0

0 T

C 0

0 O

O 70%-

60%-

)% -

40%-

30%-

20%-

10%-

,R, 0%

i Jan93 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec93 1993 44

l Monthly UnN Capacity Factor

- Cycle 15 Unit Capachy Factor

--+- 36 Month Average Unit Capacity Factor

--G-Fort Calhoun Goal l

110 % -

100% -

/T 0

0 0

0 70%-

,.-me g

60%-

50%-

40%-

30%-

20%-

10%-

0%

Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 l

i l

UNIT CAPACITY FACTOR This indicator shows the plant monthly Unit Capacity Factor, the Unit Capacity Factor for the current fuel cycle and the 36-month average Unit Capacity Factor.

The Unit Capacity Factor for December 1994 was reported as 101.8%. At the end of the month, the Cycle 15 Unit Capacity Factor was 91.5%, and the Unit Capacity Factor for the last 36 months was 78.3%.

The Unit Capacity Factor is computed as follows:

Net Electrical Energy Generated (MWH)

Maximum Dependable Capacity (MWe) X Gross Hours in the Reporting Period Data Source: Monthly Operating Report Accountability: Chase Positive Trend j

i l

dk u

Monthly EAF 1992 Year-to-Date Average EAF 100 % -

i 80%-

Cyde 14 E ?[

Refuehng M

i 4

. 7;.

~

q 3

7 3

40%-

~

fh !

h

.i M

ii j

l

$h yi ll ff 20%-

7 if $ il n.

Jan92 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec92 1992 4L n

Monthly EAF GOOC 1993 Year-to-Date Average Monthly EAF

.') N 9m TU W~1

$jW

!si 80%-

igi f

J ll}

K I f-I l k

ik) k)%

3 Cycle 15 60%-

f f j

l R Refueling

r.p 2

Pl

.l '?

j f M

Outage i

40%-

h k l

l lu

lf s

t a

n

,a l

r l lh 8

I l

h I *!

i O

fj

~

s

., D 4 %

gg l e gg 2

t2 e

rm Jan93 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec93 1993 46 1

l l

l Monthly EAF

- Year-to-Date Average Monthly EAF 4

lGOODI Industry Median Value (76.7% for a Three Year Avera0e) 100 % -

85.6 W

76.2 80 % -

J jd

! g fg y

m I l_ W hf kh k

h hi 60%-

M!1 l

h@#

60.8

d D

F M

l Y

$.$ (

It ik F

J kh yI h

h k

g e

n-

?

V N

si W

4

?Q k

h m

8

- ~

{'I 5

h e

w y

a e

29 o

o a

e C

i V

W g

jy Q

y k) h h} f(f h h

k h

d h

q? h fM i

W e

s Si d

20%-

i -

h T

h1 4

?

?

B b

{ff (RJ $

W,/

44 5

2 A

5

Q g

i 2

6 2;

m h

f hh h

h 5

b hY Y

kh o%

i i

i

'91

'92

'93 Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 EQUlVALENT AVAILABILITY FACTOR This Indicator shows the plant monthly Equivalent Availability Factor (EAF), the year-to-date average monthly EAF, and the year-end average monthly EAF for the previous 3 years.

The EAF for December 1994 was reported as 100%. Energy losses for the month were due to a power reduction for MTC testing and a power reduction to correct an inverter problem. The year-to-date monthly average EAF was 97.2% at the end of the month.

Energy losses for the month of February were due to a generator and reactor trip that occurred following the failure of the relay for the Containment High Pressure Signal Supervisory Circuit. Energy losses for the month of January were due to derates for condenser tube repair and a failed level control valve on a heater drain tank.

The Fort Calhoun average monthly EAF for the three years prior to this report was 78.03%. The industry median EAF value for the three year period from 7/90 through 6/93 was 76.7%.

Data Source: Dietz/Parra (Manager / Source)

Accountability: Chase

~

Adverse Trend: None 47

Monthly Unit Capacity JL

- Cycle 14 Unit Capacity l GOOD l 110 % -

--+-- Year-to4 ate Unit Capability Factor 100% -

90%-

j 80%-

1 70%-

0 0

60%-

.gg

-ta-50%-

f

-4t' 40%-

,JF

/

30%-

20%-

10%-

0%

i i

Jan92 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec92 1992 Monthly Unit Capacity 4L

--et--

Cycle 15 Unit Capacity l GOOD l Year-to-date Unit Capability Factor 110 % -

100% -

T T

90%-

80%-

?

0 T

0 0

0 O

3

'""~

70%-

60%-

50%-

40%-

30%-

20%-

10%-

I"""1 0%

i i

Jan93 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec93 1993 e

5 MonthlyUnitCapabilityFactor Year-to-Date Unit Capability Factor

-+ - 36 Month Average Unit Capability Factor 4

--G-FortCalhounGoal l GOOD 1995INPOIndustry Goal (80%)

Industry Upper 10% (89.9% for a Three Year Average)

IriftITTri HTi

$l f4 N#4 hhh IE{R!l lsM lS4]

@j b

Ih h

I i

l i

i i

i e

i i

i I

Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 UNIT CAPABILITY FACTOR This indicator shows the plant monthly Unit Capability Factor (UCF) value, the year-to-date UCFs, the 36 month average UCFs, and the UCF goals. UCF is defined as the ratio of the available energy generation over a given period of time to the reference energy generation (the energy that could be produced if the unit were operated continu-ously at full power under reference ambient conditions) over the same time period, expressed as a percentage.

The UCF for December 1994 was reported as 100%. The year-to-date UCF was 98.1%, the UCF for the last 12 months was 98.1%, and the 36-month average UCF was reported as 78.7% at the end of the month.

Energy losses for the month of February 1994 were due to a generator and reactor trip that occurred following the failure of the relay for the Containment High Pressure Signal Supervisory Circuit. Energy losses for the month of January were due to derates to repair condenser tubes and a failed level control valve on a heater drain tank.

The 1995 INPO industry goal is 80% and the industry upper ten percentile value (for the three year period from 7/91 through 6/94)is approximately 89.9%. The 1994 Fort Calhoun year-end goal for this indicator is a minimum of 96.03%.

Data Source: Generation Totals Report & Monthly Operating Report Accountability: Chase Positive Trend e

a 1992 Monthly Unplanned Capability Loss Factor

- 1992 Year-to-Date Average Unplanned Capability Loss Factor GOOD

--O-1992 Fort Calhoun Goal V

70%-

60%-

50%-

40%-

30%-

20%-

T msg 10%-

_/

C O

h u --fD

---C O

O 0%

Jan92 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec92 1992 Monthly Unplanned Capability Loss Factor

- Year-to-Dato Unplanned Capability Loss Factor

--O-1993 Fort Calhoun Goal ( 4.5%)

Y 1995 INPO Industry Goal ( 4.5%)

Industry Upper 10% (1.65% for a Three Year Average) 70%-

60%-

50%-

40%-

)

30%-

20%-

j p

10%-

kk l

Q Q

O_ O O

O,E,E

-i 3

0%

-i-,-,-i-,

i i

i Jan93 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec93 1993 50

l l

B Monthly Unplanned Capability Loss Factor

--to--

Year-to-Date Unplanned Capability Loss Factor lGOODI

--O-Fort Calhoun Goal 9

1995 INPO Industry Goal ( 4.5%)

25%-

industry Upper 10% (1.36% for a Three Year Average) j 15%-

10%-

5%-

0%

i i

j i

i i

i

]

Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 UNPLANNED CAPABILITY LOSS FACTOR This indicator shows the plant monthly Unplanned Capability Loss Factor (UCLF), the year-to-date UCLF and the goal. UCLF is defined as the ratio of the unplanned energy losses during a given period of time, to the reference energy generation (the energy that could be produced if the unit were operated continuously at full power under reference ambient conditions), expressed as a percentage.

The UCLF for the month of December 1994 was reported as 0.0%. The year-to-date UCLF was 1.61%, the UCLF for the last 12 months was 1.61%, and the 36-month average UCLF was reported as 5.73% at the end of the month.

Unplanned energy losses for the month of February 1994 were due to a generator and reactor trip that occurred following the failure of the relay for the Containment High Pressure Signal Supervisory Circuit. Unplanned energy losses for the month of January were due to derates to repair condenser tubes and a failed level control valve on a heater drain tank. Unplanned energy losses for November 1994 were due to the inoperability of the "B" 120-VAC instrument inverter for 2.5 hours5.787037e-5 days 0.00139 hours 8.267196e-6 weeks 1.9025e-6 months .

The 1995 INPO industry goal is 4.5% and the industry upper ten percentile value (for the three year period from 7/91 through 6/94) is approximately 1.36%. The 1994 Fort Calhoun year end goal for this indicator is a maximum value of 3.97%.

Data Source: Generation Totals Report & Monthly Operating Report Accountability: Chase Positive Trend

.l l

51 l

L, E

FCS Reactor Scrarns Per 7.000 Hours Critical (Year-to4 ate)

- FCS Reactor Scrams Per 7,000 Hours Critical (for the last 36 rnonths)

-O-1992 Fort Calhoun Goal

- +-- 1995 INPO Industry Goal

-O-Industry Upper 10% (0.6 per 7,000 hours0 days 0 hours 0 weeks 0 months critical over a 36 month time period) 8-7.05 5.69 5.86 6-4.76

( 85 5-4.16 3.63 4-3.23 3-2-

3

,--$- - $, h o

Jan92 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec92 1992

-- FCS Reactor Scrams Per 7,000 Hours Critical (Year t04 ate)

~

-+-- FCS Reactor Scrams Per 7,000 Hours Critical (for the last 36 months) j 7-6-

9 amoun Goal 5-

--h-1995 INPO Industry Goal 4-

-O-Industry Upper 10% (0.51 per 7.000 hours0 days 0 hours 0 weeks 0 months critical over a 36 month time period) 3-2-

,j 1-4 A

4y A

A s

^

l 0

5r-W W i-i '5 5.5 5

5 i

i i

Jan93 ~Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec93 1993 4-3-

E Number of FCS ReactorScrams 2-1 1

1 1-0 0

0 0

1 0

0 0

May Jun Jul Aug Sep Oct Nov Dec92 i

1992 4-M Numberof FCS ReactorScrams 3-

~

1 1

~

0 0

i 0

Jan93 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec93 1993 52

i l

- FCS Reactor Scrarns Per 7,000 Hours Critical Year tcxlate

-+- FCS Reactor Scrams Per 7,000 Hours Critical for the last 36 months

-O-1994 & 1993 Fort Calhoun Goals (0.0) 1 1995 INPO Industry Goal 6-

-O-Industry Upper 10% (0.48 per 7,000 hours0 days 0 hours 0 weeks 0 months critical over a 36 morth time period) 5-4-

3-2-

0 0

^

0 0

0

^

15 r--{ i 1--:gw

-w

.w w

w

.w

.w w

r-: r-: r-: r-: r-:

r-: r-: r-:

0-i i

Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 E Numberof FCS ReactorScrams 3

4-2 3-2-

p 1

g{

0 m

0 0

'90 '91 '92 13 Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 UNPLANNED AUTOMATIC REACTOR SCRAMS PER 7,000 HOURS CRITICAL The upper graph shows the number of unplanned automatic reactor scrams per 7,000 hours0 days 0 hours 0 weeks 0 months critical (as defined in INPO's 12/93 publication " Detailed Descriptions of Interna-tional Nuclear Power Plant Performance Indicators and Other Indicators") for Fort Cal-houn Station. The lower graph shows the number of unplanned automatic reactor scrams that occurred during each month for the last twelve months.

The year-to-date station value was 0.80 at the end of December 1994. The value for the 12 months from January 1,1994, through December 31,1994, was 0.80. The value for the last 36 months was 2.01.

An unplanned automatic reactor scram occurred on February 11,1994 when supervi-sory relay 86B/CPHSS failed. An unplanned automatic reactor scram occurred on December 6,1993 during EHC testing.

The 1994 Fort Calhoun goal for this indicator is 0. The 1995 INPO industry goalis a maximum of 1 unplanned automatic reactor scram per 7,000 hours0 days 0 hours 0 weeks 0 months critical. The industry upper ten percentile value is approximately 0.48 scrams per 7,000 hours0 days 0 hours 0 weeks 0 months critical for the 36-month time period from 7/91 through 6/94.

Data Source: Monthly Operations Report & Plant Licensee Event Reports (LERs)

Accountability: Chase Adverse Trend: None 53

INPO Safety System Actuations 3-

--G--

1992 Fort Calhoun Goal 1

-s-Industry Upper 10 Percentile 2-i l

1-0---O Jan92 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec92 1992 E

INPO Safety System Actuations 3-

-O-1992 Fort Calhoun Goal O

Industry Upper 10 Percentile 2-i 1-0

=

c

=

c,=,=,c c, c, Jan93 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec93 l

1993 54

l

~

E Safety System Actuations (INPO Definition)

-f>--

Fort Calhoun Goal (0.0)

-B--

Industry Upper 10 Percentile 2-I 1_

0

0 O

C O

C C

C,C C

C O

O C

i i

i-i i

i i

'91 '92 '93 Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 UNPLANNED SAFETY SYSTEM ACTUATIONS -(INPO DEFINITION)

There were no INPO unplanned safety system actuations during the month of Decem-ber 1994.

There was 1 INPO unplanned safety system actuation during the month of February 1994. It occurred on February 11 when supervisory relay 86B/CPHSS failed, which resulted in tripping relay 86B/CPHS. The CPHS relay trip actuated the Safety injection Actuation Signal, Containment isolation Actuation Signal, Ventilation Isolation Actuation Signal and Steam Generator isolation Signal. The Steam Generator Isolation Signal automatically closed both main steam isolation valves, which resulted in a concurrent turbine and reactor trip.

An INPO unplanned safety system actuation occurred during the month of July 1992. It was due to the loss of an inverter and the subsequent reactor trip on 7/3/92.

The 1994 Fort Calhoun goal for this indicator is 0.

Data Source: Monthly Operations Report & Plant Licensee Event Reports (LERs)

Accountability: Jaworski/Foley/Ronning Adverse Trend: None 55

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l l

- 12 Month Running Total SSAs (NRC Definition)

--+- Critical Hours Safety System Actuations (NRC Definition) 10-

- 1000 cycle 15 900

8-Refueling 700 e

- 800 g

Outa v

v -

v - v

<6-

- 600 8 500 3 j

f 3

f. 4 -

-400 300 o 2

[2-200 0

/s a

j 8

aa i

i I

i 11 12 93 JFMAMJJASONDJFMAMJJASOND 1992 1993 1994 UNPLANNED SAFETY SYSTEM ACTUATIONS-(NRC DEFINITION)

This indicator shows the number of unplanned safety system actuations (SSAs), which includes the High and Low Pressure Safety injection Systems, the Safety injection Tanks, and the Emer-gency Diesel Generators. The NRC classification of SSAs includes actuations when major equipment is operated and when the logic systems for these safety systems are challenged.

There was 1 NRC unplanned safety system actuation during the month of February 1994. It occurred on February 11 when supervisory relay 86B/CPHSS failed, which resulted in a concur-rent turbine and reactor trip.

There were 3 NRC unplanned safety system actuations in 1993: 1)In December 1993 the main turbine and reactor tripped during Electro-Hydraulic Control pump start testing; 2) In June 1993 the inadvertent jarring of a 345 KV fault relay in the switchyard caused a turbine and teactor trip; and 3) In April 1993 a non-licensed operator mistakenly opened the wrong potential fuse drawer, causing a low voltage alarm on bus 1 A1, a loadshed on bus 1 A1 and an auto start of an EDG.

There were 4 unplanned safety system actuations in 1992: 1) In August, due to the failure of an AC/DC converter in the Turbine Electro Hydraulic Control system, pressurizer safety valve RC-142 opened prior to reaching design pressure during a plarit transient and trip; 2) On July 3 there was an inverter failure and the subsequent reactor trip; 3) On July 23 there was an unplanned diesel generator start when an operator performing a surveillance test inadvertently pushed the normal start button instead of the alarm acknowledge button; and 4) In May the turbine generator tripped on a false high level moisture separator trip signal which caused a simultaneous reactor trip and subsequent anticipatory start signal to both diesel generators.

There have been 2 unplanned safety system actuations in the last 12 months. The 1994 Fort Calhoun goal for this indicator is 0.

Data Source: Monthly Operations Report & Plant Licensee Event Reports (LERs) l Accountability: Jaworski/Foley/Ronning l

Adverse Trend: None 57

E Monthly Gross Heat Rate

+ 1992 Year-to-Date Gross Heat Rate v

l 10.5-10-9.5 -

Jan92 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec92 1992 4

E Monthly Gross Heat Rate

--e-1993 Year-to-Date Gross Heat Rate y

10.5-Jan93 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec93 1993 2

l 3

Monthly Gross Heat Rate

--M--

Year-to-Date Gross Heat Rate 0

1994 &1993 Fort Calhoun Goals 10.5-10300

)

i 10223 1025-10177 10-s' i

i i

9.75-

'91

'92

'93 Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec.34 GROSS HEAT RATE This indicator shows the Gross Heat Rate (GHR) for the reporting month, the year-to-date GHR, the goals and the year-end GHR for the previous 3 years.

The gross heat rate for Fort Calhoun Station was 10,037 for the month of Decembei 1994. The GHR for the year 1994 was 10,176.

The GHR varies with fluctuations in river water temperature. In general, the GHR im-proves during the winter months and degrades during the summer. This is because the gross heat rate is not normalized to the design river water temperature of 60 degrees Fahrenheit.

The 1994 Fort Calhoun year-end goal for this indicator is $10,190.

Data Source: Holthaus/ Gray (Manager / Source)

- l Accountability: Chase /Jaworski AdverseTrend: None j

E MonthlyThermalPerformance

-M-1993 Year to-Date Average Monthly Thermal Performance

^

-+- 1993 Fort Calhoun Goal ( 99.4%)

-O-1995 INPO Industry Goal (99.5%)

-e-

%Jstry Upper 10% (99.9%)

100 % -

3 Jan92 Feb Mar Apr May Jun Jul Au0 Sep Oct Nov DecS2 1992 E

1992 Monthly Thermal Periormance

-M-1992 Year-to-Date Average Thermal Performance

-+- 1992 Fort Calhoun Goal ( 99.3%)

gg

-O-1995 INPO Industry Goal (99.5%)

L Industry Upper 10% (99.8%)

100 % -

4 a

a a

i a

A i

4 h

a 9 %-

Jan93 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec93 1993 60

D Monthly Thermal Performance

--et--

Year-lo-Date Average Monthly Thermal Performance j

4 O

1994 & 1993 Fort Calhoun Goals l GOOD l

--+-- 1995 INPO Industry Goal ( 99.5%)

A industry Upper 10% (99.9%)

l #'-

A A

L a

a a

a A

i i i i llll[ l Ilil O

O O

O d

b

,1.

O 98 %

)

Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 THERMAL PERFORMANCE This indicator shows the Thermal Performance value for the reporting month, the year-to-date average monthly thermal performance value, the Fort Calhoun goals, the 1995 INPO industry goal and the approximate industry upper ten percentile value.

The thermal performance value for December 1994 was 99.14%. The year-to-date average monthly thermal performance value was 99.28% at the end of the month. The average monthly value for the 12 months from January 1,1994, through December 31, 1994 was 99.28%.

The low thermal performance value for February 1994 is attributable to level control problems on heaters 3A and SB, end to spring runoff resulting in screen carry-over and condenser fouling. Improvements made during the month of March were: warm water recirc. was taken off-line; some recovery in condenser performance was achieved due to backwashing at regular intervals; and the level control problems for heater 3A were corrected. Thermal Performance improved in May as a result of the backwash valve adjustments on "A" Condenser and improvements in Heater 2A level control.

Initial results from testing to verify FW flow requirements indicates biased results from plant instruments is causing the thermal performance indicator to be under-reported.

Corrections to the indicator will be made upon completion of the FW Flow Nozzle Foul-ing Study.

The 1994 Fort Calhoun year-end goal for this indicator is a minimum of 99.5%. The 1993 Fort Calhoun goal was a minimum of 99.4%. The 1995 INPO industry goalis 99.5% and the industry upper 10 percentile value (for the 1-year period from 7/93 through 6/94) is approximately 99.9%.

Data Source: Jaworski/Popek Accountability: Jaworski/Popek 61 Adverse Trend: Increased management attention.

f 1

This page intentionally left blank.

i t

l

n 1

i ThermalOutput a

-O-Fort Calhoun 1495 MW Goal 1

Tech Spec 1500 MW Limt 1500 1499.5-1499-1496.5-1496-1497.5-1497-a m, m(/,.

1496.5-4, in ^,,

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-I i i I I i i i I i i I i 1 i i i I 4 i I I i i i i i i i I 1

3 5

7 9

11 13 15 17 19 21 23 25 27 29 31 DAILY THERMAL OUTPUT The therma" catput graph displays the daily operating power level during December 1994, the 1500 thermal megawatt average technical specification limit, and the 1495 thermal megawatt Fort Calhoun goal.

Data Source: Holthaus/ Gray (Manager / Source)

Accountability: Chase / Tills Adverse Trend: None e

l

\\

l i

?

This page Intentionally left blank. The method of calculating this indicator was revised in 1994.

4 b

i

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n

)

I i

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1

(

~

Equiprnent Forced Outage Rate /1,000 Critical 0.86 Hours for a 12 Month Interval lGOODI

~ -

1993 & 1994 Fort Calhoun Year-End Goals ( 02)

V 0.6 -

0.5 1

,0 0.4 -

0.2 -

C O

O O

m 91 S2

'93 Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 2-E Nurnber of Equipment Forced Outages Per Month 1-0-

b 5 $$

N $hb EQUIPMENT FORCED OUTAGES PER 1,000 CRITICAL HOURS The equipment forced outage rate per 1,000 critical hours for the 12 months from Janu-ary 1,1994, through December 31,1994, was 0.11. The rate per 1,000 critical hours for the months from January through December 1994 was 0.11.

An equipment forced outage occurred on February 11,1994, when the plant experi-enced an unplanned automatic reactor trip as a result of the failure of the relay for the Containment High Pressure Signal Supervisory Circuit.

An equipment forced outage occurred in August 1992 and continued through Septem-ber. It was due to the failure of an AC/DC converter in the Turbine Electro Hydraulic Control System.

The 1994 Fort Calhoun year-end goal for this indicator is a maximum value of 0.20.

Data Source: Monthly Operations Report & Plant Licensee Event Reports (LERs)

Accountability: Chase /Jaworski Positive Trend e5

1 I

(This page intentionally left blank. The method of reponing this indicator was revised in 1993.)

1

i

+ # of Component Categork 40-

-+- # of Application Categories 35-30-

--Ar--

Total # of Categories c 25-20-g 15-A A

A 10-

- v" "% -

_m 5-Y d

l7ll $$

0 J93 A S

O N

D J94 F M

A M

J J

A S

O N D94 E WearOut/ Aging G OtherDevices 5 Manufacturing Defect O Maintenance / Action d'

O Engineer'ng/ Design E Error / Operating Action 44.5 4.9%

Percent of Total Failures During I

I

,a' the Past 18 Months b

d 3.3%

\\

7.5*.

II COMPONENT FAILURE ANALYSIS REPORT (CFAR)

SUMMARY

The top chart illustrates the number of component categories, application categories and total categories in which the Fort Calhoun Station has significantly higher (1.645 standard deviations) failure rates than the industry failure rates during the past 18 months (from January 1993 through August 1994). Fort Calhoun Station reported a higher failure rate in 5 of the 87 compo-nent categories (valves, pumps, motors, etc.) during the past 18 months. The station reported a higher failure rate in 6 of the 173 application categories (main steam stop valves, auxiliary /

emergency feedwater pumps, control element drive motors, etc.) during the past 18 months.

The pie chart depicts the breakdown by INPO cause categories (see the " Definitions" section of this report for descriptions of these categories) for the 96 failure reports that were submitted to INPO by Fort Calhoun Station during the past 18 months. Of these, the failure cause was known for 81. The pie chart reflects known failure causes.

Data Source: Jaworski/ Frank (Manager / Source)

Accountability: Jaworski/ Frank Adverse Trend: None 67 j

Components With More Than One Failure

+

IGOOD V

-M--

Componerts With More Than Two Failures i

25 -

t i

20 20 -

19 18 18 18 1

15

~

13 e

\\ 11 10-5-

4 4

4 3,

3, X

'Q3 3,

,3 3y' 2

2fs m

s m

m 0

Jan92 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec92 1992 b

l 1

-+- Components With More Than One Failure l GOOD

--H-Components With More Than Two Failures y

i 25 -

21 20-18 15-11 11 11 11 11 10-9 9

5-3 3

3 3

X 2

2 n

O Jan93 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec93 1993 es l

I 4

--+-- Components With More Than One Fauure 25 -

--M-Components With More Than Two FaNures 20-15-1_2 1_2 1_2 10 [

10-e g

8 p --

p q

q 7

7 s

5-3 3

X

.(2 2,N1 1

1 1

n n

o 0

Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 REPEAT FAILURES The Repeat Failures Indicator (formerly called the " Maintenance Effectiveness" perfor-mance indicator) was developed in response to guidelines set forth by the Nuclear Regulatory Commission's Office for Analysis and Evaluation of Operational Data (NRC/

AEOD). The NRC requirement for a Maintenance Effectiveness Performance Indicator has been dropped, but station management considers it useful to continue to track repetitive component failures using the Nuclear Plant Reliability Data System (NPRDS).

This indicator shows the number of NPRDS components with more than 1 failure during the eighteen month CFAR period and the number of NPRDS components with more than 2 failures during the eighteen month CFAR period.

During the last 18 reporting months there were 8 NPRDS components with more than 1 failure.1 of the 8 had more than 2 failures. The tag numbers of the components with more than 1 failure are: AC-10A, AC-100, AC-10D, FW-48, FW-40, HCV-386-0, NT-001 and RC-374. The tag number of the component with more than 2 failures is AC-100. Recommendations and actions to correct these repeat component failures are listed in the quarterly Component Failure Analysis Report.

Data Source: Jaworski/ Frank (Manager / Source)

Accountability: Chase l

Adverse Trend: None l

3 Radioactive Waste Buried This Month (in cubic feet)

- Cumulative Radioactwo Waste Buried gg,y

--O-Fort Calhoun Goal For Waste Buried (3,000 cubic feet)

V 3000-C C

C C

C O

C C

O C

C O

2850-2700 -

25G0-2400-2250 -

2100 -

1950 -

1800 -

1650 -

1500 -

1350 -

1200 -

1050 -

900 -

750-600-T=

f4 450 -

g 300-U Unh 150 -

0 pgy

,,3

,,r, Jan92 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec92 1992 Q

Radioactive Waste Buried This Month (in cubic feet)

GOOD Cumulative Radioactive Waste Buried 1200 -

--O--

Fort Calhoun Goal For Waste Burttd (1,000 cubic feet)

O C

C C

C O

900-750-N' 800-i 450-300-

~

150-WE

8 g^'

tj' {'

$~d

'^

0 l

I i

i i

I i

i i

I Jan93 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec93 1993 70

l' E

Radioactive Waste Buried This Month (in cubic feet) 750-Curnulative Radioactive Waste Buried l GOOD l

--O-Fort Calhoun Goal For Waste Buried (500 cubic feet)

V

+

ustry &al(3,884 cuNc feet) 600-

-D-Industry Upper 10% (965.3 cubic feet)

/

C O

O O

450 -

300-b f_

150-b

~

.., _, b Jan94 Feb Mar Apr May Jun94 VOLUME OF LOW-LEVEL SOLID RADIOACTIVE WASTE This indicator shows the volume of the monthly radioactive waste buried, the cumulative annual total for radioactive waste buried, the Fort Calhoun and INPO goals, and the approximate industry upper 10%.

Amount of solid radwaste shipped off site for processing during December (cubic feet) 0.0 Amount of metals from rack cut-up shipped off-site for processing during December (Ibs.)

80,800 Volume of Solid Radwaste Buried during June (cubic feet) 206.0 Cumulative volume of solid radioactive waste buried in 1994 (cubic feet) 543.6 Amount of solid radioactive waste in temporary storage after July 1,1994 (cubic feet) 0.0 The 1994 Fort Calhoun goal for the volume of solid radioactive waste which has been buried is 500 cubic feet. The goal was exceeded in June because OPPD's 18-month goal (established in 1993) allowed the opportunity to further reduce the amount of solid radioactive waste. The 1995 INPO industry goal is 110 cubic meters (3,884 cubic feet) per year. The industry upper ten percentile value from 7/91 through 6/94 is approxi-mately 27.33 cubic meters (965.3 cubic feet) per year.

Data Source: Chase /Breuer (Manager / Source)

Accountability: Chase /Lovett Adverse Trend: Although the 1994 goal was exceeded, this indicator is not exhibiting an adverse trend because Fort Calhoun did not exceed the 18-month goal of 1,500 ft.8 that was established in 1993. The 18-month total for

~

Fort Calhoun was 1,401.4 ft.8 at the end of June 1994.

SEP 54 71 l

E Primary System Chemistry Percent of Hours Out of Umit GOOE 3%-

1I

--O-Fort Calhoun Goal ( 2%)

2%-

C O

O O

O 1%-

Cycle 14 Refueling Outage 0*'.

i i

i Jan92 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec92 1992 i

E Primary System Chemistry Percent of Hours Out of Umit 3%-

GOOE

-O-Fort Calhoun Goal ( 2%)

37 2%-

C O

O O

O C

O

~

Cycle 15 Refueling UU98 0%

i i

Jan93 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec93 1993 72

E Primary System Chemistry Percent of Hours Out of Limit l GOODI

-O-Fort Calhoun Goal ( o.o2)

V 3%-

2%-

O

-O O

O O

O 1%-

01'=

i i

Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 PRIMARY SYSTEM CHEMISTRY PERCENT OF HOURS OUT OF LIMIT The Primary System Chemistry Percent of Hours Out of Umit indicator tracks the pri-mary system chemistry performance by monitoring 6 key chemistry parameters. The key parameters are: lithium, dissolved oxygen, chlorides, fluoride, hydrogen and sus-pended solids.100% equates to all 6 parameters being out of limit for the month.

The Primary System Chemistry Percent of Hours Out of Umit was 0.0% for the month of December 1994.

The 1994 F C alhoun monthly goal for this indicatoris a maximum of 2% hours out of limit.

I Data Source: Smith / Spires (Manager / Source)

Accountability: Chase / Smith Positive Trend

1 l

(This page intentionally left blank. The method of reporting this indicator was revised in 1993.)

i j

1 1

i 74 i

=

E Secondary System CPI lGOODI 1.6 -

-O-Fort Calhoun Goal ( 1.5) 1.5 -

C O

O O

1,4 -

.i %

l

..lll ll&1 Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 SECONDARY SYSTEM CHEMISTRY Criteria for calculating the Secondary System Chemistry Performance Index (CPI) are:

1) The plant is at greater than 30% power; and 2) the power is changing at less than 5%

)

per day.

The CPI for December 1994 was 1.03 due to hydrogen out of specification for 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months .

The year-to-date average monthly CPI value was 1.16 at the end of the month.

The CPI for December 1993 was 1.92. This relatively higher number was due primarily to iron transport following the plant start-up.

l The 1994 Fort Calhoun monthly goal for the CPI is a maximum value of 1.5.

The CPI calculation is different from that reported in 1993 in that it reflects the recent INPO revision to the calculation. This revision addresses the penalties for the beneficial effect of attemative chemistry,i.e., morpholine, such as used at Fort Calhoun Station, and focuses more on specific impurities.

Data Source: Smith / Spires (Manager / Source)

Accountability: Chase / Smith Positive Trend 75

~

l This page intentionally left blank.

COST Goal: To operate Fort Calhoun Station in a manner that cost effectively maintains nuclear generation as a viable source of electricity.

t Actuals

-C}--

Budget 6-5.75-5.5-5.25-5-

4.75-4.5 -

4.25-3.75 3.5 -

3.25-3-

2.75-2.5 Jan92 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec92 1992 The unit price budget in 1992 is unusually high since the rescheduling of the Fall 1991 outage is not accounted for in the 12 - month budget average.

-R-Actuals

-C}- Budget t

Plan 6-5.75 -

5.5 -

5.25-5-

7 75 -

4

=> 4.5 -

4.25 -

c 4_

3.75 -

3.5 -

3.25 -

f 3-2.75 -

2.5 i

i i

i D91 D92 J93 F M

A M

J J

A S

O N D93 D94 D95 D96 D97 1993 78

4-1 Actuals

-O-Budget A

Plan 3.75 -

3.5 -

3.25-5 i

h i

3-2.75 -

l 2.5

,m D92 D93 J94 F M

A M

J J

A S

O N D94 D95 D96 D97 D98 D99 Months CENTS PER KILOWATT HOUR The purpose of this indicator is to quantify the economical operation of Fort Calhoun Station.

The cents per kilowatt hour indicator represents the budget and actual cents per kilowatt hour on a 12 month rolling average for the current year. The basis for the budget curve is the approved 1993 and 1994 revised budget. The basis for the actual curve is the Financial and Operating Report.

i The December 31 amounts are also shown for the prior years 1992 and 1993. In addi-tion, the report shows the plan amounts for the years 1995 through 1999 for reference.

The basis for the dollars are the Nuclear Long Range Financial Plan and the 1994 Corporate Planning and Budget Review. The basis for the generation is provided by Nuclear Fuels.

The unit price (2.62 cents per kilowatt hour for the reporting month) is averaging lower than budget due to expenses being below budget while generation exceeds the budget.

Data Source: Scofield/Jamieson (Manager / Source)

Accountability: Scofield Positive Trend

1 This page intentionally left blank.

a 1

1 1

E Nuclear Services DMsion Staffing O Production Engineering Division Staffing y Nuclear Operations Division Staffing E Total Nuclear Staffing 7

8 7

9 0

7 7

7 8

2 4

3 800-9 3

2 h

3 700-5l i

i 600 -

g 4

j 4

4 4 y 4

4 5 ;

4 3 4

3 8 500-ji i

h l

L d

400-f 7: i l 5

l t :i k*"l l i LI i

i h

b 4

3 7

6 6

4 3

5 5

'I 0

Jan91 Jan92 Jan93 Jan94 Apr94 Jul94 Oct94 Dec94 ACTUAL STAFFING LEVEL (UPDATED QUARTERLY)

STAFFING LEVEL The actual staffing levels for the three Nuclear Divisions are shown on the graph above.

The authorized staffing levels for 1994 are:

1994 Authorized Staffing 452 Nuclear Operations Division 191 Production Engineering Division 115 Nuclear Services Division Data Source: Ponec (Manager & Source)

Accountability: Ponec Adverse Trend: None SEP 24 81

==- Spare Parts inventory Value ($ Million) 17-16-Cycle 14 Refueling 15-Outage 14-1'3 -

12-11 -

10

_. i Jan92 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec92 1992 Cycle 15 Spare Parts inventory Value ($ Million)

Refueling 17-Outage 16-15-14-f 13-12-11 -

10 Jan93 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec93 1993 82

- Spare Parts inventory Value ($ Million) 17-1 1

16-i i

d E

8

'o 15-E2 5

14-13 Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 SPARE PARTS INVENTORY VALUE The spare parts inventory value at the Fort Calhoun Station at the end of December i

1994 was reported as $16,520,462.

Data Source: Steele/Huliska (Manager / Source)

Accountability: Willtett/McCormick Adverse Trer.d: None 1

83

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84

l

\\

DIVISION AND DEPARTMENT j

PERFORMANCE INDICATORS These indicators may be deleted from this report if the responsible group con-tacts the Manager - Station Engineering to request their removal. Indicators referencing SEP ltems require documentation to ensure that the original Intent and scope of the SEP ltem will not be altered by removal of the indicator from this report.

l l

I i

v e--

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86

O Corrective Maintenance 9

Non-Corrective /Plart irnprovements E

Preventive Maintenance

-e-Fort Calhoun Goal i

f 6

800-723 M2 M0 891 700-626 017 l

581 800-500-l 400 -

300 C

p#p 2"-

'T r;

i en rm Jan94 Feb Mar Apr May Jun Jul Aug Sep M

Nov Dec94 Non-Outage Maintenance Work Order Backit.g

[] TotalMWOs G MWOs Which Exceed Maintenance Completion Goals i

400-

{

350 -

216 200-150-100-

>3

>14

>90

>180 50 38 0

18_ 18 days Y8 days E _633 days I i

27Bpuppppgit i

i i

i Priority 1 Priority 2 Priority 3 Priorky 4 Priority 5 Priority 6 l

Non-Outage Maintenance Work Order Aging

+

)

MAINTENANCE WORKLOAD BACKLOGS This indicator shows the backlog of non-outage Maintenance Work Orders remaining open at the end of the reporting month. It also includes a breakdown by maintenance i

classification and priority. The 1994 goal for this indicator has been changed to 400 i

non-outage corrective MWOs. To ensure that the MWO backlog is worked in a timely manner, non-outage maintenance completion goais have been established as:

GQAl Priority 1 Emergency N/A l

Priority 2 Immediate Action 3 days

}

Priority 3 Operations Concem 14 days Priority 4 Essential Corrective 90 days Priority 5 Non-Essential Corrective 180 days L

Priority 6 Non-Corrective / Plant Improvements N/A i

Data Source: Chase /Schmitz (Manager / Source) i j

Accountability: Chase /Faulhaber l

Adverse Trend: None SEP 36 l

This page intentionally left blank.

88

I l

Ratio of Preventive to Total Maintenance

+

100% -

90%-

(

80%-

P 70%-

l

~ j s0%-

50%-

ih,

!$N N

5 h

ih 7

w :

40%- k

@e id D,'

M d

>m

^

e?

7 N

gp gy g

g g

g y

&g

)

y y7 m

30*/. -

4 m.

n m

x n,

g E

5 Ba 2Pi C

3' e

<c W

20%-

MM s

+

@h V

Y W

M W

1' '

sp[;

hi 7,

N ff k

b

' b,',

h

~

I i

e I

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Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 U*-

Preventive Maintenance items Ovardue GOOD

--O-Fort Calhoun Goal V

1%-

o-5-_c p_

p_

_o -o - c c

o

.o.-o ri n

n o.,,

i i

Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 RATIO OF PREVENTIVE TO TOTAL MAINTENANCE &

PREVENTIVE MAINTENANCE ITEMS OVERDUE The top graph shows the ratio of completed non-outage preventive maintenance to total completed non-outage maintenance.

The ratio of preventive to total maintenance was 53.7% for the month of December 1994. The trend of this ratio reflects the revised definition of corrective maintenance which was implemented in March.

The !ower graph shows the percentage of preventive maintenance items overdue.

During December,526 PM items were completed.1 of these PM items (0.19% of the total) was not completed within the allowable grace period or administratively closed.

The 1994 Fort Calhoun monthly goal for the percentage of preventive maintenance items overdue is a maximum of 0.5%

Accountability: Chase /Faulhaber Data Source: Chase /Schmitz/Meistad (Manager / Sources)

J Positive Trend SEP 41

~l as j

J

E Rework As identified By Planning or Craft

--O-1993 Fort Calhoun Goal (<4.0%)

5%-

g4%-

O O

h3%-

ihi i lil;l;l.l 1:

i 0%

i i

i g

i Feb93 Mar 93 Apr93 May93 Jun93 Jul93 Aug93 Sep93 Oct93 Nov93 Dec93 2

90

1 E

Rework As identifed By Planning or Craft I

-O-Fort Calhoun Goal (>3%)

5%-

4%-

o S

3.33 %

y 3.16%

g M-C O

O O

q 2.43 %

2.44 %

0 o2%-

'E 1.58 %

1%-

0.6%

E 0*,u i

i i

Jun94 Jul Aug Sep Oct Nov Dec94 PERCENTAGE OF TOTAL MWOs COMPLETED l

PER MONTH IDENTIFIED AS REWORK This graph indicates the percentage of total MWOs completed per month identified as rework. Rework activities are identified by maintenance planning and craft.

The 1994 Fort Calhoun monthly goal for this indicator is <3%.

l l

Data Source: Faulhaber/Schmitz (Manager / Source)

Accountability: Chase /Faulhaber Adverse Trend: None l

l i

=

l 80%-

E Maintenance Overtime 70%-

--M-12 Month Avera0e Maintenance Overtime GOOC i

60%-

--O-1992 Fort Calhoun "On-Line" Goal V

50%-

1 Jan92 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec92 1992 80%-

E Maintenance Overtime GOOC 70%-

-M--

12 Month Average Maintenance Overtime y

'"~

60%-

50%-

40%-

i A;;i',

.. ;.i.

0%

i i

Jan93 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec93 1993 92

. ~.

i 80%-

M uaintenance overtime

-M--

12 Month Average Maintenance Overtime IGOODI D-

--O-Fort Calhoun "On-Une" Goal ( 10%)

60%-

50%-

40%-

30%-

20%~

M M

M-u a

u u

6 S

3 d

O O

eimuuuI;.i;iii 10%-

^

D%

i i

i Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 MAINTENANCE OVERTIME The Maintenance Overtime Indicator monitors the ability to perform the desired mainte-nance activities with the allotted resources.

The percent of overtime hours with respect to normal hours was reported as 2.86% for the month of December 1994. The 12-month average percentage of overtime hours with respect to normal hours was reported as 5.37% at the end of the month.

The 1994 Fort Calhoun monthly "on-line" goal for this indicator is a maximum value of 10%.

Data Source: Chase /Schmitz (Manager / Source) l Accountability: Chase /Faulhaber

.I Adverse Trend: None 93

O Open irs Related to the Use of Procedures (Maintenance)

@ Closed irs Related to the Use of Procedures (Maintenance)

E Procedural Noncompliance irs (Maintenance) 10-S g.

8-7-

6-5-

4 4

4_

3 3-2-

1 1

11 1

1 11 1

1 1-0 0

0 0

0 0 0 0 00 00 0

00 00 i

i i

i Jan92 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec92 1992 O Open irs Related to the Use of Procedures (Maintenance)

@ Closed irs Related to the Use of Procedures (Maintenance) 10-E Procedural Noncompliance irs (Maintenance) 9-8-

7-6-

5-4-

3-2-

j 1

1 1

1-0

' 0 00 000 000 000 000 000 000 00 000 000 000 O f

i i

Jan93 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec93 1993 94

O OpenIRs Relatedtothe Useof Procedures (Maintenance)

@ Closed irs Related to the Use of Procedures (Maintenance)

E Procedural Noncompliance irs (Maintenance) 2-1 1

15 1

i_

000 000 00 00 000 000 000 000 0

000 000 i

i i

e i

i e

i Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 PROCEDURAL NONCOMPLIANCE INCIDENTS (MAINTENANCE)

This indicator shows the number of open Maintenance incident Reports (irs) that are related to the use of procedures, the number of closed irs that are related to the use of procedures, and the number of open and closed irs that received procedural noncom-pliance cause codes for each of the last twelve months.

There was one procedural noncompliance incident for maintenance reported for the month of Decem'>er 1994.

There was ole procedural noncompliance incident (IR 940323) for maintenance re-ported for tha month of September 1994. The IR was written to document procedural noncompliance that occurred when a mercury thermometer was used, rather than the required abohol thermometer, during a surveillance test.

Data Source: Chase (Manager)

Accountability: Chase / Conner Adverse Trend: None SEP 15,41 & 44 95

E Completed Scheduled ActMties (All Crafts)

O Numberof Emergent MWOs Completed en

.* 100%-

110 T

k #~

100]*

0 0

90 ~ci l 80%-

- 80 b

@ 70%-

3 O

e E 60%.

70 g

/{

- 60 g 50%-

h 4og_

- 40 h 48

- 50 e

3 34 e

r 30%-

- 30 E c3 g 2W-fj

- 20

[I

'O 5 10% -

l dz S:

SS-

/

g 3

y

.o g

0%-

January February August September'94 N

r 3 CompletedS@eduled Activities (AlCrafts)

D Numberof EmergentMWOsCompleted

--O-Fort Calhoun Goal (80%)

110 100g y 90%-

- 90 5o.

E g 80%-

C O

O O

80 U

E 70%-

7n b S

61 55 54 77) 60 h O'

j 50 g f

.g 40%-

% Completed

% Complehd ((:

% Completed

/

- 40 g 34 e

Scheduled Scheduled Schedu'l

//'

SchMuld

E 30%-

ActMties Not ActMties Not Activities Not ((:

Activees Not,((h W

Avaiable Available

ff:

Available 20%-

Available 20 o E

. /

/

'//

d

'99, i ' 5-s'js fj!

iss!

ijf

~'

E

?

??

g

.n O

September October November December 94 PERCENT OF COMPLETED SCHEDULED MAINTENANCE ACTIVITIES (ALL MAINTENANCE CRAFTS)

This indicator shows the percent of the number of completed scheduled maintenance activities as compared to the number of scheduled maintenance activities concerning all Maintenance Crafts. Maintenance activities include MWRs, MWOs, STs, PMOs, cali-brations, and miscellaneous maintenance activities. The number of emergent MWOs completed for the month is also shown.

The percent of the number of completed scheduled maintenance activities as compared to the number of scheduled maintenance activities for the months of July, August, September and October 1994 are not available due to the software and data collection method changes involved with the implementation of the Integrated Plant Schedule.

There were 61 emergent MWOs completed during the month of December.

The 1994 Fort Calhoun monthly goal for completed scheduled mair. enance activities is 80%.

Data Source: Chase /Schmitz (Manager / Source)

Accountability: Chase /Faulhaber Adverse Trend: None SEP 33 1

i 97 l

l

e l

This page intentionally left blank. The method for calculations this performance Indicator has changed.

l O

I

E

% of Hours the in-Line Chemistry instruments are Inoperable 12-

--O-1994 Fort Calhoun Goal (10%)

11-10-C O

O O

9-8-

7-E 6-5-

h dI II 4-E O

i i

Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 IN-LINE CHEMISTRY INSTRUMENTS OUT-OF-SERVICE This indicator shows the percentage of hours the in-line chemistry system instruments are inoperable for the reporting month. The chemistry systems involved in this indicator include the Secondary System and the Post Accident Sampling System (PASS).

At the end of December 1994, the percentage of hours the in-line chemistry system instruments were inoperable was 3.59%

The entire instrument channel is considered inoperative if: 1) the instrument is inopera-tive, 2) the chart recorder associated with the instrument is inoperative, or 3) the alarm

(

function associated with the instrument is inoperative. If any of the functions listed above are not operational, then the instrument is not performing its intended function.

The 1994 Fort Calhoun monthly goal for this indicator is a maximum of 10% in-line chemistry instruments inoperable. 5 out-of-service chemistry instruments make up 10%

of all the chemistry instruments that are counted for this indicator.

Data Source: Chase /Reneaud (Manager / Source) l Accountability: Chase /Jaworski Positive Trend m

1

2 Waste Produced Each Month (Kilograms)

- Monthly Avera0e Waste Produced During the Last 12 Months (Kilograms)

)

--O-Federal & State Monthly Umit (Max. of 1,000 Kg) j 1000-C O

O O

800-m 600-400-200-0

,~~'"',

Jan92 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec92 1N2 5

Waste Produced Each Month (Kilograms)

Monthly Avera0e Waste Produced During the Last 12 Months (Kilo 0 rams)

-O-Fort Calhoun Monthly Average Goal ( 100 Kg) 1 Federal & State Monthly Umit (Max, of 1,000 Kg) 1000-

=

800 -

$ 600-e3g 400-200-O-h --C O

C

-O C

O-C O

O Jan93 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec93 1993 100

~

Waste Produced Each Month (Kilograms)

Monthly Average Waste Produced During the Last 12 Months (Kilograms)

-O-Fort Calhoun Monthly Average Goal (100 kilograms)

-B - Federal & State Monthly Limit (Max. of 1,000 Kg) 1000-

=

800 -

E 600 -

E Hg 400-200 -

C O

O--

--C O

O O

O---

-n 0

1 I

I I

i e

i i

i Jan Feb Mar Apr May Jun Jul Aug Sep Oct (dov Dec94 HAZARDOUS WASTE PRODUCED This indicator shows the total amount of hazardous waste produced by the Fort Calhoun Station each month, the monthly average goal and the monthly average total for hazard-ous waste produced during the last 12 months. This hazardous waste consists of non-halogenated hazardous waste, halogenated hazardous waste, and other hazardous waste produced.

During the month of December 1994,0.0 kilograms of non-halogenated hazardous waste was produced,0.0 kilograms of halogenated hazardous waste was produced (this waste was unusable morpholine generated after the station switched to using ethanolamine), and 0.0 kilograms of other hazardous waste was produced. The total for hazardous waste produced during the last 12 months is 958.8 kilograms. The monthly average for hazardous waste produced during the last 12 months is 79.9 kilograms.

Hazardous waste is counted based upon a full drum of waste.

The 1994 Fort Calhoun monthly average goal for hazardous waste produced during the last 12 months is a maximum of 100 kilograms.

Data Source: Chase / Smith (Manager / Source)

Accountability: Chase / Smith Positive Trend

,g

1--O-FortCalhounGoal(noneutagemonths)

M contaminated Radiation Controlled Area GOOC 15%-

y Jan92 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec92 1992 E

Contaminated Radiation Controlled Area

--O-Fort Calhoun Goal (noneutage months) y 12%-

C O

O O

i i

=

-w,

E Contaminated Radiation Controlled Area 15%-

l GOOD l

-O--

Fort Calhoun Goal (non-outage rnonths)

V

- O-Fort Calhoun Goal (outage months) l 12%-

C O

O O

9%-

6%-

3%-

0%

i i

i Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 CONTAMINATED RADIATION CONTROLLED AREA This indicator shows the percentage of the RCA that is contaminated based on the total square footage. The 1994 monthly non-outage goalis a maximum of 10% contami-nated RCA and the monthly outage goalis a maximum of 13% contaminated RCA.

At the end of December 1994, the percentage of the total square footage of the RCA that was contaminated was 9.4%.

Data Source: Chase /Gundal(Manager / Source)

Accountability: Chase /Lovett Positive Trend SEP54 103 I

1 30-

-*-- Number of identified PRWPs GOOE 2S -

-O-Fort Calhoun Non-Outage Goal y

e

.f 20-n.

Eo3

]15-Ho I

tr 10-C O

O O

5 n.

Cycle 15 Refueling S_

Outage L

0 Jan93 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec93 1993 104

l'

-o--

Number of Iderdied PRWPs Year-To-Date IGOODI 30-

-O--

1994 Fort Calhoun Goal (<25)

V

25 -

C C

C O

.h D 20 -

b I'

a

]15-3 0

j10-0" g

n.

5-0

~

Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 RADIOLOGICAL WORK PRACTICES PROGRAM The Radiological Work Practices Program Indicator shows the number of Poor Radio-logical Work Practices (PRWPs) which were identified during the reporting month.

The number of PRWPs which are identified each month should indirectly provide a means to qualitatively assess supervisor accountability for their workers' radiological performance.

During the month of December 1994, there were no PRWPs identified.

There have been 7 PRWPs in 1994.

The 1994 year-end goal for the number of PRWPs is a maximum of 25.

Data Source: Chase /Little (Manager / Source)

Accountability: Chase /Lovett Adverse Trend: None SEP 52 l

l 105 l

l

O Documenissen duiedforneview B Documents Reviewed 3 Overdue Documents 600-500 M-300-200-100-A h "

r r

3 0

i 1

l 1

Jan92 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec92 1992 4

O Documents sen dui dforReview B Documents Reviewed E Overdue Documents

[

600-500-400-l 300-200-100-E

- 3

_F d

r

)

l

,r F

!_ff._

~

0 Jan93 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec93 106 1993

i O 'Documerds Scheduled for Review E Documents Reviewed E Overdue Docurnerds 350 -

300 -

250 -

200 -

150 -

/

3 100 -

50-z

/

E 0

Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 i

DOCUMENT REVIEW 4

This indicator shows the number of completed, scheduled, and overdue (greater than 6 months past the scheduled due date) biennial reviews for the reporting month. These document reviews are performed in-house and include Special Procedures, the Site Security Plan, Maintenance Procedures, Preventive Maintenance Procedures, and the Operating Manual.

During December 1994 there were 53 document reviews scheduled, while 63 document reviews were completed. At the end of the month, there were 19 document reviews more than 6 months overdue.

There were 12 new documents initiated in December.

Data Source: Chase (Manager)

Accountability: Chase /Jaworski Adverse Trend: None SEP 46 107

30-E Non-System Failures 25-

~

12 12

'N Jan93 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec93 j

1993

@ System Failures 2:

~

24 25 26 30 32 h B, E, ll s, s, E, E, E, E, l31l5 4

30 31 Jan93 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec93 1

1993 E Non-System Failures 30-25-39 J

20-14 5

2 3

2 2

2 0-Jan92 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec92 1992

@ System Failures 90-80-72 70-60-52 47 50-43 33 33 34 40-

!!E

'd E,i,B,e,i,B,id, Jan92 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec92 1992 108

E Non-System Failures 16-14-Y 12-10 10-8-

6-5 5

4 4

4 0

i i

Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 60 -

@ System Failures l GOOD l 50-y 40-30-26 23 9

h 16 17 17 f

20-15 h,

,h,b b,b b

'~

0 Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 l

LOGG ABLE/ REPORTABLE INCIDENTS (SECURITY)

The Loggable/ Reportable Incidents (Security) Indicator is depicted in two separate graphs. The top graph depicts the total number of loggable/ reportable non system failures concerning Security Badges, Access Control and Authorization, Security Force Error, and Unsecured Doors. The second chart shows the total number of loggable/

reportable incidents conceming system failures which occurred during the reporting month.

During the month of December 1994, there were 22 loggable/ reportable incidents identi-fied. System failures accounted for 17 (77%) of the loggable/ reportable incidents.11 of the 17 system failures were environmental failures due to poor weather conditions.

Non system failures included 2 unattended security doors (not properly closed after entry / exit),1 access controlincident (visitor entered PA before escort), and 2 security force error incidents (during vehicle processing). Through December 1994, system and non-system failures continued on a significant downward trend compared to 1993.

Data Source: Sefick/Woerner(Manager / Source)

Accountability: Sefick Adverse Trend: None SEP 58 109

M Temporary Modifications >1 cycle old (RFO required for Rornoval) t Ternporary Modifications >6 rnonths old (Removable on-line) a

- O-Fort Calhoun Goal for Temporary Modificatioris >1 cycle old (0) 8-7 j

7./

'/

6-

',y/

5 7/

4 4

7 4.

Z 7

l[

j 7

4-3 O

/s

/.

Y

'h

/s

/.

/

'/

7 C

/s

/

'/

/s

//

/.

/

'/

2

'/

2 2

2

/,;

/-

2 p.

'p/

p

's

'/

7 7

j 2-

/

'/

/

/s

/,

/.

'/

/

'/

,/

b

/s

/,

J.

/

'/

/

//

/s

/,

/.

/

'/

/

'/

/

'/

.'/

s

//

/,

/

'/

't M

0-q Jan93 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec93 9

110

~

-. _ - _ ~ _. _ - -,

p 3

Ternporary Modifications >1 cycle old (RFO required for Removal)

G Temporary Modifications >6 months old (Removable on-line)

--O--

Fort Calhoun Goal for Temporary Modifications >1 cycle old

--O--

Fort Calhoun Goal for Temporary Modifications >6 months old h

5 4

4 4

j:

W B%%%d B%%%1 m%%1 September 94 October 94 November 94 December 94 TEMPORARY MODIFICATIONS This indicator provides information on the number of temporary modifications greater than one fuel cycle old requiring a refueling outage (RFO) for removal and the number of temporary modifications removable on-line that are greater than six months old. In addition, the 1994 Fort Calhoun monthly goals for this indicator are zero, however, specific temporary modifications have been approved by management to exceed these t

goals due to cost effectiveness considerations. These are listed below.

There is currently 1 temporary modification that is greater than one fuel cycle old requir-ing a refueling outage to remove: Epoxy repairs to ST-4B, which is awaiting completion of MWO 931325, scheduled start date 1995 Refueling Outage. This temporary modifi-cation was previously included in the on-line removable >6 months old classification, but was re-classified as an outage modification to save engineering resources from com-pleting 1 ECN to allow the epoxy repair to remain in place and a second ECN to remove it during the 1995 refueling outage. In addition, at the end of December 1994 there were 4 temporary modifications installed that were greater than six months old that can be removed on-line. These were: 1) Local indication for BAST CH-11 A and CH-11 B, in which Operations is reviewing a draft FLC. After review, Licensing is to issue an FLC, and the NRC is to approve; 2) Swap leads for DG-1 shutdown solenoid, which is awaiting completion of MWO 941809, scheduled for the next DG-1 outage; 3) Replace FP-156 with new design plug valve, which is awaiting the completion of MR-FC-92-019, scheduled for issue 1/13/95; and 4) Rubber patch on surface sluice line, which is await-ing completion of MWO 940774, has been re-scheduled for 10/16/95.

Currently,1 temporary modification associated with the surface sluice line is over the goal of 6 months. The other 3 are exceptions to the goal as described in letter PED-STE-94-042.

At the end of December 1994, there was a total of 30 TMs installed in the Fort Calhoun Station.16 of the 30 installed TMs require an outage for removal and 14 are removable on-line in 1994 a total of 46 temporary modifications have been installed.

Data Source: Jaworski/ Turner (Manager / Source)

Accountability: Jaworski/Gorence Adverse Trend: None SEP 62 & 71 111 1,

350-300-E Total Modification Packages Open 250 -

I" 200-189 179 176 173 172 i

i i

Jan92 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec92 1992 350-al na ages @ en 300-O 1993 Fort Calhoun Monthly Goal ( 150) 250-i 200 -

f 193 O

O O

O 150 -

136 126 125 126 04 103 100 d

100 i

i l

i i

Jan93 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec93 1993 112

E Total Modifcation Packages Open 264

-O-Fort Calhoun Year-End Goal 250 -

200-150-127 100 t

'91

'92

'93 Jan Feb Mar Apr May Jun Jul Aug sep Oct Nov Dec04 OUTSTANDING MODIFICATIONS This indicator shows the total number of outstanding modifications (excluding outstand-l ino modifications which are oronosed to be cancelled).

Cataoorv Reoortino Month Form FC-1133 Backlog /In Progress 2

Mod. Requests Being Reviewed 2

Design Engr. Backlog /In Progress 25 Construction Backlog /In Progress 21 i

Deeinn Enor. Undata Raekloo/in Proora==

0 Total - 50 At the end of December 1994,24 additional modification requests had been issued this year and 41 modification requests had been cancelled. The Nuclear Projects Review Committee (NPRC) had completed 132 backlog modification request reviews this year.

The Nuclear Projects Committee (NPC) had completed 63 backlog modification request reviews this year.

l The 1994 year-end Fort Calhoun goal for this indicator is a maximum of 80 outstanding modifications.

Data Source: Jaworski/Tumer (Manager / Source)

Scofield/Lounsbery (Manager / Source)

Accountability: Scofield/Phelps Adverse Trend: None

=

This page intentionally left blank.

114

l EARS Requiring Engineering Closeout - Not in Clooeout O DEN E SE 70-60-50-40-40-40-4 30-30-30-3 20 -

20-20-20-10-10-10-10- g qq 4

o o

o o-a i

i a

e i

i Oct Nov Dec Oct Nov Dec Oct Nov D'

Oct Nov Dec 0-3 monthe 3-6 months 6-12 months

>12 months December 1994 Overdue EARS E Clomeout(SE)

O Engineering Response 80-60-40-

~~~

20-p 0

Priority 0 Priority 1 Priority 2 Priority 3 Priority 4 Priority 5 Priority 6 O

Priority 1 & 2 D

Priority 3 Total Open EARS 200 -

ISO-100-b!

~

i e

i i

e i

Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Deco 4 O ss Ov.rdue Responses

@ 63 EARS Resolved and in Closeout E 61 Overdue Closeouts O 111 EARS Requiring Response 8 28 EARS on Schedule I,,

48.9%

\\

[

36.2%

ll llllI 63.8 %

16.1 Y ENGINEERING ASSISTANCE REQUEST BREAKDOWN I

This indicator shows a breakdown of the number of EARS assigned to Design Engineer-ing and System Engineering. The 1994 year-end goal for this indicator is a maximum of 140 outstanding EARS.

Total EAR breakdown is as follows:

EARS opened during the month 12 EARS closed during the month 9

l Total EARS open as of the end of the r.anth 174 1

l Data Sourca: Skiles/Mikkelsen (Manager / Source)

Accountability: Jaworski/Skiles Adverse Trend: None SEP 62 115 i

m

E in DtN = 167 5 0-3 Morths - 235 27.

.1%

O in System Engineering - 106 O 3-8 Mornha - 115 O in ProcuremenvConstr. - 128 3is 0.7%

O >s Mornha - 205 19.1 %

@ in CM - 154 ECN STATUS OVERALL BACKLOG I

E ECNsBacklogged O ECNs Received During the Month

@ ECNs Completed During the Morth 250 -

E 0-3 Months - 80 9

12 8. 7 %

200 -

l 7.9%l D 3-6 Months - 39 150 -

O >6 Months - 48 Jul Aug Sep Oct Nov Dec94 (Year-to-Date monthly average of ECNs received was 39)

ECN STAT 1JS - DEN 250 -

200-g E 0-3 Months - 31 150-nt s = 5 15.1 %

Jul Aug Sep Oct Nov Dec94 ECN STATUS SE 250-200 -

g E 0-3 Manths - 42 150-O 3-8 Months.24 100 -

148.4%

5-

s 0 >6 Months - e2 0

18.8%

Jul Aug Sep Oct Nov Dec94 ECN STATUS PROC /CONSTR 250 -

g ILkLht.L@iE.E Jul Aug Sep Oct Nov Dec94 ECN STATUS CLOSEOUT ENGINEERING CHANGE NOTICE STATUS Data Source: Skiles/Mikkelsen (Manager / Source)

Accountability: Skiles/Jaworski Adverse Trend: None SEP 62 116

l E FC Type - 186 E Priority 1 & 2 - 111 0.4 27.0%

$ SRI Type - 256 L

S Priority 3 & 4 - 300

.1%

O DC Type - 113

(

84s: /

O Priorky 5 & 6 - 143 w

TOTAL OPEN ECNS BY TYPE (554 TOTAL)

TOTAL OPEN ECNe BY PRIORITY (554 TOTAL)

O DEN - Engineering Not Complete

@ System Engineering Response, Confirmation Not Complete Q Maintenance / Construction / Procurement - Work Not Complete E DEN - Closeout or Drafting Not Complete 250 -

1#

187 186 200 -

8 150 -

22.6,, 15.%

B Norny 1 or 2 100 -

8 Priorky 3 or 4 83.

50-O Priority 5 or 6

\\

51 V

0-g g

t-Jul Aug Sep

.x Nov Dec94 i ec 6ty Change ECNs Open 247 230 N

255 N

E Priority 1 or 2 150 -

67

@ Priority 3 or 4 M61.7%d O Priority 5 or 6 100 -

45 0-g i

Jul Aug Sep Oct Nov Dec94 Substitute Replacement item ECNs Open 250 -

200 188 150 -

112 E Priority 1 or 2 m

100-51 l

@ Priority 3 or 4 62.0 %

O Priorty 5 or 6 Jul Aug Sep Oct Nov Dec94 Document Change ECNs Open ENGINEERING CHANGE NOTICES OPEN Data Source: Skiles/Mikkelsen (Manager / Source)

~

Accountability: Skiles/Jaworski Adverse Trend: None SEP 62 117

Q Ac'n ;nistrative Control Problem O Licensed Operator Error S Other Personnel Error G Maintenance Problem E Design / Construction / Installation / Fabrication Problem E Equipment Failures 4-3-

2-1-

g y

i i

i 4

4 i

i i

I a

iii Jan92 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec92 1992 l

I O Administrative Control Problem i

O Licensed Operator Error

@ Other Personnel Error 5-

@ Maintenance Problem E Design / Construction / Installation / Fabrication Problem 4-

@ Equipment Failures 3-2-

1-I i

i l I-I

~

i iiiie i

i i

iii Jan93 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec93 1993 118 C

O Administrative Control Problem O Licensed Operator Error

@ Other Personnel Error S Maintenance Problem l

3-E Design / Construction / Installation / Fabrication Problem E Equipment Failures 1

i 2-l

-=

=

1-E E

l 5

5 j

E E

1 0

i i

5 5

E b

LICENSEE EVENT REPORT (LER) ROOT CAUSE BREAKDOWN l

This indicator shows the LERs by event date broken down by Root Cause Code for l

each of the past twelve months from December 1,1993, through November 30,1994.

To be consistent with the Preventable / Personnel Error LERs indicator, this indicator is reported by the LER event date, as opposed to the LER report date.

1 The cause codes are intended to identify possible programmatic deficiencies. For detailed descriptions of these codes, see the "Performcnce Indicator Definitions" section of this report.

There were three events in November 1994 that resulted in an LER.

Data Source: Trausch/Cavanauth (Manager / Source)

Accountability: Chase Adverse Trend: None 119

l O Total Requalification Training Hours Simulator Training Hours 60 -

Non-Requalification Training Hours Numberof Exam Failures 50-as 36 as as 30 30 30 -

3 20 -

14 14 14

~~

~

11 10 10 6

5 4

4 4

3 h'J

-t

?',

~f l

f Qo o

o 0-Cycle 921 Cycle 92-2 Cycle 92-3 Cycle 92-4 Cycle 92-5 Cycle 92-6 Cycle 92-7 1992

' Note: The Simulator was out-of-service for maintenance and modificationsduring Cycle 92-7.

Total Requalification Training Hours Simulator Training Hours Non Requalification Training Hours 50-Numberof Exam Failures 40-3 33 33 33 33 30-27 20-14 14 14 13 3

~

k 10-7 7

8 7

7

/, 3 7

2 4

3 2

l 0

i Cycle 931 Cycle 93-2 Cycle 93-3 Cycle 93-4 Cycle 93-5 Cycle 93-6 1993 120

O TotalRequalificationTraining Hours O simuistorTraining Hours so D Non-RequalificationTrainingHours

$n 50 -

E Numberof Exam Failures z

E E

E 32 I

8 30 -

222 20 -

=

n h

5

~

14 i

g l

g n"

E 6

7.

,g_

j 2

s' '

w s

as a

V 7)'

9' V

7)1 '

9 o

o g

i i

Cycle M-1 Cycle M-2 Cycle 94-3 Cycle 94-4 Cycle 94-5 Cycle 94-6 C@ 94-7

Note 1: The Simulator was out-of-service during Cycle 94-4.

Note 2: Includes 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months of General Employee Training.

LICENSED OPERATOR REQUALIFICATION TRAINING This indicator provides information on the total number of hours of training given to each crew during each cycle. The Simulator training hours shown on the graph are a subset of the total training hours. Non-Requalification Training Hours are used for AOP/EOP verification & validation, INPO commitments, GET, Fire Brigade, Safety Meetings, and Division Managerlunches.

Exam failures are defined as failures in the written, simulator, and Job Performance Measures (JPMs) segments of the Licensed Operator Requalification Training.

Rotation 94 6 was the annual Requalification Examination rotation. There were 2 crew simulator failures and 1 written examination failure. The crews that failed the simulator evaluation were remediated without impacting the Operations Department shift sched-ule, as was the individual who failed his written examination.

Data Source: Gasper /Guliani (Manager / Source)

Accountability: Gasper /Guliani Adverse Trend: None SEP 68 121

Total Requalification Training Hours Simulator Training Hours 60 -

Non-Requalification Training Hours Numberof Exam Failures l

50 -

i 40-3e as 36 as 1

so 30 l

30-l 25 1

)

20-l 14 14 14 11 to 10 10-a n

6 6

- /

4

^

5

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Cycle 92-1 Cycle 92-2 Cycle 92-3 Cycle 92-4 Cycle 92-5 Cycle 92-6 Cycle 92-7 1992

Note: The Simulator was out-of-service for maintenance and modificationsduring Cycle 92-7.

Total Requalification Training Hours i

Simulator Training Hours 60 -

t i

Non-Requalification Training Hours

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Numberof Exam Failures 40-33 33 33 33 30-27 20-14 14 14 93 3

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i Cycle 93-1 Cycle 93-2 Cycle 93 3 Cycle 93-4 Cycle 93-5 Cycle 93-6 1993 122

O SRO Exams Administered O SRO Exams Passed E RO Exams Administered i

O RO Exams Passed 20-I 15-5 I.

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i Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 l

LICENSE CANDIDATE EXAMS This indicator shows the number of Senior Reactor Operator (SRO) and Reactor Opera-tor (RO) quizzes and exams taken and passed each month. These internally adminis-tered quizzes and exams are used to plot the SRO and RO candidates' monthly progress.

In December 1994, tMrs were 14 SRO exams administered and 13 of these exams were passed. In acdition, there were 8 RO examinations administered and all of these exams were passed..

Data Source: Gasper /Guliani(Manager / Source)

Accountability: Gasper /Guliani Adverse Trond: None SEP 68 123

i G SRO Exams Administered O sRO Exams Passed 35-3 RO Exams Adtninistered 30-O RO Exams Passed 25 -

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OPEN CORRECTIVE ACTION REPORTS AND INCIDENT REPORTS l

This indicator shows the total number of open Corrective Action Reports (CARS), CARS

>6 months old, the total number of Open irs, irs >6 months old, the number of open significant CARS and the number of open significant irs.

At the end of December 1994 there were 58 open CARS.17 of these CARS were greater than 6 months old. There were 7 Open Significant CARS at the end of the month.

l

/.lso, at the end of December there were 323 open irs.191 of these irs were greater than 6 months old. There were 75 Open Significant irs at the end of the month.

The 1994 monthly goal for the number of CARS greater than 6 months old is less than 30.

Data Source: Orr/Gurtis (Manager / Source) & CHAMPS Accountability: Andrews/Gambhir/ Gates Adverse Trend: Although the number of irs has been increasing, an adverse trend is not indicated because the increase is a result of a revision to Standing Order R-4 that lowers the threshold for writing irs and requires completion of all corrective actions prior to closing irs.

125

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126 Engineering Hold

-+- Planning Complete

-O-Planning Hold Ready

-V-Part Hold Total 850 -

800 -

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i Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94Jan95 Feb Mar 95 j

MWO PLANNING STATUS (CYCLE 16 REFUELING OUTAGE)

This indicator shows the total number of Maintenance Work Requests (MWRs) and Maintenance Work Orders (MWOs) that have been approved for inclusion in the Cycle 16 Refueling Outage. This graph indicates:

Parts Holds (part hold removed when parts are staged and ready for use)

Engineering Holds (Engineering hold removed when appropriate engineering paper-work or support is received for the package) l Planning Holds (Planning hold removed when planning is completed to the point when package is ready or other support is necessary to continue the planning process) l Planning Complete (status given when only items keeping the job from being ready to work are parts or engineering support)

Ready (status when all planning, supporting documentation, and parts are ready to go)

Data Source: Chase /Schmitz (Manager / Source)

Accountability: Chase /Faulhaber Adverse Trend: None SEP 31 127

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1995 OUTAGE MODIFICATIONS

-+-- Baseline Schedule for PRC Approval

- -. Projected / Actual Schedule for PRC Approval 20-Final Design Package issued 3

l Total Modification Packages (19) (5 added after 1/14/94) 2 15-llllllllllllllllllllllllllll': 'll'l': lllllll g

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PROGRESS OF CYCLE 16 OUTAGE MODIFICATION PLANNING (FROZEN SCOPE OF 13 MODIFICATIONS)

This indicator shows the status of modifications approved for installation during the Cycle 16 Refueling Outage. The data is represented with respect to the baseline schedule (established 1/14/94) and the current schedule. This information is taken froa the Modification Variation Report produced by the Design Engineering group.

In December 1994,1 modification was added and none were deleted.

The goal for this indicator was to have all modification packages identified prior to 1/14/

94 and PRC approved by October 15,1994. 5 modifications were added after 1/14/94 and one is not included in this performance indicator. The 5 modifications are sched-uled and will not impact 1994 on-line construction.

This performance goal was achieved on 9/12/94.

Data Source: Skiles/Ronne (Manager / Source)

Accountability: Phelps/Skiles Adverse Trend: None 130

l i

I 1994 ON-LINE MODIFICATIONS

--+-- Baseine Sdedule for PRC Approval Projected / Actual Schedule for PRC Approval Final Desi0n Packa0e issued (7 FD DCPs issued prior to 1/14/94) f20-l Total Modification Packa0es (18) (2 are Close Out Only) (2 Added after 1/14/94) g

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PROGRESS OF 1994 ON-LINE MODIFICATION PLANNING (FROZEN SCOPE OF 14 MODIFICATIONS)

This indicator shows the status of modifications approved for on-line installation during 1994. The data is represented with respect to the baseline schedule (established 1/14/

94) and the current schedule. This information is taken from the Modification Variance Report produced by the Dosign Engineering Nuclear group.

In December 1994,1 modification was added and none were deleted The goal for this indicator was to have all modification packages identified prior to 1/14/

94 and PRC approved by August 15,1994, 2 modifications were added after 1/14/94 and is not included in this performance indicator. The modifications are scheduled and wi:1 not impact the 1995 outage.

This performance goal was achieved on 9/12/94.

Data Source: Skiles/Ronne (Manager / Source)

Accountability: Phelps/Skiles Adverse Trend: None 131

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ACT ON PLANS

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i ACTION PLANS i

This section lists action plans that have been developed for the performance indicators cited as Adverse Trends during the month preceding this report. Also included are Action Plans for indicators that have been cited in the preceding month's report as Needing increased Management Attention for 3 consecutive months.

In accordance with Revision 3 of NOD-OP-37, the following performance indicators would require action plans based on 3 consecutive months of performance cited as "Needing increased Management Attention":

. Unplanned Automatic Reactor Scrams Per 7,000 Critical Hours i

Unplanned Safety System Actuations (INPO and NRC)

The Plant Manager and Station Engineering Manager have reviewed the daily and ongoing actions being taken to return these performance indicators to meeting the goals. This review indicates appropriate action is being taken and no explicit action plan is required.

The action plan for Fuel Reliability indicator (page 25) follows:

1) The prediction that there is a potential for 1 or 2 defective fuel rods in the core is based on a change in the Xe-133 to 1-131 ratio. The power reduction in late October was unable to provide any conclusive data.

2) A specification will be prepared for Ultrasonic Testing / Fuel Sipping during the next refus!ing outage.

The action plan for Violations Por 1,000 inspection Hours (page 33) follows:

1) The number of inspections (and thus exposure to potential violations) currently scheduled for the remainder of the year is much less than the first half of 1994 (SALP period ended 7/31/94). Only the SWOPl and Resident inspections are currently scheduled.

2) Pursuit of Resident inspector concems/ problems / issues will be thorough to preclude them from becoming violations.

3) Preparation for scheduled inspections (e.g. SWOPI) will be thorough and comprehensive.

133

. ACTION PLANS (cantinued)

The action plan for Thermal Performance (page 61) follows:

Actions to improve Thermal Performance are:

1) Backwash durations have been lengthened over the weekends to improve condenser performance.

2) Investigate the possibility of FW flow nozzle fouling. Test equipment was installed at the beginning of October.

3) Investigate the effects of adding Ethanolamine to secondary chemistry to clean system and possibly reduce S/G blowdown.

t J

b

PERFORMANCE INDICATOR DEFINITIONS AUXILIARY FEEDWATER SYSTEM SAFETY SYSTEM approved 1993 budget. The basis for the actual curve is PERFOfM4ANCE the Financial and Operating Report.

The sum of the known (planned and unplanned) unavail-able hours and the estimated unavailable hours for th*

CLEAN CONTROLLED AREA CONTARENATIONS auxiliary foodwater system for the reporting period di-21,000 DISINTEGRATIONS /85NUTE PER PRO 8E vided by the critical hours for the reporting period multi-AREA plied by the number of trains in the auxiliary feedwater The personnel contamination events in the clean con-system.

trolled area. This indicator tracks personnel pedor-mance for SEP #15 & 54.

COLLECTWE RADIATION EXPOSURE Collective radiation exposure is the total external whole-CONTARMNATED RADIATION CONTROLLED AREA body dose received by all on-site personnel (including The percentage of the Radiation Controued Area, which contractors and visitors) during a time period, as mea-includes the auxHiary building, the radwaste building, and sured by the thermoluminescent dosimeter (TLD). Col-areas of the C/RP building, that is contaminated based lective radiation exposure is reported in units of person-on the total square footage. This indicator trads perfor-3 rom. This indicator tracks radiological work performanc*

mance for SEP # 54.

for SEP #54.

DAILY THERMAL OUTPUT COMPONENT FAILURE ANALYSIS REPORT (CFAR)

This indicator shows the daily core thermal output as i

SURAAARY measured from computer point XC105 (in thermal mega-The number of INPO categories for Fort Calhoun Station watts). The 1500 MW Tech Spec limit, and the unmot with significantly higher (1.645 standard deviations) fail-portion of the 1495 MW FCS daily goal for the reporting ure rates than the rest of the industry for an eighteen month are also shown.

rnonth time period. Failures are reported as component (i.e. pumps, motors, valves, etc.) and application (i.e.

DIESEL GENERATOR RELIABILITY (25 DEMANDS) charging pumps, main steam stop valves, control el*-

This indicator shows the number of failures occurring for ment drive motors, etc.) categories.

each emergency diesel generator du,ing the last 25 start Failure Cause Categories are:

demands and the last 25 load-run demands.

Wear Out/A ing - a failure thought to be the conse-0 quence of expected wear or aging.

DISASLING NJURY/lLLNESS FREQUENCY RATE Manufacturing Defed - a failure attributable to inad-(LOST TIME ACCIDENT RATE) equate assembly or initial quality of the responsible com-This indicator is defined as the number of accidents for ponent or system.

an utility personnel permanently assigned to the station, Engineering / Design - a failure attributable to the inad-involving days away from work per 200,000 man-hours equate design of the responsible component or system.

worked (100 man-years). This does not include contrac-Other Devices - a failure attributable to a failure or for personnel. This indicator trods personnel perfor-misoperation of another component or system, includin9 mance for SEP #25 & 26.

associated devices.

Maintenance / Testing a f ailure that is a result of im-DOCUMENT REVIEW (SIEl# GAL) proper maintenance or testing, lack of maintenance, or The Document Review Indicator shows the number of personnel errors that occur during maintenance or test-documents reviewed, the number of documents sched-ing activities performed on the responsible component or uled for review, and the number of document reviews system, including failure to follow procedures.

that are overdue for the reporting month. A document Errors - failures attrbutable to incorrect procedures that review is considered overdue if the review is % com-were foNowed as written, improper installation of equip-plete within 6 months of the assigned due date. This ment, and personnel errors (including failure to follow indicator tracks performance for SEP #46.

procedures property). Also included in this category are failums for which the causa is unknown or cannot be as-EMERGENCY AC POWER SYSTEM SAFETY SYSTEM signed to any of the proceding categories.

PERFORMANCE The sum of the known (planned and unplanned) unavail-LTATS PER 10LOWATT HOUR able and the estimated unavailable hours for the emer-The purpose of this indicator is to quantify the economi-gency AC power system for the reporting period divided caloperation of Fort Calhoun Station. The cents per by the number of hours in the reporting period multiplied kilowatt hour indicator represents the budget and actual by the number of trains in the emergency AC power sys-cents per kilowatt hour on a 12 month roNing average for tem.

the current year. The basis for the budget curve is the EMERGENCY DIESEL GENERATOR UNIT RELIABIL-ITY This indicator shows the number of failures that were reported during the last 20,50, am! 100 emergency die-set generator demands at the FornCalhoun Station. Also shown are trigger values which co relate to a high level 135 i

PERFORMANCE INDICATOR DEFINITIONS of confidence that c unit's diesel generators hav3 ob-unroNabiHty.

tained a reliabibly of greater than or equal to g5% when the demand fauures are less than the trigger values.

ENGINEERING ASSISTANCEREQUEST(EAR) 1)Numberof Start Demands: Allvalid andinadvertent BREAKDOWN start demands, including all start only demands and all This indicator shows a breakdown, by ago and priorky of start demands that are followed by load run demands, the EAR, of the number of EARS assigned to Design En-whether by automatic or manual initiation. A start only gineering Nuclear and System Engineering. This indica-demand is a demand in which the emergency generator tor tracks performance for SEP #62.

is started, but no attempt is made to load the generator.

2) Number of Start Failures: Any failure within the emer-ENQ1NEERING CHANGE NOTICE (ECN) STATUS gency generator system that prevents the generator from The number of ECNs that were opened. ECNs that were achieving specified frequency and voltage is classified as completed, and open backlog ECNs awaiting completion a valid start faNure. This includes any condtion identified by DEN for the reporting month. This indicator tracks in the course of maintenance inspedions (with the emer-perfor nance for SEP #62.

gency generator in standby mode) that definholy would have resulted in a start failure if a demand had occurred.

ENGINEERING CHANGE NOTICES OPEN

3) Number of Load-Run Demands: For a valid load run This indicator breaks down the number of Engineering demand to be counted the load-run attempt must meet Change Notscos (ECNs) that are assigned to Design one or more of the following criteria:

Engineering Nuclear (DEN), System Engineering, and A) A load-run of any duration that results from a real au-Maintenance. The graphs provide data on ECN Facuhy tomatic or manualinitiation.

Changes open. ECN Substitute Replacement Parts B) A load-run test to satisfy the plant's load and duration open, and ECN Document Changes open. This indicator as stated in each test's specifications.

tracks performance for SEP #62.

C) Other special tests in which the emergency generator is expected to be operated for at least one hour while EQUIPMENT FORCED OUTAGES PER 1,000 CRITI-loaded with at least 50% of its design load.

CALHOllRS

4) Number of Load-Run Failures: A load run failure Equipment forced outages per 1000 critical hours is the should be counted for any reason in which the emer-inverse of tre mean time between forced outages gency generator does not pick up load and run as pre-caused by requipment failures. The mean time is equal dicted. Failures are counted during any vaEd load-run to the numoer of hours the reactor is critical in a period demands.

(1,000 hours0 days 0 hours 0 weeks 0 months ) divided by the number of forced outages l

5) Exceptions: Unsuccessful attempts to start or load-run caused by equpment failures in that period.

should not be counted as valid demands or failures when they can be attributed to any of the fonowing:

EQUIVALENT AVAILABILITY FACTOR A) Spurious trips that would be bypassed in the event of This indicator is defined as the ratio of gross available an emergency, generation to gross maximum generation, expressed as B) Malfunction of equipment that is not required during a percentage Available generation is the energy thsit an emergency.

can be produced if the unit is operated at the maximum C) Intentional termination of a test because of abnormal power level permkted by equipment and regulatory Emi-conditions that would not have resulted in major diesel tations. Maximum generation is the energy that can be generator damage or repair.

produced by a unit in a given period if operated continu-D) Malfunctions or operating errors which would have not ously at maximum capacity.

prevented the emergency generator from being restarted and brought to load within a few minutes.

FORCED OUTAGE RATE E) A fmilure to start because a portion of the starting sys-This indicator is defined as the percentage of time that tem was disabled for test purpose, if foNowed by a suc-the unit was unavailable due to forced events compared cessful start with the starting system in ks normal align-to the time planned for electrical generation. Forced mont.

events are failures or other unplanned conditions that Each emergency generator failure that results in the gen-require removing the unit from service before the end of orator being declared inoperable should be counted as the next weekend. Forced events include start-up fail-one demand and one failure. Exploratory tests during uros and events inklated while the unit is in reserve shut-corrective maintenance and the successful test that fol-down (i.e., the unit is available but not in service).

lows repair to verify operability should not be counted as demands or failures when the EDG has not been de-FUEL RELIABILITY #dDICATOR clared operable again.

This indicator is defined as the steady-state primary cool-ant 1-131 activity, corrected for the tramp uranium contri.

EMERGENCY DIESEL GENERATOR UNRELIABILITY bution and normalized to a common purification rate.

This indicator measures the total unreliability of emer.

Tramp uranium is fuel which has been deposited on re-gency diesel generators. In general, unreliability is the actor core internals from previous defective fuel or is ratio of unsuzessful operations (starts or load-runs) to the number of valid demands. Total unreliability is a combination of start unreliability and load-run 136

PERFORMANCE INDICATOR DEFINITIONS prmnt on ths curfeco of fusi ci:m:nts from ths minu-UCENSED OPERATOR REQUALIFICATION TRAIN-facturing process. Steady state is defined as mntinuous ING operation for at least three days at a power level that The total number of hours of training given to each crew does not vary more than + or - 5%. Plants should collect during each cycle. Also provided are the simulator train-data for this indicator at a power level above 85%, when ing hours (which are a subset of the total training hours),

possible. Plants that did not operate at steady state the number of non-requalification training hours and the power above 85% should collect data for this indicator at number of exam f ailures. This indicator tracks training the highest steady state power level attained during the performance for SEP #68.

l month.

The density correction f actor is the ratio of the specific LICENSEE EVENT REPORT (LER) ROOT CAUSE volume of coolant at the RCS operating temperature BREAKDOWN (540 degrees F., Vf - 0.02146) divided by the specific This indicator shows the number and root cause mde for volume of coolant at normalletdown temperature (120 Licensee Event Reports. The root cause codes are as degrees F at outlet of the letdown cooling heat ex-follows:

changer, Vf. 0.016204), which results in a density cor-

1) Administrative Control Problem - Management and rection factor for FCS equal to 1.32.

supervisory deficiencies that affect plant procrams or l

activities (i.e., poor planning, breakdown or lack of ad-GROSS HEAT RATE equate management or supervisory control, incorrect i

Gross heat rate is defined as the ratio of total thermal procedures, etc.)

energy in British Thermal Units (BTU) produced by the

2) Licensed Operator Error This cause code captures reactor to the total gross electrical energy produced by errors of omission / commission by licensed reactor opera-the generator in kilowatt-hours (KWH).

tors during plant activities.

3) Other Personnel Error - Errors of omission /commis-HAZARDOUS WASTE PRODUCED sion committed by non licensed personnel involved in The total amount (in Kilograms) of non-halogenated haz-plant activities.

ardous waste, halogenated hazardous waste, and other

4) Maintenance Problem - The intent of this cause hazardous waste produced by FCS each month.

code is to capture the full range of problems which can be attributed in any way to programmatic deficiencies in HIGH PRESSURE SAFETY INJECTION SYSTEM the maintenance functional organization. Activities in-SAFETY SYSTEM PERFORMANCE cluded in this category are maintenance, testing, surveil-The sum of the known (planned and unplanned) unavail-lance, calibration and radiation protection.

able hours and the estimated unavailable hours for the

5) Design / Construction / Installation / Fabrication Problem high pressure safety injection system for the reporting This cause code covers a full range of programmatic period divided by the critical hours for the reporting po-deficiencies in the areas of design, construction, installa-riod multiplied by the number of trains in the high pres-tion, and f abrication (i.e., loss of control power due to sure safety injection system.

underrated fuse, equipment not qualified for the environ-ment, etc.).

INDUSTRIAL SAFETY ACCIDENT RATE INPO

6) Equipment Failures (Electronic Piece-Parts or Envi-This indicator is defined as the number of accidents per ronmental-Related Failures) - This code is used for spuri-200,000 man-hours worked for all utility personnel per-ous failures of electronic piece-parts and failures due to manently assigned to tne station that result in any of the meteorological conditions such as lightning, ice, high following: 1) one or more days of restricted work (ex-winds, etc. Generally, it includes spurious or one-time ciuding the day of the accident); 2) one or more days failures. Electric components included in this category away from work (excluding the day of the accident); and are circuit cards, rectifiers, bistables, fuses, capacitors,

3) fatalities. Contractor personnel are not included for diodes, resistors, etc.

this indicator.

LOGGABLE/ REPORTABLE INCIDENTS (SECURITY)

IN LINE CHEMISTRY INSTRUMENTS OUT OF SER.

The total number of security incidents for the reporting VICE month depicted in two graphs. This indicator tracks so-Total number of in-line chemistry instruments that are curity performance for SEP #58.

out of service in the Semndary System and the Post Accident Sampling System (PASS).

MAINTENANCE OVERTIME The % of overtime hours compared to normal hours for LICENSE CANDIDATE EXAMS maintenance. This includes OPPD personnel as well as This indicator shows the number of SRO and/or RO quiz-contract personnel.

zes and exams that are administered and passed each month. This indicator tracks training performance for MAINTENANCE WORKLOAD BACKLOGS SEP #68.

This indicator shows the backlog of non-outage Mainte-nance Work Orders remaining open at the end of the reporting month. Maintenance classifications are de-fined as:

Corrective - Repair and restoration of equipment or com-137 b

=

PERFORMANCE INDICATOR DEFINITIONS Room, proindes cutomatic actions from or to the Control ponents that have faaed or are malfunctioning and are Room, or provides a passive functon for the Control not performing their intended function.

Room and has been identified as deficient, i.e., does not perform under au conditions as designed. This definition Preventive. Actions taken to maintain a piece of equip-also appnes to the Ahernate Shutdown Panels Al 179, ment within design operating conditions, prevent equip-Al.185, and Al 212.

ment failure, and extend its life and are performed prior A plant component which is deficient or inoperable is to equipment failure.

considered an " Operator Work Around (OWA) llem" if some other action is required by an operator to compen-Non-Corrective / Plant improvements Maintenance ac-sale for the condition of the component. Some examples tivities performed to implement station improvements or of OWAs are: 1) W control room level indicator does to repair non-p, ant equipment.

not work but a local sightglass can be read by an Opera-tor out in the plant; 2) A defic'ent pump cannot be re-Maintenance Work Priorities are defined as:

paired because replacement parts require a long lead time for purchase /dehvory, thus requiring the redundant Emergency - Conditions which significantly degrade sta-pump to be operated continuously; 3) Special actens tion safety or availability.

are required by an Operator because of equipment de-sign problems. These actons may be described in Op-Immediate Action Equipment deficiencies which signifi-erstions Memorandums, Operator Notes, or may require cantly degrade station reliability. Potential for unit shut-changes to Operating Procedures. 4) Deficient plant

~

down or power reduction.

equpment that is required to be used during Emergency Operating Procedures or Abnormal Operating Proco-Operations Concem Equipment deficiencies which dures. 5) System indication that provides critical infor-hinder station operation.

mation during normal or abnormal operations.

Essential - Routine corrective maintenance on essential NUGABER OF BBSSED SURVEILLANCE TESTS RE-station systems and equipment.

SULTING IN LICENSEE EVENT REPORTS The number of Surveillance Tests (STs) that result in Non-Essential-Routine corrective maintenance on non-Licensee Event Reports (LERs) during the reportmg essential station systems and equipment.

month. This indicator tracks missed STs for SEP #60 &

61.

Plant improvement Non corrective maintenance and plant improvements.

OPEN CORRECTIVE ACTION REPORTS & INCIDENT REPORTS This indicator tracks maintenance performance for SEP This indicator displays the total number of open Correc-

36.

tive Action Reports (CARS), the number of CARS that are older than six months and the number of open significant MAXIMUtd DIDIVIDUAL RADIATION EXPOSURE CARS. Also displayed are the number of open incident The total maximum amount of radiation received by an Reports (irs), the number of irs that are greater than six individual person working at FCS on a monthly, quarterly, months old and the number of open significant irs.

and annual basis.

OUTSTANDING BAODIFICATIONS MWO PLAledlNG STATUS (CYCLE 16 REFUELING The number of Modification Requests (MRs)in any state OUTAGE) between the issuance of a Modification Number and the The total number of Maintenance Work Orders that have completion of the drawing update.

been approved for inclusion in the Cycle 15 Refueling

1) Form FC-1133 Backlog /in Progress. This number rep-Outage and the number that are ready to work (parts resents modification requests that have not been plant staged, planning complete, and all other paperwork approved during the reporting month.

ready for field use). Also included is the number of

2) Modification Requests Being Reviewed. This category MWOs that have engineering holds (ECNs, procedures includes-and other miscellaneous engineering holds). parts hold, A.) Modification Requests that are not yet reviewed (parts staged, not yet inspected, parts not yet arrived)

B.) Modification Requests being reviewed by the Nuclear and planning hold (job scope not yet completed). Main-Projects Review Committee (NPRC).

tenance Work Requests (MWRs) are also shown that C.) Modification Requests being reviewed by the Nuclear have been identified for the Cycle 15 Refueling Outage Projects Committee (NPC) and have not yet been convened to MWOs.

These Modification Requests may be reviewed several times before they are approved for accomplishment or NURABER OF CONTROL ROOM EQUtPMENT DEFl-cancelled. Some of these Modification Requests are CIENCIES retumed to Engineering for more information, some ap-A control room equhment deficiency (CRD)is defined as proved for evaluation, some approved for study, and any component which is operated or controlled from the some approved for planning. Once planning is com-Control Room, provides indication or alarm to the Control pleted and the scope of the work is clearly defined, these Room, provides testing capabilities from the Control Modification Requests may be approved for accomplish-ment with a year assigned for construction or they may 138

PERFORMANCE INDICATOR DEFINITIONS be cancelled. All of these different phases require re-more individuals (as opposed to being attributed to a de-

view, partment or a general group). Also, the inappropriate

3) Design Engineering Backlog /In Progress. Nuclear action must have ocx:urred within approximately two Planning has assigned a year in which mnstruction will years of the

Event Date* specified in the LER.

be completed and design work may be in progress.

Additionally, each event classified as a " Personnel Error"

4) Construction Backlog /In Progress. The Construction should also be classified as

Preventable." This indicator Package has been issued or construction has begun but trends personnel performance for SEP ltem #15.

l the modification has not been accepted by the System Acceptance Committee (SAC).

PRIMARY SYSTEM CHEMISTRY % OF HOURS OUT

5) Design Engineering Update Backlog /In Progress. PED OF UMIT has received the Modification Completion Report but the The % of hours out of limit are for six primary chemistry drawings have not been updated.

parameters divided by the total number of hours possible l

(

The above mentioned outstanding modifications do not for the rnonth. The key parameters used are: Lithium, include modifications which are proposed for cancella-Chloride, Hydrogen, Dissolved Oxygen, Fluoride and tion.

Suspended Solids. EPRIlimits are used.

i OVERALL PROJECT STATUS (REFUELING OUTAGE) PROCEDURAL NONCOMPLIANCE INCIDENTS This indicator shows the status of the projects which are (MAINTENANCE) in the scope of the Refueling Outage.

The number of identified incidents concerning mainte-nance procedural problems, the number of closed irs PERCENTAGE OF TOTAL MWOs COMPLETED PER related to the use of procedures (includes the number of

{

MONTH IDENTIFIED AS REWORK closed irs caused by procedural noncompliance), and The percentage of total MWOs completed per month the number of closed procedural noncompliance irs.

identified as rework. Rework activities are identified by This indicator trends personnel performance for SEP j

maintenarce planning and craft. Rework is: Any main-

15,41 & 44 tenance work repeated to correct a deficiency which has I

re-occurred within 60 days following similar work activi-PROGRESS OF CYCLE 16 OUTAGE MODIFICATION ties. Any additional work required to correct deficiencies PLANNING (FROZEN SCOPE OF 15 MODIFICA.

i discovered during a failed Post Maintenance Test to on-TIONS)

{

sure the component / system passes subsequent Post This indicator shows the status of modifications ap-Maintenance Tests. This definition can be found in S. O.

proved for completion during the Refueling Outage.

M-101.

PROGRESS OF 1994 ON-LINE MODIFICATION PLAN-PERCENT OF COMPLETED SCHEDULED MAINTE-NING (FROZEN SCOPE OF 14 MODIFICATIONS)

NANCE ACTIVIT1ES This indicator shows the status of modifications ap.

The % of the number of completed maintenance activi.

proved for completion during 1994.

ties as compared to the number of scheduled mainte-nance activities each month. This % is shown for all RADIOLOGICAL WORK PRACTICES PROGRAM maintenance crafts. Also shown are the number of The number of identified poor radiological work practices emergent MWOs. Maintenance activities include MWRs, (PRWPs) for the reporting month. This indicator tracks MWOs, STs, PMOs, calibrations, and other miscella-radiological work performance for SEP #52.

neous activities. This indicator tracks Maintenance per-formance for SEP #33.

RATIO OF PREVENTIVE TO TOTAL MAINTENANCE &

PREVENTIVE MAINTENANCE ITEMS OVERDUE PREVENTABLE / PERSONNEL ERROR LERs The ratio of preventive maintenance (including surveil-1 This indicator is a breakdown of LERs. For purposes of lance testing and calibration procedures) to the sum of I

LER event classification, a preventable LER is defined non-outage corrective maintenance and preventive main-as: An event for which the root cause is personnel error tenance completad ever the reporting period. The ratio, (i.e., inappropriate action by one or more individuals),

expressed as a percentage, is calculated based on man-j inadequate administrative controls, a design /construc-hours. Also displayed are the % of preventive mainte-l tion /installaten/f abrication problem (involving work com-nance items in the month that were not completed or ad-pleted by or supervised by OPPD personnel) or a main-ministratively closed by the scheduled date plus a grace tenance problem (attributed to inadequate or improper period equal to 25 % of the schedeled immval. This indi-upkeep / repair of plant equipment). Also, the cause of cator tracks preventive maintenance activities for SEP the event must have occurred within approximately two

41.

years of the

Event Date* specified in the LER (e.g., an event for which the cause is attributed to a problem with RECORDABLE INJURY /1LLNESS CASES FRE-the or ginal design of the plant would not be considered QUENCY RATE oreventable).

The number of injuries requiring more than normal first lv purposes of LER event classification, a

Personnel aid per 200,000 man-hours worked. This indicator Error

LER is defined as follows: An event for which the trends personnel performance for SEP #15,25 & 26.

root cause is inappropriate action on the part of one or REPEAT FAILURES 139

PERFORMANCE INDICATOR DEFINITIONS special tests or construction activities. An event identi-The number of Nuclear Plant Rehability Data System fied from the swooning process as a significant event (NPRDS) components with more than 1 failure and the candidate is further evaluated to determine if any actual number of NPRDS components with more than 2 f ailures or potential thred to the health and safety of the public for the eighteen month CFAR period.

was involved. Spec'c examples of the type of criteria are summarized a; ollows: 1) Degradation of important SAFETY SYSTEM FAILURES safety equhmer o f) Unexpected plant response to a Safety system failures are any events or conditions that transient; 3) D3.mistion of fuelintegrity, primary cool-could prevent the fulfillment of the safety functions of ant pressure boundary, important==aad= tad features; strudures or systems. If a system consists of multiple

4) Scram with complicaten; 5) Unplanned release of redundant sutmystems or trains, failure of al trains con-radioactivity; 6) Operation outside the limits of the Tech-stitutes a safety system failure. Failure of one of two or nicalSpecihcations; 7) Other.

more trains is not counted as a safety system failure.

INPO significant events reported in this indicator are The definition for the indicator parallels NRC reporting SERs (Significant Event Reports) which inform utilities of requirements in 10 CFR 50.72 and 10 CFR 50.73. The significant events and lessons loamed identified through following is a list of the major safety systems, sub-the SEE-IN screening process systems, and components monitored for this indicator:

Accident Monitoring instrumentation, Auxiliary (and SPARE PARTSINVENTORY VALUE Emergency) Feedwater System, Combustible Gas Con-The dollar value of the spare parts inventory value for trol, Component Cooling Water System, Containment FCS during the reporting period.

~

and Containment isolation, Containment Coolant Sys-tems, Control Room Emergency Ventilation System, STAFFING LEVEL Emergency Core Cooling Systems, Engineered Safety The actual staffing level and the authorized staffing level Features Instrumentation, Essential Compressed Air for the Nuclear Operations Division, the Production Engi-Systems, Essential or Emergency Service Water, Fire neering Division, and the Nuclear Services Division. This Detection or Suppression Systems, leolation Condenser, indicator tracks performance for SEP #24.

Low Temperature Overpressure Protection, Main Steam Line isolaton Valves, Onsite Emergency AC & DC STATION NET GENERATION Power w/ Distribution, Radiation Monitoring instrumenta.

The not generation (sum) produced by the FCS during tion, Reactor Coolant System Reactor Core i.oistion the reporting month.

Cooling Systei.. Reactor Trp System and instrumenta-tion, Recirculaton Pump Trip Actuation instrumentation.

TERFORARY MODIFICATIONS Residual Heat Removal Systems, Safety Valves, Spent The number of temporary mechanical and electrical con-Fuel Systems, Standby Liquid Control System and Ulti-figurations to the plant's systems.

mate Heat Sink.

1) Temporary configurations are defined as electrical jumpers, electrical blacks, mechanical jumpers, or me.

SECONDARY SYSTEM CHEARSTRY PERFORMANCE chanical blocks which are installed in the plant operating INDEX systems and are not shown on the latest revision of the The Chemistry Performance Index (CPI) is a calculation P&lD, schematic, connec: ion, wiring, or flow diagrams, based on the concentration of key impurities in the sec-

2) Jumpers and blocks which are installed for Surveil-ondary side of the plant. These key impurities are the lance Tests, Maintenance Procedures, Calibration Pro-most likely cause of deterioration of the steam genera-cedures, Special Procedures, or Operating Procedures tors. Criteria for calculating the CPI are: 1) The plant is are not considered as temporary modifications unless the i

i st greater than 30 percent power; and 2) The power is jumper or block remains in place after the test or proco-changing less than 5% per day. The CPIis calculated dure is complete. Jumpers and blocks installed in test or using the following equation: CPI - (sodium /0.90) +

lab instruments are not considered as temporary modifi-(Chloride /1.70) + (Sulfate /1.90) + (Iron /4.40) + (Copper /

cations.

0.30)/5. Where: Sodium, sulfate and chloride are the

3) Scaffolding is not considered a temporary modifica-monthly average blowdown concentrations in ppb, iron tion. Jumpers and blocks which are installed and for and copper are monthly time weighted average which MRs have been submitted will be considered as feedwater concentrations in ppb. The denominator for temporary modifications untilfinal resolution of the MR each of the 5 factors is the INPO median value. If the and the jumper or block is removed or is permanently monthly average for a specific parameter is less than the recorded on the drawings. This indicator tracks tempo-INPO median value, the median value is used in the cal-rary modifications for SEP #62 & 71, culation.

THERMAL PERFORMANCE SIGNIFICANT EVENTS The ratio of the design gross heat rate (corrected) to the Significant events are those events identified by NRC adjusted actual gross heat rate, expressed as a percent-staff through detailed screening arxl evaluation of operat-age.

ing experience. The screening process includes the daily review and discussion of all reported operating re-UNIT CAPABILITY FACTOR actor events, as well as other operational data such as 140

PERFORMANCE INDICATOR CFINITIONS l

The r?b of the available energy generation over a giv:n ECCS actuation setpoint or from a spurious /inady;rtent time period to the reference energy generation (the en-ECCS si nal.

0 orgy that could be produced if the unit were operated

2) The number of unplanned emergency AC power system I

continuously at full power under reference ambient con-actuations that result from a loss of power to a safeguards ditions) over the same time period, expressed as a per-bus. An unplanned safety system actuation occurs when conta0e.

an actuation setpoint for a safety system is reached or when a spurious or inadvertent signal is generated (ECCS UNIT CAPACITY FACTOR only), and major equipment in the system is actuated.

I The not eledrical energy generated (MWH) divided by Unplanned means that the system actuation was not part the product of maximum dependable capacity (not MWe) of a planned test or evolution. The ECCS actuations to be times the gross hours in the reporting period expressed counted are actuations of the high pressure injection sys-as a percent. Net electrical energy generated is the tem, the low pressure injection system, or the safety injec-gross electricaloutput of the unit measured at the output tion tanks.

terminals of the turbine generator minus the normal sta-tion service treads during the gross hours of the reporting UNPLANNED SAFETY SYSTEM ACTUATIONS (NRC l

period, expressed in megawatt hours.

DEFWITION) l The number of safety system actuations which include UNPLANNED AUTOMATIC REACTOR SCRAMS PER (onbf,) the High Pressure Safety injection System, the Low 7,000 CRITICAL HOURS Pressure Safety injection System, the Safety injection This indicator is defined as the number of unplanned au-Tanks, and the Emergency Diesel Generators. The NRC tomatic scrams (reactor p#otection system logic actua-classification of safety system actuations includes mutus-tions) that occur per 7,000 hours0 days 0 hours 0 weeks 0 months of critical operation.

tions when major equipment is operated and when the The value for this indicator is calculated by multiplying logic systems for the above safety systems are chal-the total number of unplanned automatic reactor scrams longed.

In a specific time period by 7,000 hours0 days 0 hours 0 weeks 0 months , then dividing that number by the total number of hours critical in the VIOLATIONS PER 1,000 INSPECTION HOURS same time period. The indicator is further defined as This indicator is defined as the number of violations sited follows:

in NRC inspec.a reports for FCS per 1,000 NRC inspec.

1) Unplanned means that the scram was not an antici-tion hours. The violations are reported in the year that the pated part of a planned test.

inspection was actually performed and not based on when

2) Scram means the automatic shutdown of the reactor the inspection report is received. The hours reported for by a rapid insertion of negative reactivity (e.g., by control each inspection report are used as the inspection hours.

rods, liquid injection system, etc.) that is caused by ac-tuation of the reactor protection system. The scram sig. VOLUME OF LOW LEVEL SOUD RADIOACTIVE nal may have resulted from exceeding a setpoint or may WASTE have been spurious.

This indicator is defined as the volume of low-level solid

3) Automatic means that the initial signal that caused radioactive waste actually shipped for burial. This indica-actuation of the reactor protection system logic was pro-tot also shows the volume of low-level radioactive waste vided from one of the sensors monitoring plant param-which is in temporary storage, the amount of radioactive eters and conditions, rather than the manual scram oil that has been shipped off-site for processing, and the switches or, in manual turbine trip switches (or push-but-volume of solid dry radioactive waste which has been tons) provided in the main control room, shipped off-site for processing. Low-level solid radioactive

4) Critical means that during the steady-state condition of waste consists of dry active waste, sludges, resins, and the reactor prior to the scram, the effective multiplication evaporator bottoms generated as a result of nuclear power factor (k,,) was essentially equal to one.

plant operation and maintenance. Dry radioactive waste includes contaminated rags, cleaning materials, dispos-UNPLANNED CAPA81UTY LOSS FACTOR able protective clothing, plastic containers, and any other The ratio of the unplanned energy losses during a given material to be disposed of at a low-level radioactive waste period of time, to the reference energy generation (the disposal site, except resin, sludge, or evaporator bottoms.

energy that could be produced if the unit were operated Low-level refers to all radioactive waste that is not spent continuously at full power under reference ambient con-fuel or a by-product of spent fuel processing. This indica-ditions) over the same time period, expressed as a per-tor tracks radiological work performance for SEP #54.

contage.

UNPLANNED SAFETY SYSTEM ACTUATIONS-(INPO DEFINITION)

This indicator is defined as the sum of the following safety system actuations:

1) The number of unplanned Emergency Core Cooling i

System (ECCS) actuations that result from reaching an 141

1 1

SAFETY ENHANCEMENT PROGRAM INDEX 1

The purpose of the Safety Enhancement Program (SEP) Performance Indcators Index is to list perfor-mance indcators rehted to SEP llems with parameters that can be trended.

I SEP Reference Ernbar 15 P.agg increase HPES and IR Accountability Through Use of Performance Indcators Procedural Noncornpliance incidents (Maintenance)............................................................... 95 Clean Controlled Ares Contaminations 21,000 Disintegrations / Minute Per Probe Area............... 8 Recordable injuryMilness Cases Frequency Rate................................................................ 7 Preventable / Personnel Error LERs.................................................................................... 9 i

SEP Reference Number 24 Complete Staff Studies

[

Staffing Loul

..............................................................................................................81 i

SEP Reference Nunbar 25 I

Training Program for Managers and Supervisors implemented Disablire injuryMHness Frequency Rate..................................................................... 5 Recordable injuryMilness Cases Frequency Rate..........................................................

.... 7 SEP Reference Number 26 Evaluate and implement Station Standards for Safe Work Practice Requirements Disabling injuryMliness Frequency Rate................................................................. 5 Recordable injuryMilness Cases frequency Rate.......................................................... 7 i

SEP Reference Number 27 irrolement Supervisory Enforcement of indastrial Safety Standards Disat2ing injuryMilness Frequency Rate.................................................................... 5 Recordable injuryMilness Cases Frequency Rate..................................................................... 7 SEP Reference Number 31 Develop Outage and Maintenance Planning Manual and Coixiuct Project Management TraininD MWO Planning Status (Cycle 16 Refueling Outape)..............................................................127 Overall Project Status (Cycle 16 Refueling Outage)..............................................................129 Progress of Cycle 16 Outage Modification Plc aning..............,............................................130 SEP Reference Number 33 i

Develop On-Line Malntenance and Modification Schedule i

Percent of Completed Scheduled Maintenance Activities 1

(All Maintenance Crafts)...................

.............................97 1

SEP Reference Number 36 Reduce Corrective Non-Outage Backlog Maintenance Workload Badiogs (Corrective Non-Outage)................................................ 87 SEP Reference Number 41 Develop and implement a Preventive Maintenance Schedule Ratio of Preventive to Total Maintenance & Preventive Maintenance items Overdue........... 89 Procedural Noncortpliance Incidents.............................................................. 95 l

I

,l I

142 l

l

i SAFETY ENHANCEMENT PROGRAM INDEX (continued)

SEP Reference Number 44 Eagg Compliance With and Use of Procedures Procedural NonconWlance incidents (Maintenance)............................................

........... 9 5 SEP Reference Number 46 Design a Procedures Control and Administrative Program Document Review................................................................................................... 107 SEP Reference Number 52 Establish Supervisory Accountability for Workers Radiological Practices Rad 6ological Work Practices Program.......................

...............................................105 SEP Reference Number 54 Complete implementation of Radiolo0ical Enhancement Program Collective Radiation Exposure.......................................................................... 29 Volume of Low-Level Solid Radioactive Waste........................................................... 71 Clean Controlled Area Disintegrations 21,000 Counts / Minute Per Probe Area....

..........8 Contaminated Radiation Controlled Area................................................................103 SEP Reference Number 58 Revise Physical SeaJrity Training and Procedure Pro 0 ram Lo9 gable / Reportable incidents (Security).........................................................109 SEP Reference Number 60 Improve Controls Over Surveillance Test Program Number of Missed Surveillance Tests Resulting in Licensee Event Reports......................... 37 SEP Reference Number 61 Modify Computer Program to Correctly Schedule Surveillance Tests Number of Missed Surveillance Tests Resulting in Licensee Event Reports......................... 37 SEP Reference Number 62 Establish Interim System Engineers Temporary Modifications.................

......... 1 1 1 Engineering Assistance Request (EAR) Breakdown................................................115 En0ineering Chan0e Notice Status............................................................... 117 Engineering Change Notices Open...................................................................... 118 SEP Reference Number 68 Assess Root Caure of Poor Operator Training and Establish Means to Monitor Operator Training Licensed Operator Requalification Training._..........................................

........... 121 License Candidate Exams...............

...........................................................123 SEP Reference Number 71 Improve Controls over Temporary Modifications Temporary Modifications....................

.............................................111 143

)

1 REPORT DISTRIBUTION LIST R.L Andrews W. C. Jones K. L. Beisk J. D. Keppler B. H. Biome D. D. Kloock C. E. Boughter L T. Kusek j

C. J. Brunnert M. P. Lazar i

M. W. Butt B. R. Livingston G. R. Cavanaugh D. L Lovett J. W. Chase J. H. MacKinnon I

A. G. Christensen J. W. March O. J. Clayton N. L. Marfice j

R. P. Clemens R. D. Martin R. G. Conner T. J. Mcivor J. L. ConnoNey K. G. Melstad l

G. M. Cook K. A. Miur.-

S. R. Crites P. A. M.;a J

D. W. Dale Nuci er Licensby D. C. Dietz

& Ino.Z~y Affs;ts M. L. ENis J. T. O'Crmr H. J. Faulhaber W. W. Orr j

M. T. Frans T. L Patterson i

D. P. Galle R. T. Pearce S. K. Gambhir R. L PheDs J. K. Gasper W. J. Ponec W. G. Gates C. R. Rice l

S. W. Gebers A. W. Richard L. V. Gokberg D. G. Ried D. J. Golden G. K. Samide l

D. C. Gorence M. J. Sandhoefner l

R. H. Guy F. C. Scofield A.L. Hale H. J. Sefick K. R. Henry J. W. Shannon J. B. Herman C. F. Simmons T. L. Herman E. L Skaggs K. C. Holthaus J. L. Skiles i

L. P. Hopkins F. K. Smith C.K.Huan0 R. L. Sorenson T. W. Jamieson K. E. Steele i

R. L. Jaworski M. A.Tesar R. A.Johansen J. J. Tesarek J. W. Johnson J. W. TINS R. Jones D. R. Trausch J. M. Waszak G. R. WHiiams S. J. WHirett i

4 144

I PORT CALHOUN STATION OPERATING CYCLES AND REFUELING OUTA0E DATES Event Date Range Production (MWH)

Cumulative (MWH)

Cycle 1 06/26/73 02/01/75 3,299,639 3,299,639 1st Refueling 02/01/T5 06/09/T5 Cycle 2 06/09/75 10/01/F6 3,853,322 7,152,961 2nd Refueling 10/01/76 12/13/76 Cycle 3 12/13/76-9/30/TT 2,806,927 9,958,888 3rd Refueling 09/30/77 12/09/F7

)

i Cycle 4 12/09/T7 13/14/TS 3,026,832 12,986,720 4th Refuenng 10/14/F8 12/24/18 Cycle 5 12/24/78- 01/18/80 3,882,734 16,868,454 5th Refueling 01/18/80- 06/11/80 Cycle 6 06/11/80 09/$81 3,899,714 20,768,168 8th Refuenng 09/18/81 -12/21/81 Cycle 7 12/21/81 -12/06/82 3,561,866 24,330,034 7th Refueung 12/06/82 04/07/83 Cycle 8 04/07/83- 03/03/84 3,406;371 27,736,405 8th Refueung 03/03/84 07/12/84 Cycle 9 07/12/84- 09/28/85 4,741,488 32,477,893 9th Refueling 09/28/85- 01/16/86 Cycle 10 01/16/86 - 03/07/87 4,356,753 36.834,646 10th Refueling 03/07/87- 06/08/87 j

Cycle 11 06/08/87-09/27/88 4,936,859 41,771,505 11th Refueling 09/27/88 - 01/31/89 Cycle 12 01/31/89 02/17/90 3,817,954 45,589,458 12th Retuoling 02/17/90 05/29/90 i

Cycle 13 05/29/90 - 02/01/92 5,451,069 51,040,528 13th Refueling 02/01/92 05/03/92 Cycle 14 05/03/92-09/25/93 4,981,485 56,022,013 14th Refueling 09/25/93 11/26/93 Cycle 15 11/26/93 - 03/11/95 15th Refueling 03/11/95 - 04/29/95 (Planned Dates)

FORT CALHOUN STATION CURRENT PRODUCTION AND OPERATIONS " RECORDS" First Susteined Reaction August 5,1973 (5:47 p.m.)

First Electricity Supplied to the System August 25,1973 Commercial Operation (180,000 KWH)

September 26,1973 Achieved Full Power (100%)

May 4,1974 Lon0est Run (477 days)

June 8,1987 Sept. 27,1988 Highest Monthly Not Generation (364,468,000 KWH)

October 1987 Most Productive Fuel Cycle (5,451,069 MWH)(Cycle 13)

May 29,1990 Feb.1,1992

..

ML20078G854

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