Text

Performance Indicators Rept, for Dec 1995
	ML20097H144
Person / Time
Site:	Fort Calhoun
Issue date:	12/31/1995
From:	; OMAHA PUBLIC POWER DISTRICT
To:	;
Shared Package
ML20097H143	List: ML20097H138; ML20097H144;
References
	NUDOCS 9601290282
	Download: ML20097H144 (91)
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-

Omahe Puter Power Dietrict FORT CALHOUN STATION PERFORMANCE INDICATORS s

DECEMBER 1995 SAFE OPERATIONS PERFORMANCE EXCELLENCE COST EFFECTIVENESS R

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m OMAHA PUBLIC POWER DISTRICT FORT CALHOUN STATION PERFORMANCE INDICNf0RS REPORT ImCKMBER 1995 PreparedBy:

Production Engineering Division System Engineering TestandPerformance Group l

DECEMBER 1995 9

FORT CALHOUN STATION December 199s MONTHLY OPERATING REPORT OPERATIONS

SUMMARY

During the month of December,1995, Fort Calhoun Station (FCS) operated at a nominal 100% power with the exception of a one-day power reduction to 99.2% for placing an lon Exchanger for the Reactor Coolant in service. Normal plant maintenance, surveillance, equipment rotation activities and scheduled on-line modifications were performed during the month. Monitoring of a Control Element Drive Mechanism (CEDM) mechanical seal leak continued.

On December 4,1995, a one hour non-emergency NRC notification was made as a result of the determination that the plant had been outside of its design basis for maintaining a adequate quantity of Trisodium Phosphate (TSP) in the Containment Building to neutralize the sump water to a pH of 27.0. The TSP is stored in the basement of the building and is designed to neutralize the boric acid which would be injected into the Reactor Coolant System (RCS) and containment during a Loss-of-Coolant Accident (LOCA). The amount of TSP in the FCS containment is sufficient to neutralize the sump water to a pH 27.0 for current boric acid concentrations in the RCS, Safety injection Tanks, Boric Acid Storage Tanks and Safety injection Tanks and the Safety injection Refueling Water Tank. Corrective actions are being takes as reported in Licensee Event Report (LER)95-008.

On December 7,1995, the plant Fire brigade was alerted and assembled to respond to smoke in the warehouse. The smoke was determined to be caused by an overheated motor on an oscillating fan.

No fire suppression system or eq"ipment discharge was required.

i

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-*-- Fort Calhoun index Value l==l 100,

- *- Industry Median inden Value 90 -

80 -

l 70 -

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0 92/1 92/2 92/3 92/4 93/1 93/2 93/3 93/4 94/1 94/2 94/3 94/4 95/1 95/2 95/3 Oct Nov Dec 96 Performance Index Trend For the index calculation unit capability factor, unplanned capability loss factor, unplanned automatic scrams per 7000 hours0.081 days 1.944 hours 0.0116 weeks 0.00266 months critical, safety system performance, collective radiation exposure, and volume of low-level solid radioactive waste indicators are calculated for a two-year period instead of the normal three-year period to allow the index trend to be more responsive to changes in plant performance.

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NRC Performance Indicators t

FORT CALHOUN STATION PERFORMANCE INDICATORS REPORT December 1995 -

SUMMARY

POSITIVE TREND REPORT ADVERSE TREND REPORT A performance indicator with data representing three A pedormance indcator with data representing three consecutive months of improving performance or three consecutive months of declining performance or three consecutve months of performance that is superior to the conseche months of pedomance that is trending stated goal is exhitzbng a pos#tive trend per Nuclear toward dedning as determined by the Manager - Station Opersbons DMaion Quahty Procedure 37 (NOD-QP-37).

Engineering, constitutes an adverse trend per Nuclear Opershons Dunion Quairty Procedure 37 (NOD-QP-37).

The foRowing performance indicators exhituted positive A supervsor whose performance indicator exhibits an trends for the reporting month:

adverse trend by the delniDon may specify in wntten form (to be pubished in this report) why the trend is not Safety System Failures aderse.

E' I

The fogowing performance indicators exhibited adverse Hiah Pressure Safety Iniection System Safety System trends for the reporting month:

Maintenance Workload Backloos (Page 48)

(p,'

Thermal Perfoemance (Page 33)

Emeao Diesel Generator Unreliability p

Diesei Generator Reliability (25 Demands)

INDICATORS NEEDING INCREASED page 12)

MANAGEMENT ATTENTION REPORT Emeroenev Diesel Generator Unreliabilftv (Page 13)

A performance indicator with data for the reporting period that is inadequate when compared to the OPPD goalis Sianificant Events defined as *Needing increased Management Attention" (Page 20) per Nuclear Operations Division Quakty Procedure 37 (NOD-QP-37).

Missed Surveillance Tests Results in Ucensee Event BE23 Industnal Safety Accident Rate (Page 21)

(Page 2)

Unolanned Safety System Actuations -INPO Definition Disablino iniury/ Illness Freauency Rate (Page 30)

(Page 3)

Primary Svstem Chemistry Percent of Hours Out of Limit (Page 39) l Secondary System Chemistry I

(Page 40) l l

Hazardous Weste Produced I

(Page SS) l l

Contaminated Radiation Controlled Area (Page 56)

End of Postbve Trend Report.

V

~

FORT CALHOUN STATION PERFORMANCE INDICATORS REPORT December 1995 -

SUMMARY

l INDICATORS NEEDING INCREASED MANAGEMENT ATTENTION REPORT (continued)

)

Fuel Reliststy Indicator End of Report improvements / Changes Report.

1 (Page 14)

Number of Control Room Eauipment Deficiencies (Page 15)

Number of On-Line and Outaae Control Room Eauloment Deficiencies (Page 16)

Collectrve Radiation Exoosure (Page 17)

Forced Outaae Rate (Page 24)

Unit Caoabiltty Factor (Page 27)

Unit Capabihty Loss Factor (Page 28)

Eauioment Forced Outaae Rate (Page 35)

Percentaae of Total MWOs Completed oer Month identrlied as Rework (Page 50)

Temocrary Modtfications (Page 60)

PERFORMANCE INDICATOR REPORT IMPROVEMENTS / CHANGES The section irsts significant changes made to the report and to specific indicators within the report since the previous month.

Two new Chemistry Performance Indicators were added to the November Performance Indicator Book. See pages 41 and 42.

Vi

Table of Contents / Summary enan oOAts.................................................................. x SAFE OPE 00NS Industrial Safety Accident Rate - INPO..........................................

2 Disabling injury / Illness Cases Frequency Rate...

3 Recordable injury / Illness Cases Frequency Rate..................

.4 Clean Controlled Area Contaminations

(

!>.1,000 DisintegrationsMinute per Probe Area 5

Preventable / Personnel Error LERs

.6 Safety System Failures 7

Safety System Performance:

High Pressure Safety injection System

.... 8 Auxiliary Feedwater system

............... 9 Emergency AC Power System 10 Emergency Desel Generator Unit Reliability 11 Reliability (25 Demands)

....................................................12 Un reliability................................................

..............13 Fuel Reliabilify indicator............................................................ 14 Control Room Equipment Deficiencies.............................................. 15 On-Line and outage Control Room Deficiencies........................................ 16 Cmlective Radiation Exposure.....................

.................................17 Maximum individual Radiation Exposure.............................................. 18 Vio lation Tre nd............................................................. 19

)

Significant Events.............................

...... 20 Missed Surveillance Tests Resulting in LERs 21 PERFORMANCE Station Net Generation.......

. 23 Forced Outage Rate.

........... 24 i

Unit Capacity Factor 25 1

{

Equivalent Availability Factor...

26

Table of Contents / Summary PERFORMANCE (continued)

FAGE Unit Capability Factor.............

.......... 27 Unplanned Capability Loss Factor

.. 28 Unplanned Automatic Reactor Scrams per 7,000 Hours Critical 29 Unplanned Safety System Actuations INPO Definition..

. 30 NRC Definition 31 Gross Heat Rate....

32 Thermal Performance.....

33 Daily Thermal output

............ 34 Equipment Forced Outages per 1,000 Critical Hours 35 Component Failure Analysis Report (CFAR) Summary..

. 36 1

Repeat Failures

. 37 Volume of Low-Level Solid Radioactive Weste

. 38 Primary System Chemistry Percent of Hours Out of Limit 39 Secondary System Chemistry......

....................40 Chemistry......

41 Chemistry........

42 Cents Per Kilowatt Hour 44 Staffing Level

. 45 Spare Parts inventory Value

. 46 1

DIVISION AND DEPAR M NT PERF0 M U G INDICATORS

)

Maintenance Workload Backlogs (Corrective Non-Outage) 48 Ratio of Preventive to Total Maintenance & Preventive Maintenance items Overdue 49 Percentage of Total nios Completed per month identified as Rework 50 I

Overtime 51 Procedural Noncompliance Incidents 52 Daily Schedule Perfortnance - Percent of Completed Scheduled Activities 53

Table of Contents / Summary DMSiON AND DEPARTMENT PERFORMANCE INDICATORS PAGE In-Une Chemistry instruments Out-of-Service 54 Hazardous Waste Produced 55 Contaminated Radiation Controlled Area...

. 56 Radiological Work Practices Program 57 Document Review 58 Lo99able/ Reportable incidents (Security) 59 Modifications Temporary.............

60 Outstanding

. 61 Engineering Assistance Request (EAR) Breakdown

... 62 Engineering Change Notices Status 63 Open.

64 Ucensee Event Report (LER) Root Cause Breakdown 65 Ucensed Operator Requalification Training

...............................66 Ucense Candidate Exams...

67 Open incident Reports 68 Cycle 17 Refueling Outage MWO Planning Status

. 69 Overall Project Status 70 Outage Modification Planning

. 71 On-Une Modification Planning.............

. 72 Progress of 1995 On-Une Modification Planning 73 ACTION PLANS. DEFINITIONS. SEP INDEX & DISTRIBUTION LIST l

Action Plans 74 l

Performance Indicator Definitions..

76 l

Safety Enhancement Program index 85 Report Distribution List.

87 l

OPPD NUCLEAR ORGANIZATION GOALS ix

Vice President-1995 Priorities MISSION The safe, reliable and cost effective generation of electricity for OPPD customers through 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 Supports: April 1994 Corporate Strategic Plan Goal 3, Obj: 3 & 4 A proactive, self-critical and safety conscious culture is exhibited throughout the nuclear organization. Individuals demonstrate professionalism through self ownership and personal initiative and o,: i communication.

1995 Priorities:

i Improve 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.

Objectives to support SAFE OPERATIONS.

OBJECTIVE 1-1:

j No challenges to a nuclear safety system.

OBJECTIVE 1-2:

I Conduct activities in accordance with applicable policies, technical specifications, procedures, standing orders and work instructions.

Less than 1.4 NRC violations per 1,000 inspection hours.

Fewer significant Corrective Action Documents (CADS) originating from activities.

OBJECTIVE 1-3:

Identify conditions BEFORE they affect plant safety and reliability.

OBJECTIVE 14:

Achieve all safety-related 1995 performance indicator goals in the Performance Indicator Report.

OBJECTIVE 1-5:

Zero Lost Time injuries and recordable injuries rate BELOW 1.5 percent.

OPPD NUCLEAR ORGANIZATION GOALS x

Vice President-1995 Priorities Eggjj:

PERFORMANCE Supports: April 1994 Corporate Strategic Plan Goal 3, Obj: 2 and Goal 4, Obj: 1 Achieve high standards of performance at Fort Calhoun Station resulting in safe, reliable and cost effective power production.

1995 PRIORITIES:

Improve Quality, Professionalism and Teamwork.

Improve 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.

Objectives to support PERFORMANCE:

OBJECTIVE 2-1:

Achieve an annual plant capacity factor of 70% and a unit capability factor of 81%,

OBJECTIVE 2-2:

Execute the 1995 refueling outage in 49 days; emphasize shutdown plant safety.

OBJECTIVE 2-3:

Achieve all performance related 1995 performance indicator goals in the Performance Indicator Report.

OBJECTIVE 2-4:

All projects and programs are planned, scheduled, and accomplished according to schedules, resource constraints, and requirements.

OBJECTIVE 2-5:

Team //ndvidual ownership, accountability, performance and teamwork is evident by improved plant reliability; improved ratings for both INPO and NRC; reduced number of human performance errors and identification of performance problems by effective self assessment and for indviduals as measured by the successful completion of department goals & objectives and other specific measures.

Xi i

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OPPD NUCLEAR ORGANIZATION GOALS Vice President - 1995 Priorities fdtgil:

COSTS Supports: April 1994 Corporate Strategic Plan Goal 2, Obj: 1,2 and 3, and Goal 6, Obj: 1 Operate Fort Calhoun in a manner that cost effectively maintains nuclear generation as an economically viable contribution to OPPD's " bottom line". Cost consciousness is exhibited at all levels of the organization.

1995 Priorities:

Maintain total O&M and Capital Expenditures within budget.

Streamline work process to improve cost effectiveness.

P Objectives to support COSTS:

OBJECTIVE 3-1:

Conduct the nuclear programs, projects, and activities within the approved Capital and O&M budgets.

OBJECTIVE 3-2:

Implement nudear related Opportunity Review recommendations according to approved schedules and attain the estimated cost savings.

i e

i Goals Source:

Scofield (Manager) l Xii I

SAFE OPERATIONS Goal: A proactive, self-critical and safety conscious culture is exhibited throughout the nuclear organization. Individuals demonstrate professionalism through self-ownership and per-sonal initiative and open communication.

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Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nw Dec 1996l lNDUSTRIAL $AFETY ACCIDENT RATE As stated in INPO's December 1993 publication ' Detailed Descriptions of World Association of Nuclear Operators (WANO) Performance Indicators and Other Indicators for Use at U.S. Nuclear Power Plant': "The purpose of this indicator is to monitor progress in improving industrial safety performance for utility personnel permanently assigned to the station."

l The INPO industrial safety accident rate value year-to-date was 1.22 at the end of December 1995. The value for the 12 months from January 1,1995, through December 31,1995,was 1.22.

l There were no restricted-time and zero lost-time accidents in December 1995.

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 1995 Fort Calhoun year-end goal is 50.50. The 1995 INPO industry goal is 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 Trend:

Needs increased Management Attention 2

1995 Disateng injuryminess Requency

-x 1994 Disabling injury 41 ness Requency 4

Average Rate (Last 12 Months) l G000]

1995 Goal (0.50) 2..

1.8 1.6..

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Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec DISABLING INJURY /lLLNESS FREQUENCY RATE l

(LOST-TIME ACCIDENT RATE)

This indicator shows the 1995 disabling injury / illness frequency rate. The 1994 disabling injury /

illness frequency rate is also shown.

The disabling injury / illness frequency rate year-to-date was 1.22 at the end of December 1995.

There were zero disabling injury / illness cases reported for the month.

The disabling injury / illness frequency rate for the 12 months from January 1,1995, through December 31,1995, was 1.22.

The 1995 Fort Calhoun year-end goal for this indicator is a maximum value of 0.5.

Data Source:

Sorensen/Skaggs (Manager / Source)

Accountability:

Chase / Conner Trend:

Need increased Management Attention SEP 25,26 & 27 3

MI5 Recordable IriuryfIllness Frequency x

1994 Recordable Iriuryoliness Frequency o000l 2

Average Rate (Last 12 Months)

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Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 1995l RECORDABLE INJURY /lLLNESS FREQUENCY RATE i

This indicator shows the 1995 recordable injury / illness frequency rate. The 1994 record-able injury / illness cases fmquency rate is also shown.

A recordable injury / illness case is reported if personnel from any of the Nuclear Divisions 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.

There have been eleven recordable injury / illness cases in 1995. The recordable injury /

illness cases frequency rate year-to-date was 1.49 at the end of December 1995. There were no recordable injury / illness cases reported for the month of December 1995.

The recordable injury / illness cases frequency rate for the 12 months from January 1, 1995, through December 31,1995, was 1.49.

The 1995 Fort Calhoun year-end goal for this indicator is a maximum value of 1.5.

Data Source:

Sorensen/Skaggs (Manager / Source)

Accountability:

Conner Trend:

None SEP 15,25,26 & 27 4

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_i Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nw Dec 1995 CLEAN CONTROLLED AREA CONTAMINATIONS 21,000 DISINTEGRATIONS / MINUTE PER PROBE AREA This indicator shows the Personnel Contamination Events in the Clean Controlled Area for contaminations 11,000 disintegrations / minute per probe area for the reporting month.

There were 3 contamination events in December 1995. There has been a total of 57 contamination events in 1995 through the end of December. This compares to 47 at this time last year.

Data Source:

Chase /Cartwright (Manager / Source)

Accountability:

Chase /Lovett Trend:.

None SEP 15 & 54 5

I e

e PersonnelErrors (Esch Month)

+ Preventable (18-Month Totals) e PersonnelError(18-MonthTotals) 20..

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15 1

l 10..

5.-

l E

0 1

1 Jun Jul Aug sep oct Nov Dec Jan Feb Mar Apr May Jun Jul Aug sep Oct Nov 1a l1995l PREVENTABLElPERSONNEL ERROR LER.

This indicator depicts 18-month totals for numbers of " Preventable" and " Personnel Error" LERs.

The graph shows the 18-month totals for preventable LERs, the 18-month totals for Per-sonnel Error LERs and the Personnel Error totals for each month. The LERs are trended based on the LER event date as opposed to the LER report date.

In November 1995, there was one event which was subsequently reported as an LER.

No LERs were categorized as Preventable and as Personnel Error for the month of No-vember. The total LERs for the year 1995 (through November 30,1995) is seven. The total Personnel Error LERs for the year 1995 is two. The total Preventable LERs for the year is three.

The 1995 goal for this indicator is that the year-end values for the 18-month totals be no more than 12 Preventable and 5 Personnel Error LERs.

Data Source:

Trausch/Cavanaugh (Manager / Source)

Accountability:

Chase Trend:

None SEP 15 6

i startup ie Shutdown m Operations

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Industry Average Trend 2.

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92-2 92-3 92 4 93-1 93-2 93 3 93 4 94-1 94-2 94-3 94 4 95 1 Year-Quarter SAFEW $YSTEM 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 Indica-tors for Operating Commercial Nuclear Power Reactors" report.

The following safety system failures occurred between the 2nd quarter of 1992 and the 1st quarter of 1995:

1st Quarter 1993: The SG low pressure scram signal block reset values, for all 4 channels of both SGs, were greater than the allowed limits, rendering this scram input inoperable during certain operating condi-tions.

2nd Quarter 1993: A section of the piping configuration forthe 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.

4th Quarter 1993: 1) During surveillance testing, both PORVs for the LTOP system failed to open during multiple attempts. The failures were a result of differential expansion caused by a loop seal, excessive 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.

1st Quarter 1994: A design basis review determined that an ESF relay could result in loss of safety injection and spray flow, due to premature actuation of recirculation flow.

4th Quarter 1994: An accident scenario was identified that could result in the inoperability of both control room air conditioning units. Following certain accident conditions, CCW temperature could rise causing compressor rupture disc failure an't a release of freon.

There were no safety system failures in the 1st quarter of 1995.

Data Source:

Nuclear Regulatory Commission Accountability:

Chase Trend:

Positive 7

m Monthly Ngh Prossure safetyinjection System UnavailabilityValue Year 4mte Ngh Pressure SafetyIr(ection System UnavailabilityValue Fort Calhoun Goal (0.004)

G000l 1970 Industry Goal (0.02)

industry Upper 10%(0.0011) 1 I 0.02 _

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1994 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 1996l HIGH PaESSunE SAFETY INJECTION SYSTEM 3

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 reporting month.

The High Pressure Safety System unavailability value for the month of December 1995 was 0. There were 0 hours0 days 0 hours 0 weeks 0 months of planned unavailability, and 0 hours0 days 0 hours 0 weeks 0 months of unplanned unavail-ability, during the month. The 1995 year-to-date HPSI unavailability value was 0.0006 at the end of the month. The unavailability value for the last 12 months was 0.0006.

There has been a total of 13.39 hours4.513889e-4 days 0.0108 hours 6.448413e-5 weeks 1.48395e-5 months of planned unavailability and 0.0 hours0 days 0 hours 0 weeks 0 months of un-planned unavailability for the high pressure safety injection system in 1995.

The 1995 Fort Calhoun year-end goalfor 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 1/92 through 12/94) is approximately 0.001.

Data Source:

Jaworski/Schaffer (Manager / Source)

Accountability:

Jaworski/Schaffer Trend:

Positive 8

MorWy AuxBary Fee & vater System UhawRabERy year-tocate Energency AC Pmwr thewHabdky Goo l x

..... Rrt camounGbal(0.01) 1996 woindustryanal(0.025) y e

industryUpper10%(0.0021) 0.03 0.025 0.02

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i i

1994 Jan Feb Mar Apr May Jun Jtd Aug Sep Oct Nov Dec 1996 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 1995 was 0.00336.

There were 5.0 hours0 days 0 hours 0 weeks 0 months of planned and 0 hours0 days 0 hours 0 weeks 0 months of unplanned unavailability during the month.

The year-to-date unavailability value was 0.0034 and the value for the last 12 months was 0.0034 at the end of the month.

There has been a total of 49.61 hours7.060185e-4 days 0.0169 hours 1.008598e-4 weeks 2.32105e-5 months of planned unavailability and 12.92 hours0.00106 days 0.0256 hours 1.521164e-4 weeks 3.5006e-5 months of un-I planned unavailability for the auxiliary feedwater system in 1995.

l The 1995 Fort Calhoun year-end goal for this indicator is a maximum value of 0.01.

The 1995 INPO industry goal is 0.025 and the industry upper ten percentile value is ap-proximately 0.002.

Data Source:

Jaworski/Nay (Manager / Source) i Accountability:

Jaworski/Nay f

Trend:

None 9

1

m Monedy energency Ac Power LhavaRatdllty Vakse

-x Year to.cate E'mergency AC Power thava8abigtyValue

+ FortCatiounGoal(OA24)

_g_._ 1996 IPPOlndustryGoal(0A26) 0.16.

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0.12 _

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Jan Feb Mar Apr May Jun Jul Aug Sep oct Nov Dec 1996l 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 1995 was 0.052.

During the month, there were 77.26 hours3.009259e-4 days 0.00722 hours 4.298942e-5 weeks 9.893e-6 months of planned unavailability, and 0.0 hours0 days 0 hours 0 weeks 0 months of unplanned unavailability for testing and repairs associated with the govenor switch modi-fication. The Emergency AC Power System unavailability value year-to-date was 0.010 and the value for the last 12 months was 0.010 at the end of the month.

There has been a total of 180.9 hours1.041667e-4 days 0.0025 hours 1.488095e-5 weeks 3.4245e-6 months of planned unavailability and 4.3 hours3.472222e-5 days 8.333333e-4 hours 4.960317e-6 weeks 1.1415e-6 months of un-planned unavailability for the emergency AC power system in 1995.

The 1995 Fort Calhoun year-end goal for this indicator is a maximum value of 0.024.

The 1995 INPO industry goal is 0.025 and the industry upper ten percentile value is ap-proximately 0.0035.

Data Source-Jaworski/Ronning (Manager / Source)

Accountability:

Jaworski/Ronning Trend:

10

m ranure:121FDemanda a FailureslS0 Demands e Failuresl100 Demands l0o00l l

e-Trigger Values 120 Demanda j

+ Trigger ValuestS0 Demands II

-e Trigger Values.100 Demands 8.. :

7.

6..

j 5

4 s..

2 999 3,

y9 yy

,j 93 g3 j

y, j

o Jan Feb Mar Apr May Jun Jul Aug sep Oct Nov Dec l1995l 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 values. The Fort Calhoun 1995 goal is to have fewer failures than th'.ese 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 manualinitiation. 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 minimum of one hour and to be loaded with at least 50% of design load (see exceptions and other demand criteria in the Definition Section of this report).

Data Source:

Jaworski/Ronning (Manager / Source)

Accountability:

Jaworski/Ronning Trend:

Positive due to performance better than goal.

11

DG1 FaRures/26nds DG 2 Failures /25 Demands l GOOD l o

1ss5ooal 3_

4-c 3

3_

2 i

i i

t i

1 1

1 q

q 0

0 0

0 0 0

0 0

l l

1 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec l1995l DIESEL GENERATOR RELIABILITY (25 DEMANDS)

This indicator shows the number of failures experlenced by each emergency diesel gen-l erator 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 1995, 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 fail-ures within the last 25 demands on the unit. These actions are described in the Defini-tions Section of this report. A System Engineering Instruction has been approved for the I

Fort Calhoun Station to institutionalize and formally approve / adopt the required NUMARC actions.

Diesel Generator DG-1 has experienced one failure during the last year, and zero fail-i ures during the last 25 demands on the unit. Diesel Generator DG-2 has experienced one failure during the last 25 demands on the unit.

Special diesel testing during hot weather took place during July. This testing enabled the diesel high temperature operability limits to be raised.

Data Source:

Jaworski/Ronning (Manager / Source)

Accountability:

Jaworski/Ronning Trend:

Positive due to performance better than goal.

12

m DG 1 UnrollatilityValue m DG-2 UnreliabilityValue i

+ Station unreliabilityValue i0000 1995 Goal i

_o_. Industry Upper 10%(0.002 for a 3 Year Average) 0 A6 -.

025 c

0A4..

';s:

une 3,3 _

0A2..

0A1.. ee ee ee e.

.e ee e

e e

0 9

9 9

Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 1995 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, opera-tion and test practices in controlling generator unreliability. The last event occured on September 1,1995 when the Field Flash Relay on DG-2 failed.

The year-to-date station EDG unreliability at the end of December 1995 was 0.026. The 1995 goal for this indicator is a maximum value of 0.05.

For DG-1:

There was 4 start demands for the reporting month with 0 failures.

In addition, there were 0 load-run demands without a failure.

For DG-2:

There were 2 start demands for the reporting month with 0 failures.

In addition, there were 0 load-run demands 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 unsuccessfulload-runs number of valid load-run demands Station Value = average of DG-1 and DG-2 values i

Data Source:

Jaworski/Ronning (Manager / Source)

Accountability:

Jcworski/Ronning Trend:

Positive due to performance better than goal.

13

g FueIReHeblHty GOOD l

+ 1995 IPPO Industry Ibel Defect Reference (5 x 10-4 Microcuries/ Gram) o_. 1995 Goal q

ss 601 E 56 -

g 4s _.

j

!! 50.

.3 40 3 35 g 30..

y 25.

m 20 _

y 15 -.

o 10 __

5__

O l

1 I - l I

I I

I l

l I

Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec

)

l1995 f

EUEL RELIABILITY INDICATOR The FUEL RELIABILITY INDICATOR (FRI) for December 1995 was 63.86 X 10d microcuries/ gram. The i

purpose of the FRI is to monitor industry progress in achieving and maintaining a high level of fuel integrity.

]

An effective fuelintegrity and performance monitoring program provides a means to detect fuel failures and 4

J assess the fuel failure number, physical condition, exposure, mechanism, and location.

The December FRI value is based on data from December 1" through 31 ". The days selected are when the plant chemistry values were at equilibrium for steady state full power operation.

Cycle 16 plant operation started on April 13* and attained 100% on April 23. During the months of June and July the plant operated at 100% power. The plant tripped at the end of August but has operated at 100% during the months of September through December.

The December FRI value of 63.86 X 10d microcuries/ gram indicated an increase from the November FRI value of 62.46 X 104 microcuries/ gram. No new fuel failures were determined to have occurred during the month based on changes in the equilibrium Xenon and lodine data. This is consistent with the normal increase of fission products during a cycle and the increased power production of the peripheral assemblies due to shim bumout and the subsequent power distribution changes with power shifting from the center of the core to the periphery. Recent analysis through December 31,1995, performed by nuclear engineering, indicated four to six failed rods at core average power. The Cesium isotopic analysis indicated failures in several different bumup levels. OPPD personnel estimate that 15 to 25 rods are failed based on the results from the Cycle 15 and 16 RCS chemistry data and the end of Cycle 15 fuel inspection project.

j The INPO July 1995 report, "WANO Performance Indicator Program Utility Data Coordinator Reference Notebook" (INPO No.94-009, Rev.1) states the Industry 1995 Goal for fuel reliability is:

units should strive to operate with zero fuel defects". The 1995 Fort Calhoun Station FRl Performance Indicator goal is to i

maintain a monthly FRI below 5.0 x 104 microcuries/ gram. A value larger than 5.0 x 104 microcuries/ gram indicates a high probability of reactor core operation with one or more fuel defects.

Data Source:

Holthaus/ Weber Accountability:

Chase /Spijker Trend:

Needs increased Management Attention 14

I m ControlFbom DeSciencies Added i

i ontrolRoomDeScienciesCompleted C

m CompletedwithinTargetCompletionDate 1

50 _ _

~

_ _100.0%

'78%

com.conpw. sour ex oircarim. tv T,oe conpiiabno.

k 45 4o

, 40 -

_ 80.0% e f

ss.sw O

~

s7.os h

^ " ' '

j 30 _.

_ 60.0%

8

.g, 2s ss.ov.

l 22 2,

. 40.0 % I 0 20 _.

me.os j

w w

g E

j

,o o

10 --

__ 20.0% at s

0 0.0%

May Jun Jul Aug Sep Oct ftw Dec46 ControlRoom Danciencies NuusER OF CONTROL Roou DEFICIENCIES This indicator measures the timeliness of closing Control Room Deficiencies.

Target Completion Dates are established by the Emergent Work Committee. The goalis to close at least 80% of all CRDs within the Target Due Date.

There were 29 Control Room Deficiencies completed during December 1995, and 16 were completed within the target completion date.

A Scheduling Coordinator has been assigned to track performance on a weekly basis and identify problem areas. Revisions have been made to the scheduling process to allow for more timely completion of CRDs.

Data Source:

Chase / Walling (Manager / Source)

Accountability:

Chase /Faulhaber Trend:

Needs increased Management Attention - Performance Below Goal 15

-. ~.. -

4 m

O***

+ teamberof OrRJne Cortrol Room Deficiencies 35.

30 -

28 g as 25.

2 y__

w L=umaov.a.

12 15._

E May95 Jun Jtd Asg Sep Oct Nov Dec 95 remberatOrRJnecm l m Overdue

+ Number of Outage Control Room Deficiencies 20 _

i.t 2_1 15 -

tbte: Overdue tems era *::= older than 18 morths 10.

~.

,,,,,,,,o,,,,,

5

)

0__.

May-05 Jun Jul Aug Sep oct Nov Dec 05 l Number of Outage CRDs l NUMBER OF ON.LINE AND OUTAGE CONTROL ROOu DEFICIENCIES This indicator shows the total number of On-Line and Outage Control Room Deficiencies, and the number of overdue Control Room Deficiencies.

There were 28 on-line (11 were overdue) and 30 outage (2 were overdue) Control Room Deficiencies at the end of December 1995.

The 1995 Fort Calhoun goal for these indicators are less than 8 overdue on-line and no overdue outage Control Room Deficiencies.

Data Source:

Chase / Walling (Manager / Source)

Accountability:

Chase /Faulhaber/ Herman Trend:

Needs increased Management Attention - Number of On-Line CRDs

<8 Overdue exceeds goal 16

=_.

.i

}

g Monthly Personnel Radiation Exposure Cumulative Personnel Radiation Exposure "o000]

l e

FCS Goal (143.1 Person-Rem) 160 2

2 I

2 2

0 0

0

^

2

^

j 140

^

~

130._

120-_

)

110..

l 100..

90._

hop 80.

70..

n-60 50..

40 j

30 j

20 10..

E M

--r-

-r-Od Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec l1996 l 1

COttecTive RADIATION EXPOSURE The 1995 Fort Calhoun goal for collective radiation exposure is less than 143.1 person-Rem.

The exposure for December 1995 was 1.061 person-Rem (ALNOR), down from 0.684 Rem for October.

The year-to-date exposure through the end of December was 139.155 person-Rem (TLD).

The 1995 INPO industry goal for collective radiation exposure is 185 person-rem per year. The current industry best quartile is 145 person-rem per year. The yearly average for Fort Calhoun Station for the three years from 1/93 through 12/95 was 106.395 person-rem per year.

Data Source:

Chase /Cartwright (Manager / Source)

Accountability:

Chase /Lovett Trend:'

Needs increased Management Attention SEP 54 17

O Mghest Exposure (Month) 5 Highest Exposure (Year) 5000 OPPD4500 mPemlyr. Limit 4000 3000_-

)

2000_

1,266 1000_

138 o

I

... I j

i December-95 l MAXIMUM lNDIVIDUAL RADIATION EXPOSURE During December 1995, an individual accumulated 138 mrem, which was the highest individual exposure for the morth.

The maximum individual exposure for the year of 1,000 mrem was exceeded during March 1995 when an individual received 1,266 mrem (875 mrem of this was received during orifice plate repairin a steam generator). However, the OPPD 4500 mrem /yr limit is not expected to be exceeded.

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

year. The 1995 Fort Calhoun year-end goal is a maximum of 1,000 mrem.

Data Source:

Chase /Cartwright (Manager / Source)

Accountability:

Chase /Lovett Trend:

None 18

=_

e Fc5CIWdVFoiahons (Mosthry) a FCS Non. Cited Violations (Monthly)

FCS Cited Violations (12. Month Average) l 0000 l o_.

FCS Non. Cited Violations (12. Month Average) m__

Region IV Cited Violations (12 Month Average for Ihglon IV top quartile) lI

W

~

4 a.

-[#.

j 6__

,,,-g _ q._.,,,,,n c

o- --..

O 4

y-

.C,b,m 0

r,; e,

e e

m

,E 1

3 1

k E

,f f

4 5

M w

z z

=

A o

E 5

Nl i

VIOt.ATION TREND This indicator illustrates a 12-month trend for Fort Calhoun Station Cited Violations, Non-Cited Violations and Cited Violations for the Top Quartile plants in Region IV. Additionally, the Fort Calhoun Station cited and non-cited violations for the past 12 months will be I

illustrated monthly. The 12-month trend for the Region IV top quartile lags 2-3 months behind the Fort Calhoun Station trend. This lag is necessary to compile information on other Region IV plants.

4 l

The following inspections were completed during December 1995:

IER No.

Title 95-20 Solid Radwaste Mgmt & Transportation of Radioactive Material 95-21 Monthly Resident inspection 95-22 Environmental & Monitoring Program i

95-23 Emergency Planning / Simulator Mini-Drills To date, OPPD has received fourteen violations for inspections conducted in 1995.

Levellli Violations 0

LevelIV Violations 9

Level V Violations 0

Non-Cited Violations 5

Total 14 The 1995 Fort Calhoun Station Goal for this performance indicator is to be at or below the cited violation trend for the top quartile plant in Region IV.

Data Source:

Trausch/Cavanaugh (Manager / Source)

Accountability:

Trausch Trend:

None 39

\\

l

g NRC Signmcant Events

_.e_. Industry Average Trend l OOOD l 1

i 1 __

q f 0.5._

0 m

r 2

r r

92-2 92-3 92-4 93 1 93-2 93-3 93-4 94-1 94-2 94-3 94-4 95-1 l Year - Quarter l INPO Signifbant Events (SERs) lOOODl 2 _. y g

g g

g 5y 1__

j 0

92-2 92-3 92-4 93 1 93-2 93-3 93 4 94 1 94-2 94-3 94 4 95 1 l Year-Quarter l

$IGNIFICANT EVENTS This indicator illustrates the number of NRC and INPO Significant Events for Fort Calhoun Station as re-ported by the Nuclear Regulatory Commission's Office for Analysis and Evaluation of Operational Data in l

the blannual" Performance indicators for Operating Commercial Nuclear Power Reactors" report and INPO's Nuclear Network.

The following NRC significant events occurred between the 2nd quarter of 1992 and the 1st quarter of 1995:

i 3rd 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.

4th Quarter 1994: A potential accident scenario involving a large break loss of coolant accident or a main i

steam line break inside containment could result in the inoperability of both control room A.C. units.

The following INPO significant events, as reported in Significant Event Reports (SERs), occurred between the 2nd quarter of 1992 and the 1st Quarter of 1995:

2nd Quarter 1992: Intake of Transuranics during Letdown Filter Change-out.

3rd Quarter 1992: 1) RC-142 LOCA; and 2) Premature Lift of RC-142.

1st Quarter 1993: Inoperability of Power Range Nuclear Instrumentation Safety Channel D.

J 2nd Quarter 1993: SBFU Breaker Relay (Switchyard) Plant Trip 4th Quarter 1993: Unexpected CEA Wrthdrawal.

1st Quarter 1994: Unplanned dilution of Boron concentration in the RCS.

Data Source:

Nuclear Regulatory Commission & INPO Accountability:

Chase Trend:

Positive 20 i

MasedSTs Restitingin LERs 3._

N l

Y 2__

1 1._

0 0

93 94 Jan Rob Mar Apr May Jun Jul Aug Sep Oct Nw Dec 1995 NUMBER OF MISSED $URVEILLANCE TESTS RESULT 1NG IN LICENSEE EVENT REPORTS This indicator shows the number of missed Surveillance Tests (STs) that result in Lic-ensee Event Reports (LERs) during the reporting month. The graph on the left shows the yearly totals for the indicated years.

There were no missed surveillance tests resulting in LERs during November 1995.

On December 28,1994, during the performance of OP-ST-SHIFT-0001, data was not entered for Steam Generator level per Surveillance Requirements.

The 1995 Fort Calhoun monthly goal for this indicator is 0.

Data Source:

Monthly Operating Report & Plant Licensee Event Reports (LERs)

Accountability:

Chase /Jaworski Trend:

Positive SEP 60 & 61 21

i i

4 i

i i

PERFORMANCE l

Goal: To strive for Excellence in Operations utilizing the high-est standards of performance at Fort Calhoun Station that result in safe, reliable plant operation in power productir...

.. ~ _ _. _ _ _ _ _. _ _.. _ _ _ _ _. _. _. _

t I.

l f

Not Generation (10,000 MWh) l 40.

l 36.22 36.04 34.27 35.06 l

3412 34.29 i

l 30.46 30.

2 22.82 8

21.19 i

i 1

l 1 20.

15.29 j

g N

o es.

o 0

i i

i Jan Feb Mar Apr May Jun Jul Aug sep Oct Nov Dec j

l1995l 4

i STATION NET GENERATION During the month of December 1995, a net total of 362705.4 MWh was generated by the Fort Calhoun Station. Cumulative net generation for Cycle 16 was 2,645,758.1 MWh at the end of the month.

Energy losses for August 1995 were attributable to a plant trip during a test of a backup automatic shutdown system, which began on August 24th. The generator was brought back on-line at 3:43 p.m. on Saturday, August 26th, after a two-day outage.

Energy losses for May 1995 were attributable to: (1) the component cooling water, which was leaking into the lube oil system of RC-3D reactor coolant pump motor; and (2) the generator and reactor were again manually tripped because of a similar leak. The gen-erator was put on-line after replacement of all of the reactor coolant pump lube oil cooler heat exchangers.

l Data Source:

Station Generation Report Accountability:

Chase Trend:

None 8

23

, forced Outage Rate (Monthly)

+ Forced Outage Rate (12 Months) l GoOo l

_e Fort Calhoun Goal (2.4%)

40% --

j r 35%.

30%..

25%..

20% --

15%._

10%. Y 5%.

t**%

o.o rs c

=

c a

[=

0% i n

r 92 93 94 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 95 FORCED OUTAGE RATE j

The forced outage rate (FOR) was reported as 3.7% for the twelve months from January 1,1995, through December 31,1995. The 1995 year-to-date FOR was 3.7% at the end of the month.

Energy losses for August 1995 were attributable to a plant trip during a test of a backup automatic shutdown system, which began on August 24th. The generator was brought j

back on-line at 3:43 p.m. on Saturday, August 26th, after a two-day outage.

Energy losses for May 1995 were attributable to two separate shutdowns to repair com-poi 1ent cooling water leaks in the lube oil system of RC-3D reactor coolant pump motor oil leaks. The generator was put on-line after replacement of all four of the reactor coolant pump lube oil cooler heat exchangers.

The 1995 Fort Calhoun year-end goal for this indicator is a maximum value of 2.4%.

Date Source:

Monthly Operating Report Accountability:

Chase Trend:

Needs increased Management Attention 24 l

l

i

, Monthly UnE CapecRy Factor

..... Year to.Dete thit capacityfactor g

Unit Capacity Factor for Cycler "& 16 3 Month Average Unit CapacityFactor Ml 110%..

100%..

-a:.

90%

O-T E

E 2

80%

m m

+c 70%_.

.h A<

~~

~

)

.0% -

4

.g.,,

40%._

i Cycle 15 N/* --

Ref unH,g 20%.

Od ***

10%..

0%

1 i

Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec l1995 UNIT CAPACITY FACTOR This indicator shows the plant monthly Unit Capacity Factor, the Unit Capacity Factor for the current fuel cycle, year-to-date and the 36-month average Unit Capacity Factor.

At the end of the month, the Cycle 16 Unit Capacity factor was 101.99%, and the Unit Capacity Factor for the last 36 months was 81.8%. The 1995 Fort Calhoun annual goal for this indicator is 79.65%. The Fort Calhoun 3-year average capacity factor goal for 1995 is 84.05%.

The year-to-date value is 80.38%

Energy losses for May and August 1995 are discussed on the previous page.

The Unit Capacity Factor is computed as follows:

Net Electrical Enerav Generated (MWH)

Maximum Dependable Capacity (Mwe) X Gross Hours in the Reporting Period Data Source:

Monthly Operating Report Accountability:

Chase Trend:-

Needs increased management Attention (Below 1995 Goal) 25

, Monthly FAF e_. Year-to Date Average Monthly EAF

+ 12-Month Average EAF industry Median Value (76.7% for a 3. Year Average) j 100%..

s 7.2 s g

1

=

w

]

-u u

~

f 78.2 %

u

-u u

u y-60%.."

~

40%-.

cyci. is nervenas ovies.

20%..

0%

92 94 Feb Apr Jun Aug Oct Dec-95 EQUIVALENT AVAILABILIW 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 three years.

The EAF for December 1995 was reported as 98.89%. The year-to-date monthly aver-age EAF was 85.3% at the end of the month.

Energy losses for May and August 1995 are explained on page 24.

The Fort Calhoun average monthly EAF for the three years prior to this report was 88.76%.

The industry median EAF value for the three-year period from 7/90 through 6/93 was 76.7%.

Data Source:

Dietz/Kulisek (Manager / Source)

Accountability:

Chase Trend:

None 26

, MonthlyLWtCapebilityFactor

...s... Year-to Date Unit Capability Factor Jk

_ # _ 36-Month Lhlt Capability Factor

+ FortCatmunGoals l

l teamtryu 100%..

~~

Y 3

[

,[.

j B'

80%.

" --~

.a-60%.

y....m......a..-

40%

Cycle il RefseHas 20%..

o ut...

0%

Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nw Dec N

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 continuously at full power under reference ambient conditions) over the same time period, expressed as a percentage (refueling periods excluded).

The UCF for December 1995 was reported as 100.0%. The year-to-date UCF was 81.2%,

the UCF for the last 12 months was 81.2%, and the 36-month average UCF was reported as 85.4% at the end of the month.

Energy losses for May and August 1995 are explained on page 24.

The 1995 INPO industry goal is 80% and the industry current best quartile value (for the three-year period ending 12/94) is approximately 85%. The 1995 Fort Calhoun annual goal for this indicator is a minimum of 81.64%. The 3-year average capability factor goal for 1995 is 85.5%.

Data Source:

Generation Totals Report & Monthly Operating Report Accountability:

Chase Trend:,

Needs increased Management Attention 27

I MornNy Lkiplanned Capetsity Loss Fhctor lq i

i

_, Year-ToosselkiplannedcapatsityLossFactor 12-Morth Amrage (k1 planned Capetiitty Loss Factor y

l

%_ RrtcalhmmGoal(3.9'IM x

_e NoindustryGoal(4.5%

_._ industrycarenteastaartse 40%..

3r4..

2FA..

\\

/

v*-~e --

, J

-v 194.

P

.--w y

=

I "I

-/

^

p3 r-y_

=

Jan Feb Mar Apr May Jm Jtd Aug Sep Oct Nov Dec 1995 l

UNPLANNED (APABILITY BOSS FACTOR i

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 1995 was reported as 0.00%. Unplanned energy 1

loss is defined as the energy that was not produced during the period of unscheduled shutdowns, outage extensions, or load reductions due to causes under plant manage-ment control. Energy losses are considered to be unplanned if they are not scheduled at least four weeks in advance. The year-to-date UCLF was 8.53%, the UCLF for the last 12 months was 7.46%, and the 36-month average UCLF was reported as 4.5% at the end of the month.

Energy losses for May and August 1995 are explained on page 24.

The 1995 INPO industry goal is 4.5% and the industry current best quartile value is ap-proximately 3.2% or lower. The 1995 Fort Calhoun year-end goal for this indicator is a i

maximum value of 3.97%.

Data Source:

Generation Totals Report & Monthly Operating Report Accountability:

Chase Trend:-

Needs increased Management Attention.

28

\\

e_. FCS Reactor Scrams Per '(,000 Hours CriticalYear-to-Date

+ FCS Reactor Scrams Per 7,000 Hours Criticalfor last 36 months

._,__ Fort Calhoun Goal (0.0)

INPOIndustry Goal (1) c Industry Upper 10%(1 per 7,000 houra critical) 3..

2 e

e e

e a

As e

-g-g 1

0 4

Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec l1995l Fcs Reactor Scrams 4,.

3 3

2 2

1 1

1 0

0 0

0 0,

1 91 92 93 94 Jan Feb Mar Apr May Jun Jul Aug Sep oct Nov Dec 95 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 Intema-tional Nuclear Power Plant Performance Indicators and Other indicators") for Fort Calhoun 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 1.0 at the end of December 1995. The value for the 12 months from January 1,1995, through December 31,1995, was 1.0. The value for the last 36 months was 1.21.

The 1995 Fort Calhoun goal for this indicator is 0. The 1995 INPO industry goal is a maximum of one unplanned automatic reactor scram per 7,000 hours0 days 0 hours 0 weeks 0 months critical. The indus-try upper ten percentile value is approximately 0.48 scrams per 7,000 hours0 days 0 hours 0 weeks 0 months critical.

Data Source:

Monthly Operating Report & Plant Licensee Event Reports (LERs)

Accountability:

Chase Trend:.

Needs increased Management Attention (Above FCS Goal) 29

m SafetySystem Actuations(WODefmition) l

+ ICS Goal (0)

+ industryUpper10 Percentile (0) i 3 _.

2__

1 1

1 1__

0 0

0

; ; l: __,

92 93 94 Jan Feb Mar Apr May Jun Jtd Aug Sep Oct Nov Dec 95 UNPLANNED SAFEW SYSTEM ACTUATIONS -(INPO DEFINITION)

There were no INPO unplanned safety system actuations during the month of Decenber 1995.

There was one INPO unplanned safety system actuation during the month of August 1995. It occurred on August 24,1995, when the plant was tripped during a test of a backup automatic shutdown system. The generator was brought back on-line at 3:43 p.m. on August 26th, aftei a two-day outage.

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

The 1995 Fort Calhoun goal for this indicator is 0.

Data Source:

Monthly Operating Report & Plant Licensee Event Reports Accountability:

Jaworski/Foley/Ronning Trend:

Positive 30

m SafetySystem Actuations(PRCDefinition)

, FCS Goal (0)

+ CriticalHours

-m 124onth Running Total SSAs (E Definition) 10 _

_ 800 R i "Q

700 canoe 8..

600

.2 h6 500 g3

.i g

_.400 3

4

.2 N *~

_ 300h

?

b

.200 2 4 a

-m-a-s-s-a-

====__100 l, ;I ; ; ; ; ; ; ; ; ; ; ; ; ; ; _ + 4 +,+ 4i4 0

0 92 93 94 NDJFMAMJJASONDJFMAMJJASOND 1994 1995l UNPLANNED SAFEW SYSTEM ACTUATIONS -(NRC DEFINITION) 1 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 Emergency Diesel Generators. The NRC classification of SSAs includes actua-tions when major equipment is operated and when the logic systems for these safety

, systems are challenged.

An unplanned safety system actuation occurred in December 1993 when the main turbine and reactor tripped during Electro-Hydraulic Control pump start testing. Also, there was an unplanned SSA during the month of February 1994 when supervisory relay 868/CPHSS failed, which resulted in a concurrent turbine and reactor trip.

There have been no unplanned safety system actuations in the last 12 months. The 1995 Fort Calhoun goal for this indicator is 0.

Data Source:

Monthly Operating Report & Plant Licensee Event Reports (LERs)

Accountability:

Jaworski/Foley/Ronning Trend:

None 31

m Gross Heat Rate f%

Year-to-Date Gross Heat Rate

_o_

Fort Calhoun Cbal 10.75 _

10.5..

10.25 m ars e2s h

a o---

_ o..

..o _c 10 g

E.

.T,'.'n?,

9.5

)

9.25 92 93 S4 96 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 95 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 three years.

The gross heat rate for Fort Calhoun Station was 10,020 for the month of December 1995. The 1995 year-to-date GHR was 10,219 at the end of the month.

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 1995 Fort Calhoun year-end goal for this indicator is <10,157.

Data Source:

Holthaus/Willett (Manager / Source)

Accountability:

Chase /Jaworski Trend:

None*

32

1 e MonthlyThermalPerformance g

12-Month Average i

+ Year-to-Date Average MonthlyThermalPerformance

._o__

Fort Calhoun Goal (99.6%)

+ INPOlndustryGoal(99.5%)

l GOOD]

__o__ industry Upper 10%(99.7%)

100%..

c c

c

=

a I

I 2

K d

y 99%..

outes.

98%

Jan Feb Mar Apr

.May Jun Jul Aug Sep Oct Nov Dec N

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 upper ten percentile value.

The thermal performance value for December 1995 was 99.20. The year-to-date aver-age monthly thermal performance value was 99.4, at the end of the month. The average monthly value for the 12 months from January 1,1995, through December 31,1995, was 99.4%. The reduction in thermal performance is due to a combination of feedwater heater thermal losses, condenser performance effects, system valve leakage, and auxiliary steam demand increases. These losses have been evaluated as part of the Thermal Perfor-mance improvement Action Plan developed in September 1995 and are documented in a recently developed White Paper.

The 1995 Fort Calhoun year-end goal for this indicator is a minimum of 99.6%. The 1994 Fort Calhoun goalwas a minimum of 99.5%. The 1995 INPO industry goalis 99.5% and the industry upper 10 percentile value is approximately 99.9%.

Data Source:

Jaworski/Shubert (Manager / Source)

Accountability:

Jaworski/Gorence 33 Trend:

Adverse

-+ Timmud aqut

_e_ FortOdhomim5MWChal Tes!>sc1500MWumt 1500 148.

1861 s-s-s-s-s-s-s-s-s-s-s-s-s-s-s-s-s-s-s-s-s-s-s-s-s-s-s-a-s- -s 144.

1 lE1e2.

140.

148.

1e6 1

1 2 3 4 5 6 7 8 910111213141516171819 2 2122 Zi 24 25 2 27 3 29 30 31 DAILY THERMAL OUTPUT The thermal output graph displays the daily operating power level during December 1995, the 1500 thermal megawatt average technical specification limit, and the 1495 thermal megawatt Fort Calhoun goal.

Data Source:

Holthaus/Willett (Manager / Source)

Accountability:

Chase / Tills Trend:

None 34

Number of Equipment Forced Outages (Monthly)

GOOD l

Equipment Forced Outage Rate /1,000 Critical Hrs. (12-Month Interval) i

__o Fort Calhoun Year-End Goals (0.2) 2 __

1 J

.l 1

l u-u kJ k,--

LJ J

c 0

^

0 0

0 o

g 0

92 93 94 Dec Jan Feb Mar Apr May Jun Jul Aug sep oct Nov EQUIPMENT FORCEo OUTAGES l

PER 1,000 CRITICAL HOURS The equipment forced outage rate per 1,000 critical hours for the 12 months from Janu-ary 1,1995, through December 31,1995, was 0.41. The year-to-date rate per 1,000 1

critical hours for the months from January through December 1995 was 0.412.

An equipment forced outage also occurred on February 20,1995, when the plant experi-enced a problem with a control element assembly motor drive and a related small leak of reactor coolant.

Two equipment forced outages also occurred during May 1995, which were attributable to the component cooling water, which was leaking into the lube oil system of RC-3D reactor coolant pump motor.

The 1995 Fort Calhoun year-end goal for this indicator is a maximum value of 0.20.

Data Source:

Monthly Operating Report & Plant Licensee Event Reports (LERs)

Accontability:

Chase /Jaworski Trend:

Needs increased Management Attention 35

___m.

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

~4-kW =$ W y

+

18.

16.

u.

12.

10.

8.

6

~

I y

9 g

z 4;

2.

0 A.

5 0

N D

J.

F M

A M

J J

A 8

0 N

D-N 95 95 A,ef N o rm el Use 81%

in attel in sta tis tio n 5%

iestin, A stio n 4%

""8'888"N"8 M aantenance i

"I A ctio n

.n,in...n.,o....n j

2%

j COMPONENT FAILURE ANALYSIS REPORT (CFAR) $UMMARY i

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-month Component Failure Analysis Report (CFAR) reporting period (from March 1994 through August 1995). Fort Calhoun Station reported a higher failure rate in 6 of the 87 component categories (valves, pumps, motors, etc.)

during the past 18-month CFAR period. The station reported a higher failure rate in 7 of the 173 application categories (main steam stop valves, auxiliary / emergency feedwater pumps, control element drive motors, etc.) during the past 18-month CFAR period.

The pie chart depicts the breakdown by INPO cause categories (see the " Definitions" section of j

this report for descriptions of these categories) for the 49 failure reports (failure discovery dates within the 18-month CFAR period) with known failure causes that were submitted to INPO by Fort Calhoun Station. A total of 75 failure reports were submitted to INPO with discovery dates within the 18-month CFAR period.

Data Source:

Jaworski/ Frank (Manager / Source)

Accountability:

Jaworski/ Dowdy Trend:

None 36

_ ~.

l i

i

+ Components with more than One Fal!ure

+ Components with more than Two Failures 15 _

q 7 l

10 __

7 6

5.__4 4

4 4

^

3 3

3 1

1 1

0 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec l1995l REPEAT FAILURES The Repeat Failures Indicator (formerly called the " Maintenance Effectiveness Performance 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 discontinued, but station management considers it useful to continue to track repetitive component failures using the Nuclear Plant Reliability Data System (NPRDS).

i This indicator shows the number of NPRDS reportable components with more than one failure during the 18-month Component Failure Analysis Report (CFAit) period (failure discovery dates from March 1994 through August 1995) and the number of NPRDS reportable components with more than two failures during the 18-month CFAR period.

During the last 18-month CFAR period, there were 7 NPRDS components with mcre than one failure. One of these 7 NPRDS reportable components had more than two failures. Recommendations and actions to correct it.ese repeat failures are listed in the Biannual CFAR. The description and tag numbers of the NPRDS reportable components with more than one failure are listed below:

Raw Water Pumps AC-10A, AC-108, and AC-10C Reactor Protection System Channel'A' Axial Power Distribution Trip Calculator Multiplier / Divider Module Al-31 A-AW15-B4,5 Reactor Coolant Pump Motor RC-3D-M Containment Cooling coil VA 88, CCW Outlet Valve V/P-403C (3 Failures)

Control Element Drive Mechanism RC-10-08 Data Source:

Jaworski/ Frank (Manager / Source)

Accountability:

Chase Trend:

None 37

m RadioactiveWaste sunedThihs(cu.ft.)

+ Year to Date Cumulative Radioactive Waste Buried GOOD l

..o _ Fort Cahoun Goal (900 cu.ft.)

900.00 -

c 0

0 0

800.00.

700.00 __

l 600.00 __

500.00

.2 j 400.00.

U 300.00 __

200.00._

100.00 _.

mI l

OM e

- t I

l l

I I

I e

e a

' t l

Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec l

1995l VOtuuE OF LOW-BEVEL SOUD RADIOACTIVE WASTE This indicator shows the volume of the monthly radioactive waste buried, the cumula-tive year-to-date radioactive waste buried, the Fort Calhoun and INPO goals, and the approximate industry upper 10%.

l Cu.Ft.

Amount of solid radwaste shipped off site for processing during current month 0

Volume of solid radwaste buried during current month 103.8 l

Cumulative volume of solid radioactive waste buried in 1995 450.4 Amount of solid radwaste in temporary storage 0

The 1995 Fort Calhoun goal for the volume of solid radioactive waste (buried) is 900 cubic feet. The 1995 INPO industry goalis 110 cubic meters (3,884 cubic feet) per year. The industry upper ten percentile value is approximately 27.33 cubic meters (965.3 cubic feet) per year.

Data Source:

Chase /Breuer (Manager / Source)

Accountability:

Chase /Lovett Trend:

None SEP54 38

m Primary system Chemistry Percent of Hours Out of Limit g]

_.o Fort Calhoun Goal (2.00%)

1 P 2%-

a

=

o 1%-_

Cycle 1F Refueling Outage 0%

i i

i i.

i j

i Jan Feb Mar Apr May Jun Jul Aug sep Oct Nov Dec

[ isis-l PRIMARY $YSTEM CHEMISTRY PERCENT OF HOURS OUT OF LIMIT l

The Primary System Chemistry Percent of Hours Out of Limit indicator tracks the primary system chemistry performance by monitoring 6 key chemistry parameters. The key pa-rameters are: lithium, dissolved oxygen, chlorides, flouride, hydrogen and suspended solids. 100% equates to all 6 parameters being out of limit for the month.

The Primary System Chemistry Percent of Hours Out of Specification was 0.00% for the month of December 1995.

The 1995 Fort Calhoun monthly goal for this indicator is a maximum of 2% hours out of limit.

Data Source:

Smith / Spires (Manager / Source)

Accountability:

Chase / Smith Trend:

Positive due to performance better than goal.

39

.- ~.

m SecondarySystem CPI e

12-Month Average IGOOD I

+ FortCalhounGoal(1.4) 1.6 __

1 f 1.5..

1.4 _

i 1.3._

se ~

a-1.2..

l

.y-1 I

I I

i I

i l

I I

Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 1995l l

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 1995 was 1.24. The 12-month average CPI value was 1.28 at the end of the month.

The Chemistry Performance Index (CPI) was above the goal in July due to slightly higher than average sodium and chloride values. Also the values provided as industry averages by INPO for 1995 are considerably lower than FCS historically has been able to achieve for secondary chemistry values. Iron, the one industry average that we are below, almost by half, does not assist in lowering the CPI because of the way the CPI is calculated.

Data Source:

Smith / Spires (Manager / Source)

Accountability:

Chase / Smith Trend -

Positive due to performance better than goal 40 1

CHEMISTRY ACTION LEVELS EXCEEDED lm Event Days + Average Event Days +Lrna l 4

3.5 _

2.5 E

g 1.s k

i E

I E

k I

k i

8 I

[

8 8

8

[R 8

M ONTH CHEMISTRY ACTION LEVELS EXCEEDED - EVENT DAYS The Chemistry Action Levels Exceeded indicator tracks the number of days in which chernistry parameters exceeded a corresponding action level for the reporting month, as well as a 12 month average of days an action levelis exceeded. The parameter action levels are delineated in Chem-istry procedure CH-AD-0003, Plant System Chemical Limits and Corrective Actions.

An action levelis considered to have been exceeded for the purpose of this indicator, whenever the parameter exceeds the CH-AD-0003 action level for the current system mode, with the excep-tion of the Steam Generators during Mode 1.

The Steam Generators are considered to have exceeded an action levelin Mode 1 when the plant power is greater than 30% and the power is changing less than 5% per day.

The number of event days can exceed the number of days in a month since each event is counted separately and there can be multiple events per day.

The 1995 Fort Calhoun goal for this indicator is the 12 month average of two went days per, month. There is no goal established for the number of event days per individual month.

Historical data is used to calculate the monthly average event days. The 12 month average was calculated by dividing the number of event days by the number of preceding months, until twelve months were reached.

For the month of December 1995 three (3) event days occured in which diesel fuel oil was above the specification for particulates in FO-1, DG-1, and DG-2 day tanks.

Data Source:

Chase / Spires Accountability:

Spires Trend:

None 41

Goal 5.00 1

4.00 3.00 2

5I at 2.00 1.00 0.00 i

i i

i Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Month PRIMARY SYSTEM LITHlUM % HOURS OUT OF LIMIT The Primary System Lithium Percent Hours Out of Limit indicator tracks the hours per month that the primary system lithium is out of specification.

The Primary System Lithium Percent Hours Out of Limit was 1.5% for the month of No-vember 1995.

The 1995 Fort Calhoun monthly goal for this indicator is a maximin of 5% hours out of limit i

,1 Data Source:

Chase / Spires (Manager / Source)

Accountability:

Spires Trend:

None 42

e l

l i

j l

s 4

1 COST i

l Goal: Operate Fort Calhoun Station in a manner that cost i

effectively maintains nuclear generation as an economi-l cally viable contribution to OPPD's bottom line. Cost con-l sciousness is exhibited at all levels of the organization.

f 43

f2-M Mk nth Avs a e

- l:,i'alu': 0".U!!.."l3" ' " * " " " ' ' ' " " ' * " " ' " *

t

+ INPO Industry Goal (99.5%)

+ Industry Upper 10% (99.7%)

100%

I a

e e

a e

e o

i c

c r

=

g

?.

I M

E 2

5 d

3

?

y ti.p.,y.

98 %

Jan Fe b Mar Apr May Jun J ul Aug Sep Oct Nov Dec Pmy CENTS PsR 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 1994 and 1995 revised budgets. The basis for the actual curve is the Financial and Operating Report.

The December 31 amounts are also shown for the prior years 1991 through 1994. In addition, the report shows the plan amounts for the years 1996 through 1999 for refer-ence. The basis for the dollars are the Nuclear Long Range Financial Plan and the 1995 Corporate Planning and Budget Review. The basis for the generation is provided by Nuclear Fuels.

The 12-month average unit price (3.16 cents per kilowatt hour for December 1995) aver-aged above the original budget due to 12-month generation not meeting the budget ex-pectations, and 12-month expenses exceeding the original budget..

Data Source:

Scofield/Jamieson (Manager / Source)

Accountability:

Scofield Trend:

None 44

g NuclearServices Dvision O Prh % ring Division g PbclearOperations Division g TotalNuclear 800.

7" 7ss 7se 7s 742 733 727 727 721 700_

600-500_

487 4ss 4s2 44 441 4:s 438 da 43 400_

300__

o 32 sei ses ist se too 57e 57s

~

,,7 tu tu in in 100_

0 i

i i

1

'l 1

I I

I Jan.93 Jan.94 Apr-94 Jul-94 Oct-94 Dec.94 Mar-95 Jun-95 Sep-95 l Actualstamng Level l STAFFING LEVEL The actual staffing levels for the three Nuclear Divisions are shown on the graph above.

The authorized staffing levels for 1995 and 1996 are:

Authorized Staffing l

1995 1996 439 432 Nuclear Operations Division 185 175 Production Engineering Division l

115 113 Nuclear Services Division l

739 720 Total Data Source:

Ponec/Kobunski (Manager / Source)

Accountability:

Ponec Trend:

None SEP 24 45

+ Spare Parts inventoryValue ($ Million) 16.6..

16.5.

16.4 __

16.3 4 g 16.2 __

i o 16.1 _-

E 16 __

15.9 __

15.6.

15.7 _-

15.6 g

Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec l1995l Spare Part. Inventory Vaiue The spare parts inventory value at the Fort Calhoun Station at the end of December 1995 was reported as $15,833,870.

Parts being resupplied and replenished following last outage.

Data Source:

Steele/Huliska (Manager / Source)

Accountability:

Willrett/McCormick Trend:

None*

46

l l

l i

i i

DIVISION AND DEPARTMENT l

PERFORMANCE l

INDICATORS i

i Goal: Achieve high standards at Fort Calhoun Station resulting in safe, reliable and cost effective power pro-duction.

47

g Corrective Maintenance g Preventive WaT6tenance g Non-Corrective /Plantimprovements Fort Calhoun Goal 1000 _

,34 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec l

l Non-Outage Maintenance Work Order Backlog l l1995l lg Total Mwos l

% Overdue = 49%

1 24 73 O___.

i -. -

Riorny Riorty Riorty R orty Rorty Total MWOs = 749 1

2 3

4 5

l MAINTENANCE WORKLOAD EACKLOGS 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 classification and priority. The 1995 goal for this indicatoris 400 non-outage corrective maintenance MWOs. The current backlog of corrective MWOs is 370. To ensure that the MWO backlog is worked in a timely manner, non-outage maintenance completion goals have been established as follows:

Goal Priority 1 Immediate Action 2 days Priority 2 Urgent 5 days Priority 3 Operational Concems 21 days Priority 4 Routine Corrective 90 days Priority 5 Non-Essential 180 days i

l Continued management attention is required.

Data Source:

Chase /Schmitz (Manager / Source)

Accountability:

Chase /Faulhaber Trend:

Adverse SEP 36 48

s h

i 4

i Ratio of Preventive to Total Maintenance 1

100%

90 %

j 80%

i 70%

60%.

l!!t l._,..l...i...,.l.i..i, n%

i

..i.._

... j. _

i j

Jan Feb Mar Apr May aun Jul Aug Sep Oct Nov Dec

{

l1995l 1

e Preventive Maintenance items Overdue

+ Fort Calhoun Goal j

2%.

9 f i

l

]

1%.

l 0%

i

.3 i

i l

Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec l

l1996j l

RATIO OF PREVENTIVE TO TOTAL MAINTENANCE &

PREVENTIVE MAINTENANCE ITEMS OvEnouE 3

The top graph shows the ratio of completed non-outage preventive maintenance to total com-pleted non-outage maintenance. The ratio was 47.84% for the month of December 1995.

The lower graph shows the percentage of scheduled preventive maintenance items that are overdue. During December 1995, 540 PM items were completed. All but 6 PMs were com-pleted within the allowable grace period or were administratively closed.

The 1995 Fort Calhoun monthly goal for the percentage of preventive maintenance items over-due is a maximum of 0.5%.

j Data Source:

Chase /Schmitz/Melstad (Manager / Sources)

Accountability:

Chase /Faulhaber Trend:

None SEP 41 & 44 49

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

e Rework as identified by craft e_. Fort Calhoun Goal (<3%)

6%..

s.e %

0.3 %

5% __

I 13: 4%..

3.8 %

0 3.2 %

3.2 %

f3%

2- %

>=

2.7%

2.8 %

2.6%

h s 2% _

b n.

1%.

n%

i l

l l

t 6

i l

Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec

[1995l PERCENTAGE OF TOTAL MWO. COMPLETED PER MONTH IDENTIFIED AS REWORK l

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

This indicator is calculated from the 15th November to the 15th of December, due to the delay in closing open MWOs at the end of each month.

The Fort Calhoun monthly goal for this indicator is <3%. A detailed review is conducted of rework items each month to identify generic concerns.

Data Source:

Faulhaber/Schmitz (Manager / Source)

Accountability:

Chase /Faulhaber Trend:

Improving 50

m MaintenanceOertime 12 Month Average Maintenance Omrtime GOO l l

o ratenshoun onune emi(10w 46%,-

1 I 40%._

35%._

i 30%._

l 25%.

I 20%.-

15% -.

u n

n x

x 10%._

o o_._

- o_-.-- o _ o

--oo-

--c 6%._

0%

l l

l i

l l

l j

i l

l Jan Feb Mar Apr May Jm Jul Aug Sep Oct Nov Dec 1995l MAINTENANCE OvenTime 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 4.0% for the month of December 1995. The 12-month average percentage of overtime hours with respect to normal hours was reported as 13.0 % at the end of the month.

The 1995 Fort Calhoun monthly "on-line" goal for this indicator is a maximum value of 10%.

Data Source:

Chase /Schmitz (Manager / Source)

Accountability:

Chase /Faulhaber Trend:

None 51 b...

. -. ~ - -

i l

Human Performana CRs(Maintenance) i 20 _

l 18 __

l 16 __

\\

=

l 14 -

13 l

l 3 12 __

Y 10 -

u g

8.

6_

No Information Anlable for the I

4_-

Months of Sept. and Oct.

l 2_

)

1 0

1 1

I i

i i

JW Aug Sep Oct Nov Dec PROCEDURAL NONCOMPLIANCE INCIDENTS (MAINTENANCE) i This indicator shows the number of Condition Reports related to procedural noncompli-i ance incidents assigned to the Maintenance Department.

J i

Data Source:

Faulhaber Accountability:

Chase /Faulhaber Trend:

None SEP 15,41 & 44 52

i 1

i A

I l

g% Scheduled ActivkiesCompleted l

N*"

0%Emement Activities 100.0% --

i 90.74 848%

ES%

85.1%

g4 l

80.e4 I

i 70.e4 j

60.0% __

l i

50.wk -

i l

40.0% -

i 30.0% -

247%

24.7 %

19.0 %

20.0% _

10.74-0.0%-_

i i

i Sep.95 Oct Nov Dec-95 DAILY SCHEDULE PERFORMANCE PERCENT OF SCHEDULED ACTIVITIES COMPLETED This indicator shows the percent of Integrated Plant Schedule activities completed on schedule. All work groups and activities are included.

The percent of emergent work is calculated as a percentage of the total number of sched-uled and emergent activities.

The 1995 Fort Calhoun monthly goal for completed scheduled maintenance activities is 85%.

Data Source:

Chase /Schmitz (Manager / Source)

Accountability:

Chase /Faulhaber Trend:

None SEP 33 53 1

m %dMarsthehuna01snistryinstrmatsarehaperatie N

_e 1996RrtCahanGal(174 l

Y 2rk.-

2e4.-

2F4.

2rk..

1F4..

1F4._

ifA.-

i 174._

174._

F4._

F4..

94._

2%._

E F4-I 1 '" I I

I i

1 I

l-I i

I Jan Rib Mar Apr IWhy JLn Jti Ag Sep Q:t Mw Dec 1996 IN-l.,1NE CHEMISTRY lNSTRUMENTS 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 1995, the percentage of hours the in-line chemistry system instruments were inoperable was 1.91%. The following instruments were out of service during the month:

CE-1547A - Primary Water Storage Tank Specific Conductivity; waiting to be replaced by ECN.

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.

Data Source:

Chase /Reneaud (Manager / Source)

Accountability:

Chase /Jaworski Trend:

None 54

_. _ _.. _.. _.. _. ~... _.. _ _ _ _ _ _ _ _ _ _ _ _ _ _.. _ _ _.. _.. ~..

4 j

m weste ProdsosaEachMonth(IGlogram2)

-e-Month 6y Aver age Weste Produced During the last 12 Months (4Glograms)

-e-- Port Cagenen MomeMy Average asel(150 kangrams) l l

- 4e-- Federala ser to MontMy Limil(Mex. of 1,000 kg) i

)

1000

=

l s00 -

4 l

t i

soo.

i 88' ~

l Jan Feb Ma*

Apr May Jun Jul Aug sep oot Nov Dec isesl HAzAnoousWasTe PnooucaD This indicator shows the total am3unt of hazardous waste produced by the Fort Calhoun i

Station each month, the monthly average goal and the monthly average total for hazard-ous west produced during the last 12 months This hazardous waste consists of non-i halogenated hazardous waste, ha logenated hazardous waste, and other hazardous waste Produced During the month of December 1995,0.0 kilograms of non-halogenated,0.0 kilograms of halogenated and 0.0 kilograms of other hazardous waste was produced The total haz-ardous waste produced during the last 12 months is 470.6 kilograms.

Hazardous waste is counted bas ed upon a full drum of waste.

The 1995 Fort Calhoun monthly average goal for hazardous wasta produced is a mam-mum of 150 kilograms.

Data Source:

Chase /Carls m (Manager / Source)

Accountability:

Chase / Smith Trend:

Positive 65

m Contan*nted. dation Controlled Area GOOD]

e Fort Calhoun Gbal(10*4 V

10*/* --

c o

l i

9'/..

I A*4 i

i i

j j

i Jan Feb kr Apr hy Jm Jul Aug Sep Oct Nov W

1995l l

CONTAMINATED RADIATION CONTROLLED AREA This indicator shows the percentage of the Radiologically Controlled Area that is contami-nated based on the total square footage. The 1995 monthly non-outage goal is a maxi-mum of 9.5% contaminated RCA.

At the end of December 1995, the percentage of the total square footage of the RCA that j

was contaminated was 9.4%.

Data Source:

Chase /Gundal(Manager / Source)

Accountability:

Chase /Lovett Trend:

Positive SEP54 56 9

Identifled PRWPs (Year to Date)

Fort Calhoun Goal (<20) 20 :

20 2

18.

a 16.

15 18 13 1

14 0

_ 15 l

14.

13 12 12.

10.

.g l-6-

4 4_

2-1 0

Jan Feb Mar Apr May Jun Jul Aug Sep oct Nov Dec p555]

RADIOLOGICAL WORK PRACTICES PROGRAM The Radiological Work Practices Program Indicator shows the number of Poor Radiologi-cal 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 1995, there were O PRWPs identified.

There have been 20 PRWPs in 1995.

The 1995 year-end goal for PRWPs is a maximum of 20.

Data Source:

Chase /Cartwright (Manager / Source)

Accountability:

Chase /Lovett Trend:

None SEP 52 57

O Documents Scheduled for Review g Documents Reviewed g Documents Overdue 200 -_

180__

160.

140_

120__

j 100

]

l 80 _

60.

40.

20 _

_k 0__

i.

j_

+

l mLp.

l E+

l l

+

l Jan Feb Mar Apr May Jun Jul Aug sep Oct Nov Dec

]

l1995l DOCUMENT Review i

This indicator shows the number of completeo, 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 Se-curity Plan, Maintenance Procedures, Preventive Maintenance Procedures, and the Op-erating Manual.

During December 1995, there were 185 document reviews scheduled, while 52 reviews were completed. At the end of the month, there were 8 document reviews more than 6 months overdue. There were 11 new documents initiated during December. Beginning in September, these figures include PED and NOD procedures.

Data Source:

Chase /Plath Accountability:

Chase /Jaworski Trend:

None SEP 46 58

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

j g system Failures Goool O Non-System Failures 1

Y 35 -

)

30 _

25.

21 21 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec N

j LOGGABLE/ REPORTABLE INCIDENTS (SECURITY)

This graph shows the Loggable/ Reportable incidents (Security) Indicator and depicts (1) the total number of loggable/ reportable incidents concerning system failures which oc-curred during the reporting month, and (2) the total number of loggable/ reportable inci-dents non-system failures concerning Security Badges, Access Control and Authoriza-tion, Security Force Error, and Unsecured Doors.

During the month of December 1995, there were 20 loggable/ reportable incidents iden-tified. System failures accounted for 17 (85%) of the loggable/ reportable incidents. Four (4) of the loggable events involved the PAP x-ray machine. Due to repeated problems, the manufacturer has agreed to replace the machine within the next 60 - 90 days. The non-system loggables included two (2) security badge incidents and a vital area door left unsecured.

This indicator provides information on security performance for Safety Enhancement Pro-gram (SEP) Item No. 58.

Data Source:

Sefick/Woerner (Manager / Source)

Accountability:

Sefick Trend:

None SEP 58 59

1

, Temporary Modifications >1-cycle old (RFO reoGed for removal) m Temporary Modifications >6 months old (Removable on-line)

+ Fort Calhoun Goals for >1 cycle and >6 months old e

e e

e y

Jan Feb Mar Apr May Jun Jul Aug sep Oct Nov Dec N

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 modi-fications removable on-line that are greaterthan six months old. The 1995 Fort Calhoun monthly goals for this indicator are zero. However, one temporary modification (BAST level indication) has been approved by management to exceed these goals due to cost effectiveness consider-ations (reference PED-STE-94-042).

There is currently 1 temporary modification that is greater than one-fuel cycle old requiring a refueling outage to remove: RC-3D cover gasket pressure indicator, which is awaiting comple-tion of MWO 940868, which is scheduled for a future refueling outage whenever cover gaskets are replaced, in addition, at the end of December 1995, there were 6 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-118, in which Licensing sent FLC 94-001 to the NRC 6/27/

95 for approval; 2) Control system for intensifier on HCV-2987, which is awaiting completion of ECN 94-280, scheduled for completion 2/96; 3) brace to instrument air (IA) header "T" to water plant, which is awaiting completion of ECN 94-482, scheduled for cornpletion 2/96; 4) braces on main IA header, which is awaiting completion of ECN 94-482, scheduled for completion 2/96; 5)

HE-3 Crane safety line, which is awaiting completion of ECN 95-054, scheduled for issue from DEN-Mehanical 1/12/96;. 6) "A" Channel RPS VHPT capacitor, which is awaiting completion of MR-FC-95-010, DEN-Electrical to issue a 1996 on-line mod; 7) Wire spliced on Inverter D bypass transformer EE-4R which has completion date of 2/29/96.

At the end of December 1995, there was a total of 26 TMs installed in the Fort Calhoun Station.

9 of the 26 installed TMs require an outage for removal and 17 are removable on-line. In 1995, a total of 44 temporary modifications have been installed.

Data Source:

Jaworski/ Turner (Manager / Source)

Accountability:

Jaworski/Gorence Trend:

ContinuedManagement Attention is Needed SEP 62 & 71 eo

m Total Modification Packages Open j

_o._ Fort Cahoun Year-End Goal

)

140,_,7 120 _

100.

80.

60 so 4.

M n

40 -

20._

0 _

92 93 94 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 95 OUTSTANDING MODIFICATIONS This indicator shows the total number of outstanding modifications (excludino outstandino modifications which are proposed to be cancelled).

Reporting

)

Cateaorv

'93

'94

'95

'96

'97

'98 Month Form FC-1133 Backlog /In Progress 0

0 0

Mod. Requests Being Reviewed 0

0 4

0 0

0 4

Design Engr. Backlog /In Progress 0

0 0

23 1

11 35 Construction Backlog /In Progress 5

0 12 6

0 0

23 Design Engr. Update Backlog /in Progress 0

3 4

0 0

0 7

i Totals 5

3 20 29 1

11 69 (outage + online)

(3+2)

(0+3) (7+13) (20+9) (0+1) (11+0)

(41+28)

At the end of December 1995,25 additional modification requests had been issued this year and 9 modification requests have been cancelled. The Nuclear Projects Review Committee (NPRC) has conducted 70 backlog modification request reviews this year.

The Nuclear Projects Committee (NPC) has completed 21 backlog modification request reviews this year.

A review of the repoits used to determine the total number of outstanding modifications and their various stages of accomplishment was undertaken at the request of the Nuclear Planning Department. The results of the review determined that the reports were not providing complete / accurate data. The reports have been corrected. The revised totals beginning with the March 1995 data are reflected in the current graph.

The 1995 year-end Fort Calhoun goal for this indicator is a maximum of 63 outstanding modifications.

Data Source:

Skiles/Ronne (Manager / Source)

Scofield/Lounsberry (Manager / Source)

Accountability:

Scofield/Skiles Trend:

None*

g,

80.

EARS Requiring Engineering Closeout - Not in Closeout 60 -

E sE O DEN

~

40 _

20.

~

O;O O;

- ;r

r

E: M;E 0

1 Oct Nov Dec Oct Nov Dec oct Nov Dec Oct Nov Dec 0-3 Months 3-6 Months 6-12 Months

>12 Months l

O Engineering Response g Closeout (SE) 20.

10 -

N M

0 i

i Priority 0 Priority 1 Priority 2 Priority 3 Priority 4 Priority 5 Priority 6 78 EARS 37 EARS Resolved 68 EARS on 33 Overdue Wrig j

and in SdusMe Reponses

Response

Closeog 88 E 28.W.

67.9*4 631f4 w om acesauts n n.

ENGINEERING ASSISTANCE REauEsT BREAKDOWN This indicator shows a breakdown of the number of EARS assigned to Design Engineer-ing and System Engineering. The 1995 year-end goal for this indicator is a maximum of 140 outstanding EARS.

Total EAR breakdown is as follows:

EARS opened during the month 2

EARS closed during the month 8

Total EARS open at the end of the month 115 Data Source:

Skiles/ Parsons (Manager / Source)

Accountability:

Jaworski/Skiles Trend:

None SEP 62 62 l

m__.

i

)

12 8 cc 18 a

C LC SEQ UT DEN 0-3 Months 3

8 3-8 Months ECN Status -Overall Backlog a Backlogged O Received a Completed 2R-a u

bb a

.. _=

- M. _

4 80.

Jul Aug Sep Oct Nov Dec s4%

s%

Design Engineering 250.

s 6

i Ms ths g

Mo hs

~

11 %

8%

'7 7s n

7' SE 100.

1 h E 3';; r; E -

~ = "

Jul Aug Sep Oct Nov Dec System Engineering 250,

2M ur ne o,

n, o,

s i LLLLLL.

~=

win'th.

Jul Aug Sep Oct Nov Dec Procurement /ConstrucEon

'S

't'"

25o.

lidiLidi 6 Jul Aug sep m

WDrafti% Closeout ENGINEERING CHANGE NoricE STATUS Data Source:

Skiles/ Parsons (Manager / Source)

Accountability:

Skiles/Jaworski Trend:

None SEP 62 63

_y_

m

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

l 5

78 gg PC TYPE I

DC TYP E P riority 10 5 I

P rio it

'"' $ Total Open ECNs = 547 88 Total Open ECNs = 544 O DEN - Closeout or Drafting Not Complete P ri P domy 5 MaintenancelConstruction/ Procurement Work Not Complete 5&s 142 i

5 System Engineering - Response, Confirmation Not Complete 14 %

5 DEN Engineering Not Complete

6 200 is t se s i

8 8

150 s1 1

s s

3 j

1M.

s r

g _

4 3

4 8

s P riority 0

i i

i Nov Dec 95 Jul A ug Sg g

70 %

,sr 2

i aa

=

, s.

.1 3.

7.

[a's 1

s4 a

51 8

l s

1 e

s 17 0

i i

i

, P riority Jul Aug Sep Oct Pbv Dec-95

,," 4 8

Substitute Replacement item ECNs Open 7

N-Priorey gg,

74 77 81 78 78 35 0

i i

i Priorey

)

Jul Aug Sep Oct Nov Dec-96 5&#

84

,,y Document Change ECNs Open as4 ENGINEERING CHANGE NoricES OPEN Data Source:

Skiles/ Parsons (Manager Source)

Accountability:

Skiles/Jaworski Trend:

None 64

g Administrative ControlProblem g Licensed operator Error g other Perconnel Error E Maintenance Problem O Design /constructionAnstallation/ Fabrication Problem a Equipment Failures 2.

1-l 0

Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov l1994l pH]

LICENSEE EVENT REPORT (LER) Root CAUSE BREAKDOWN This indicator shows the LERs by event date broken down by Root Cause Code for each of the past twelve months from December 1,1994, through November 31,1995. 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.

The cause codes are intended to identify possible programmatic deficiencies. For de-tailed descriptions of these codes, see the " Performance Indicator Definitions" section of this report.

There was one event in November 1995 that resulted in an LER.

Data Source:

Trausch/Cavanaugh (Manager / Source)

Accountability:

Chase Trend:

None 65

O Total Requalification Treining Hours g SimuistorTraining Hours a Non-Requalification Trahing Hours g Numberof Exam Failures 40 37 Nb M5 M

y 35 32 30 26 25 20

$7 16 15

~

1.5 2

12 10

.5 8

0 0

.5 4

5 3

2.5 3

2 0

0 0

0 _

l i

i i

Cycle Cycle Cycle Cycle Cycle CWie Cycle Cycle 94-7 95-1 95-2 95-3 95-4 95-5 95-6 95-7

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

l

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

ElCENSED 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 APO/EOP verification & validation, INPO commitments, GET, Fire Brigade, Safety Meetings, and Division Manager lunches.

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

Data Source:

Gasper /Guliani(Manager / Source)

Accountability:

Gasper /Guliani Trend:

None SEP 68 i

l

g SROExams EdinTriTslered O SRO Exams Passed O RO Exams Administered g RO Exams Passed 10 1

s i

=

1 1

5_

0 i

Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec PS1 I"1 blCENSE 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.

1 During the month of December 1995, there were 4 RO and 4 SRO exams given. All individuals pass the exams.

Data Source:

Gasper /Guliani(Manager / Source)

Accountability:

Gasper /Guliani Trend:

None SEP 68 67

__ _ _..._._... ~._.__.___._ _..

m OpenIRs >6 Months Old Open SignificantIRs 4

i i

+ TotalOpenIRs 600.

500_

400

~

274 249 22B 22 "2

c1 no ni as

,3 Jan 1%b Mar Apr May Jun Jul Aug Sep Oct Nov Dec 1994l 1995l OPEN INCIDENT REPORTS This indicator shows the total number of Open irs, irs greater than 6 months old, and the number of open significant irs.

Also, at the end of December 1995, there were 367 open irs. 274 of these irs were greater than 6 months old. There were 99 Open Significant irs at the end of the month.

These numbers have been restated to reflect the elimination of CARS from the system.

As of April 21,1995, CARS are no longer being issued. As of September 21,1995 inci-dent Reports are no longer issued. All future corrective actions will be documented on Condition Reports.

Data Source:

Conner /Plott (Manager / Source)

Accountability; Andrews/Phelps/Patterson Trend :

None 68

o WOdem a WOWNk soo.

~

m.

55 000.

MM 500.

bRuw 35 124

s 3B 100.

O j

i

i..

..i SepE Of Mar DuoM MWO PLANNING STATUS (CYCLE 17 REFUELING OUTAGE)

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

- Parts Holds - Planning Complete, Awaiting Parts

- System Engineering Holds - Awaiting System Engineering Input to Planning

- Planner Holds - Maintenance Planner has not completed planning the work package.

- ECN Hold - Awaiting Substitute Replacement items ECN from DEN.

Data Source:

Chase /Schmitz (Manager / Source)

Accountability:

Chase /Faulhaber Trend:

None SEP 31 69

1996 Outage Projects Status Report g Last Month a This Month 100 O For Schedule 90 __

80 __

70 __

60 _

i sr g 50 o

40 _-

32 32 31 31 lirri rt I 2324 23 22 1

2 i

i i

f is if

~}J n

3 i

s te d

g 8

a oI g;

g E

E 2

B E

i 3

4 5

la e

e

=

E Sp.ci i S ivic.. Engin.. ring Departm nt OVERALL PROJEcr STATUS (Cycle 17 Refueling Outag.)

This performance indicator shows the status of projects which are in the scope of the Cycle 17 Refueling Outage. SSED's goalis to have all projects completed by August 23, 1996,30 days prior to the Refueling Outage start date.

Data Source:

Jaworski/Swearngin (Manager / Source)

Accountability:

Jaworski/Boughter Trend:

None SEP 31 70

Baselsne Schedule for PRC Approyal

--G-Projected /ActualSchedule forPRC Approval

- -Fnal Design Pkg ir, sued (2 FD DCP Issued Pro rto 05/0195)

Total M odif cato n Packages (20)(9 Added After D5/0795) 9 -+

^ ^

+++--++++++++-+4+

+ + + - + + + +.

8.

E 7.

12

_! E 8 -

fr $ 5 -

3 ft 4 P

i{ 3.

j 2

/-_ ::::.

,1

/

=

o

!laEl!lllllE!!!lElliill3 N

5

~

m s a 3-3 PROGRESS OF CYCLE 17 OUTAGE (1996 MODIFICATION PLANNING)

(FROZEN SCOPE OF 9 OUTAGE MODIFICATIONS)

This indicator shows the status of Modifications approved for installation during the Cycle 17 Refueling Outage. Modifications added to the outage list after May 1,1995, are not part of this indicator. The data is represented with respect to the baseline schedule (es-tablished June 16,1995) and the current schedule. This information is taken from the modification variation report produced by Design Engineering Nuclear.

The goal for this indicator is to have all modification packages which were identified prior to May 1,1995, PRC approved by March 22,1996. 9 Modifications added after May 1, 1995, not included.

December 1995 Modifications added: 3 Deleted = 0 Graph corrected to represent the baseline schedule.

Data Source:

Skiles/Ronne (Manager / Source)

Accountability:

Phelps/Skiles Trend:

None SEP 31 71

+ Baseline Schedule for PRC Approval

,_. Projected /ActualSchedule for PRC Approal 10.

en SE9 S

l

}N

.E s_

h i"e o a 7

.8g 5a 0

=x 8

b8~

5__

i

,; ;i>i: ;;i;;;;ii

>l

.>>l 1855 2/1045 3/1745 4/21 S 5 5/2655 6/3055 8/455 9555 10/1345 PROGRESS OF 1995 ON-LINE MODIFICATION PL.ANNING (FROZEN SCOPE OF 9 MODlHCATIONS) l This indicator shows the status of modifications approved for on-line installation during 1995. The data is represented with respect to the baseline schedule (established 1/13/

95) and the current schedule. This information is taken from the Modification Variation i

Report produced by the Design Engineering Nuclear group.

The goal for this indicator is to have all modification packages which were identified prior to January 13,1995, PRC approved by October 30,1995.1 modification added after January 13,1995, not included.

This goal was met 09/21/95.

December 1995 Modifications Added: 0 Deleted = 0 Data Source:

Skiles/Ronne (Manager / Source)

Accountability:

Phalps/Skiles Trend:

None SEP 31 72

Baseline Schedule for PRC Approval

+ Projected / Actual Schedule for PRC Approval

._e._ RnafDesign Package issue

._x.

Total Modification Packages (10)(3 Added After 05/01/95) 6 w a.u.y.w a.x m.w a.u.+ a.,,m x x.4.,m a +.n w; w y + m,x + +.u n a +

x.x u-..wwx 5.-

Ey4--

h j 3__

E 5

3 g 2._

2 1--

0 i;. ; ; ; ;;;;;

i.

6/16/95 7/21/95 8/25/95 9/29/95 11/3/95 12/8/95 1/12/96 2/16/96 3/22/96 PROGRESS OF 1996 ON-LINE MODIFICATION PLANNING (FROZEN SCOPE OF 6 MODIFICATIONS)

This indicator shows the status of modifications approved for on-line installation during 1996. Modifications added to the on-line list after May 1,1995, are not part of this indica-tor. The data is represented with respect to the baseline schedule (established June 16, 1995) and the current schedule. This information is taken from the Modification Variation Report produced by Design Engineering Nuclear.

The goal for this indicator is to have all modification packages which were identified prior to May 1,1995, PRC approved by March 25,1996. 3 Modifications added after May 1, 1995, not included.

December 1995 Modifications Added: 2 Deleted = 0 Graph corrected to represent the baseline schedule.

Data Source:

Skiles/Ronne (Manager / Source) l Accountability:

Phelps/Skiles Trend:

None SEP 31 73

O 4

ACTION PLANS 74

4 Action PLANS 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 three (3) consecutive months.

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

. Industrial Safety Accident Rate (page 2)

. Maintenance Workload Backlogs (page 48)

The action plan for industrial Safety Accident Rate (page 2) is as follows:

REVERSING THE INDUSTRIAL SAFETY ADVERSE TREND Even though the goal of zero lost-time accidents will not be met in 1995, the emphasis on safety and the reporting of potential safety hazards are still high priorities. The standards for safety will be raised by making the following items part of the station's daily operations:

Promptly resolve safety problems.

Promptly follow-up safety training to supervisors / crew leaders.

Use the Near Miss forms to resolve potential safety concerns.

The action plan for Maintenance Workload Backlogs (page 48) is as follows:

A detailed review is being conducted to determine which stage of the maintenance process has a higher than expected backlog. Areas being reviewed are:

Planning Scheduled Maintenance Bulk Work 75 l

THERMAL PERFORMANCE IMPROVEMENT ACTION PLAN A. PROBLEM STATEMENT:

Plant heat Rate as measured by the INPO Performance Indicator has shown a decreasing performance trend. This is based on decreases seen in total station electrical output, turbine first stage pressure, condenser inlet / outlet differential temperature. and condenser vacuum compared to previous operating cycles. Another loss is suspected as a result of non-optimum operation of the condensate cooler which controls cooling water to the generator hydrogen coolers, generator stator coolers, and generator field rectifier banks. Operation of this cooler with temperatures below optimum values rejects excessive amounts of thermal energy to the river and decreases overall plant efficiency.

B. GOALS:

l 1.

Improve Plant Rate as measure by the INPO Performance Indicator above the OPPD goal of 99.6%.

2.

Improve Plant Heat Rate during periods when the river water temperature exceeds 65"F - 70*F.

3.

Improve Plant Efficiency to ensure maximum station electrical generation is achieved and maintained.

C. Action (s) Reauired to Accuiiviish Gals Reso.

Qatqt Comments

1. Review the calculations utilized to justify the power increase from 1420 MWT to 1500 MWT as it relates to sec00dwy S.E.

10/30/95 in Progress plant performance and the condenser evaluation completed during the 93/94 Power Upgrade Study.

76

_____s

.-_.-------y

.------------m-----

Action (s) Reauired to Accomplish Goals Reso Due Comments

2. Evaluate the temperature correction factor utilized to correct S.E.

Completed White Pater submitted actual plant heat rate data to design conditions for INPO to Supervisor-System reporting purposes. This mathematical correlation may not Engineering on 12/07/95 accurately reflect the plant derating experienced at elevated river water temperatures

3. Review current operations procedures for condensate cooler operations. Implement changes required to ensure a implement changes to l

minimum amount of heat is rejected to the river while S.E.

Completed OI-ST-1, P.C. No. 44466 providing sufficient protection for operating equipment.

approved 10/11/95.

4. Continue to evaluate operating plant systems to determine Currently, S.E.

components operating at less than optimum values or S.E.

Ongoing reviewing all plant requiring maintenance to ensure no impact on station parameters on a daily efficiency.

basis.

77 O

l l

Reso.

Date Due Comments l

Action (s) Reauired to Accomplish Goals S.E.

Ongoing Currently, working

5. Continue to develop better tools to monitor plant toward another program performance, development of better computer models to that will provide predict and quantify equipment performance impacts on computer analysis and station efficiency.

troubleshooting assistance.

l f

i

6. Complete EAR 95-077, Evaluation of Best Method of DEN /SYE Complete EAR response received Measuring Circulating Water Flow 10/30/95

7. Implement corrective actions as outlined in EAR 95-077 DEN /SYE Later Date to be determined t

using the ECN process by NPRC

?

i i

L 78

FAILED FUEL ACTION PLAN Problem Statement:

Fuel failures in Cycle 16 have caused elevated reactor coolant system activities subsequently resulting in higher radiological dose rates ( and exposures with access problems) as well as a fuel reliability indicator (FRI) which does not meet the performance indicator goal. The elevated FRI has resulted in lowering the plant performance indicator index to an undesirable value.

Goal:

Reduce the reactor coolant activity levels for Cycle 16 operations and take measure to achieve zero defect fuel performance for Cycle 17 and beyond.

Plan:

i The plant below is compromised of both short term corrective actions to address the Cycle 16 operations goals identified l

above and long term corrective actions for Cycle 17 and beyond.

SHORT TERM (CYCLE 16 OPERATIONS) l M

ACTION M

DATE DUE STATUS 1.

Evaluate replacement at two-mcron Stor in CVCS wwth one-Holthaus 1/31/96 Complete.1/4/96. Fdter replacement will micron Ster.

result in improved parbculate removal and consequentlylower dose rates.

1a.

Install one-micron filters in CVCS Lovett 01/31/96 2.

Evaluate bar: edits of increasing letdown flow.

Holthaus/Spilker 01/19/96 Previously evaluated in Radiological Analysis95-005, which supports increased letdown flow.

3.

Evaluate nood for and effectiveness of more frequent of Holthaus 01/12/96 Complete. 01/04/96. Reain bed effectve punlicanon and canonion beds.

in mirdmeng RCS actMty Resin beds replaced in November 1995.

79 4

ITEM ACTION RESP.

Date Due STATUS 3a.

Replace resin beds during Spnng 1996 outage.

Spires 03/22/96 4.

Prepere and issue Nuclear Network request for industry 01/12/96 Cci,.f;;;. 01/12/96. Transmitted expenencein reducang FRI.

proposed inquiry to Licenomg for Nuclear Network entry.

5.

Evaluate installation of silver mordenite filtration system Holthaus/ Spires 01,26/96 Received general (ui-J

'O for increased mdme removal.

information on system used at Savannah River Project.

6.

Identify number of old design assemblies to be placed Previously identified eight assemblies to in peripheral locatons for second cycle and consider Holthaus/Guinn 01/12/96 be placed on core penphery for second replacement with new design assembly.

cycle.

7.

Evaluate whether these assemblies could be used for Holthaus/Guinn 01/19/96 more than ona cycle to reduce cost.

8.

Determene if Westmghouse can supply ths above fuel Complete. 01/12/96. Weshnghouse has assemblies for Cycle 17. Also, can Fuels Divesson Holthaus/ Hanger 01/12/96 mdecated that they can fabncate the provide necessary uranium.

assemblies. Cost estimates by Fuels Divisson is approx.12M. Discount from Westmghouse also requested 9.

Evaluate Cycle 18 pretenary pattem same as 5 & 6 Holthaus/Guinn 01/19196 10.

Evaluate Cycle 19 preimnary pottem same as 5& 6 Holthaus/Guinn 01/19/96 11.

Analyze addllonal assemblies to be procured Holthaus/ Hanger 01/20/96 12.

Evaluated cost / benefit with assumption of Holthaus/ Hanger 01/26/96

$10,000/ person exposure 80

..m..

PERFORMANCE INDICATOR DEFINITIONS AUXILIARY FEEDWATER SYSTEM SAFETY SYSTEM CLEAN CONTROLLED AREA CONTAMINA710NS E 1,000 PERFORMANCE DiSINTEORATIONS/ MINUTE PER PROSE AREA The sum of the known (pionned and unplanned) unevedoble The personnel contammaten events in the clean controte: area.

hours and the estimated unevedeth hours for the oudery The indcotor tracks personnel performance for SEP #15 & 54.

feedwater system for the reportmg portod dMded by the crittel hours for the reportog period multipled by the number of trams CONTAMINATED RADIATION CONTROLLED AREA in the auxihery foodwater system.

The percertage of the Redeten Controlled Area, which includes COLLECTIVE RADIAT10N EXPOSURE the euxileary bulldog, the radvieste budding, and areas of the C/RP buildng, that is contameneted booed on the total square Colecthe rarse agicours is the total extemel whole-body done footage. TNs indestor tracks performance for SEP #54.

n received by an on-site personnel (includng contractors and visitors) during a time period, as measured by the DAILY THERMAL OUTPUT thermolummencent dosimeter (TLD). CoNective redeten esposure is reported in units of person-rem TNs indicotor tracks TNs indcolor shows the daily core thermal output es measured radioingical work performance for SEP #54.

from romputer point XC105 (in thermal rnogewetts). The 1500 MW Tech Spec limit, and tie urvnet portion of the 1495 MW FCS COMPONENT FAILURE ANALYSIS REPORT (CFAR) dedy goal for the reportng month are also shown.

SUMMARY

DIESEL GENERATOR RELIABILITY (26 Dernands)

The summary of INPO cologories for Fort Calhoun Staten with mgniAcantly higher (1245 standard deviations) feNure rates then This indcolor shows the number of fanures occumng for each the rest of the industry for en seghteen-month time period.

emergency diesel generator during the last 25 start demands and Failures are reported as wiga (i.e., pumps motors, men the last 25 lood<un demands steem stop valves, control element rnotors, etc.) cafegories DISASLING INJURY / ILLNESS FREQUENCY RATE Fanure Cause Categonne are:

(LOSS TIME ACCIDENT RATE)

AgeNormal Use -thought to be the conesquence of expected The indcotor is defined as the number of eccedents for aN utility west, agng, ondef-hfe, or normal use.

personnel permanently assigned to the stat 6on, invoMng days away from work per 200,000 men. hours worked (100 men-years).

Manufacturing Defect. a feNure attributobie to inadequate This does not include contractor personnel. The indicator tracks assembly or instel quality of the responsible -,,,~, ra or personnel performance for SEP #25,26 & 27.

system.

DOCUMENT REVIEW (SIENNIAL)

Engineering / Design a failure attr6butobie to the ir=*=rr

design of the responsible component or system.

The Domament Reviewindcolor shows the number of documents reviened, the number of documents scheduled for review, and the Other Devices a fauure attributable to a fenure or number of document reviews that are overdue for the reportng misoperation of another w,,,,,

or system, includ6ng monttt A document review is considsred overdue if the reviewis secociated dev6ces reot compiele withm stu months of the seeigned due date. The indicator tracks performance for SEP #46.

Maintenance / Action resultng from improper memtenance, lock of maintenance, or personnel errors that occur dunng EMEROENCY AC POWER SYSTEM SAFETY SYSTEM memtenance actMteson the s~,c.,~,

ra PERFORMANCE Testing Actko. resulting from improper testmg or personnel The sum of the known (planned and unplanned) unavailable end errors that occur dunng testing activities the ashmeted unsweitable hours for the emergency AC power eyelem for the reporting period dMded by the number of hours in initial Installation Error. caused by improper initied the reportmg period multiplied by the number of trains in the i

instensten of equipment emergency AC power system.

CENTS PER KILOWATT HOUR EMEROENCY DIESEL OENERATOR UNIT RELIABILITY The purpose of the indcator is to quantify the economical This indicator shows the number of failures that were reported durme opersaan of Fort Calhoun Stahon. The cents per idlowett hour the last 20,50, and 100 ernergency diese4 generator demande el the indcolor represents the budget and actual cents per kilowett Fort Coemun Stehon. Aino shown are trigger values which correiste to a higMed of

mt a unts diesel generators how obtained hour on a twelve-rnonth average for the current )eer. The h*

teses for the budget curve is the approved yearfy budget The y,

basis for the actual cune is the Financial and Operehng Report.

1) Number of Start Demands: All valid and inadvertent start demands, includog ou startenly demands and au start l

81

PERFORMANCE INDICATOR DEFINITIONS demands inst are sosowed by bed-run demands, whether by TNs inecator messues me total unrohetely of emergency diesel automebc or manuelinibation A start.only demand is a generators in general, unrohetely is the ratio of una====ful demand h which the emergency generator is started, but no operebons (starts or lood-runs) to the number of valid demands ellempt is made to load the generator Total unrebately is e combinsbon of etert unrelietely and lood-run unrelietely

2) Numiner of Start Fellures: Any failure within the emergency generator system that prevents the generator ENGINEERING ASSISTANCE REQUEST (EAR) from schaving specifled frequency and vollege is caseeafled BREAKDOWN es e veld shut ledwe. TNs includes any condmon identined in the course of mentononce inspections (with the This indicolor shows a breakdown, by age and priority of the emergency generator in standby mode) that definitely would EAR, of the number of EARS seeigned to Desegn Enginsonng have reeuned in e stort fedure if a demand had occurred.

Nuclear and Syelem Engineenng This indcator tracks performance for SEP #62.

3) Number of Load Run Demands: For a welld lood-run demand to be counted, sie lood-run ettempt must meet one ENGSIEERING CHANGE NOTICE (ECN) STATUS or more of the following crtner6e:

The number of ECNs that were opened, ECNs that were A) A lood-run of any duranon that results from a real carryleisd, and open backlog ECNs sweeng completion by DEN sutomenc or menuelinittsbon-fos the reporting month. This indestor tracks performance for SEP#62.

B) A lood-run test to satisfy the pionre lood and durabon as stated in each toers specificeuons ENGINEERING CHANGE NOTICES OPEN C) Other special tests in which the emergency generator This indcator breaks down the number of Engineering Change is expected to be operated for et least one hour wNie Naboom (ECNs) mm are sempned to Design Engmeenne Nucieer loaded with at least 50% of Rs design loed.

(DEN), System Engmeeting, and Maintenance. The graphs prov6de date on ECN Factly Changes open ECN Substitute

4) Nurberof Load Run Failures: A lood-run failure should Replacement items open, and ECN Document Changes open.

be counted for any reason in which the emergency This indestor tracks performance for SEP #62.

generator does not pick up load and run es predicted Failures are counted during any vehd lood-run demands EQUIPMENT FORCED OUTAGES PER 1,000 CRITICAL HOURS

5) Enceptions. Unsuccessful etwnpts to etert or load-run should not be counted as vehd demands or failures when Egulpmere forced outages per 1,000 crthcel hours is the enverse they can be attributed to any of the fotowing of the rneen time between forced outages caused by equipment folkses. The mean time is aquel to tne number of hours the A) Spurmus trips that would be bypeseed in the event of remotor is critical in a penod (1,000 hours0 days 0 hours 0 weeks 0 months ) dreided by the number en emergency of forced outages caused by equipment failures in that period.

B) Merwicton of equipmert that is not required during en EQUfVALENT AVAILABILITY FACTOR emergency This indcutor is dehned as the rate of groes evadable genersbon C) Intenbonel termmebon of a test because of abnormal to groes medmum generation, empreened as a percentage condsons that would not have resulted in major diseel Andable genersten is sie energy that con be produced if the unit generstar damage or repair.

is opersied et the medmum power level permitted by equipment and reguhtory arramens Medmum generemon is the onwgy that D) Marwietons or operstmg errors which would not have can be produced by a unit in a yven period if operated prevented the emergency generator from beng cormnuously at medmum cepeesty resterted and brought to load within a few mmules FORCED OUTAGE RATE E) A failure to start boceuse a porbon of the startmg system was diesbied for test purpose, if followed by e Tnis indcator is defined as the percentage of time that the unit successful elart with the starting system in its normal was unevetable due to forced events compared to the time shgnment planned for electrical genersbon Forced events are feNures or other unplanned condmons that require removing the unit from Each emergency generator feiture that results in the generator service before the end of the next weekend Forced events being declared inoperstdo should be counted as one demand and include start-up feMuros and events inibsted whHe the unit is in one leNure. Emploretory tests during corrective memtenance end reserve shutdown (I e., the unit is eveNoble but not in service).

the successful test that fotows repeir to verify operately should not be counted as demands or feNures when the EDG has not FUEL RELIABILifY INDICATOR been declared operable again.

This indcular is denned as the steady-state primary cooient 1-131 EMERGENCY DIESEL GENERATOR UNRELIABILITY activity, corrected for the tramp uranium contributen and 82

PERFORMANCE INDICATOR DEFINITIONS rermakzad to a common punicaten rate. Tramp uranium is fuel LICENSE CANDIDATE EXAMS whch has been defemead on reactor core intomals from previous defective fuel or is present on the surface of fuel elemords from Theindicator shcws the number of SRO and/or RO quizzes and the manufactunng process. Steady state is derned as exams that are administered and passed each rnonth. This continuous operation for at least three days at a power level that indcator tracks training performance for SEPW68.

cbw rot very more than + or -5%. Plants should conect data for the inckator at a power level above 85%, when possible. Plants LICENSED OPERATOR REQUALIFICATION TRAINING that did not operate at steady state power above 85% should collect data for this indcator at the highest steady-state power The total number of hours of training given to each crew dunng level attained dunng the month.

each cyde. Also provided are the simulator training hours (whch are a subset of the total training hours), the number of non-The donelty correction factor is the ratio of the specife vc'ume of REQUALIFICATION training hours and the number of exam codant at the RCS operating temperature (540 degrees F., Vf =

failures. This indcator tracks training performance for 0 02146) divided by the spectre volume of coolant at normal SEP # 68.

letdcun temperature (120' F at outlet of the letdown cooling heat exchanger, Vf = 0.016204), which results in a densRy correction LICENSEE EVENT REPORT (LER) ROOT CAUSE factor for FCS equal to 1.32.

BREAKDOWN GROSS HEAT RATE This indcator shows the number and root cause code for Licensee Event Reports. The root cause codes are as follows:

Gross heet rate is defined as the rate of total thermal energy in Brrbsh The mal Units (BTU) produced by the reactor to the total

1) Administrative Control Probiern - Management and gross electreal energy produced by the generator in !alowatt-supervisory defciencies that affect plant programs or hours (KWH).

actrAties(i.e., poor planning. breakdown or lack of adequate management or supervisory control, incorrect procedures, HAZARDOUS WASTE PRODUCED etc).

The total arnount (in Kilograms) of non-halogenated hazardous

2) Licensed Operator Error - This cause code captures meste, halogenated hazardous waste, and other hazardous waste errors of omisson/-,,,Un by licensed reactor operators produced by FCS each month.

during plant activities.

4 HIGH PRESSURE SAFETY INJECTION SYSTEM SAFETY

3) Other Personnel Error Errors of omission /commession SYSTEM PERFORMANCE committed by nordlicensed personnel involved in plant actMtes.

The sum of the known (planned and unplanned) unavailable hours and the estimated unavadable hours for ine high pressure

4) Maintenance Problem - The intent of this ca;:se code is to safety injecten system for the reporting penod divided by the capture the full range of problems which can be attributed crtcal hours for the reporting penod multipieed by the number of in any way to pvy.,c. tic dercencies in the mair:tenance trains in the high pressure safety injection system.

fmetional organization. ActMties included in this category are maintenance, testsng, surveillance, Calibraton and INDUSTRIAL SAFETY ACCIDENT RATE INPO radiaton protecton.

The rdester e defined as the number of accidents per 200,000

5) DesigrvConstructonAnstallatiorvFabrication Problem -

marwhours worked for all utility personnel permanently assigned This cause code covers a full range of prograrnmate to the staten that result in any of the following:

deGoences h the areas of design, construchon, installation, and fabricaton(i.e., loss of control power due to underrated

1) One or rnore days of restncted work (excluding the day of fuse, equipment not qualifed for the snvironment, etc.).

the accident);

w,

6) Equipment Failures (Electronic Piece Parts or

2) One or rnore days away from work (excluding the day of the Environmental 4telated Failures) This code is used for accident); and spurious failures of electronc pece-parts and failures due to rneteorologcal conditions such as lightning, ice, high

3) Fatalities winds, etc. Generelty, it includes spunous or one-tirne falures. Electric ww.ents included in this category are Contractor personnel are not included for this indcator, circut cards, redifiers, bestables, fuses, capacitors, diodes, resistors, etc.

IN4.!NE CHEMISTRY INSTRUMENTS OUT OF GERVICE LOGGABLE/ REPORTABLE INCIDENTS (SECURITY)

Total number of irwhne chemrstry instruments that are outaf-servueinthe Secondary System and the Post Accident Sampling The total number of secunty incidents for the reporting month Sptem (PASS).

depicted in two graphs.

This indcator tracks secunty performance for SEP #58.

83

-_~---.--

PERFORMANCE lNDICATOR DEFINITIONS MAINTENANCE OVERTIME procedures and other rnisceNoneous enelneenng holds), parts hold, (parte eleged, not yet ir=r*, parts not yet arrtved) and The percent of overtime hours compared to normal hours for planning hold Gob scope not yet completed). Montenance Work memtenance. This heludes OPPD personnel as well as contract Requests (MWRs) are sieo shown that have been identified for personnel the Cycle 17 Refuelino Outage and have not yet been corworted to MWOs.

MAINTENANCE WORKLOAD BACKLOGS NUMBER OF CONTRDL ROOM EQUIPMENT DEFICIENCIES This indketor shows the bacidog of ren-outage Maintenance Work Orders remowung open at the end of the reportmg month.

A control room equipment deficiency (CRD)is defined as any Maintenance cess,elfications are defined as follows:

component which is opereled or controlled frorn the Control l

Room, provides mdlasten or alarm to the Control Room, prendes Corrective Repeer and restoration of equipment or testing rap =Naies from the Control Room, provides automehc componertslhet have failed or are malfunchoning and are not actions from or to the Control Room, or provides a possive performin0 their intended funchon function for the Control Room and has been identelled as deliciert,i.e., does not perform under al conditens as designed Preventive Actions tehon to maintom a piece of equipment This doenihon also appises to the ARemote Shutdown Peneis Al-wlmin design operating condit6ons, prevent equipment failure, 179, Al-185, and Al-212.

and edend As Ife and are performed prior to equipment failure.

A plant component whsch is deficient or inoperable is consadored Mamionence en " Operator Work Around (OWA) Item" if some other schon is Non Corrective / Plant improvements actMties performed to implomont station improvements or to required by an operator to compensate for the condihon of the repeir non-pient equipment.

component. Some esemples of OWAs are:

Maintenance Work Priorttles are defined as:

1) The control room level indicator does not work but a local sight glass con be reed by an Operator out in the pient; Emergency - Condehons which significantly degrade station eefety or availability

2) A deAccent pump cannot be repowed because repiscoment parts require a long lead time for pu,e - tri, thus immediate Action - Equipment deficiencies which requiring the redundant pump to be operated conunuously; 4

significantly degredit station reliability. Potential for unit

]

shutdown or power reduction.

3) Special achons are required by an Operator because of equipment design problems These actions may be Operations Concern - Equipment deficiencsos which heder described in Operations Memorandums, Operator Notes, or stehon opershon may require changes to Operating Procedures, Essential - Rouhne corrective memtenance on essentiel

4) DeAcert plant equipment that is required to be used during Emergency OperatinD rocedures or Abnormal Operating P

station systems and equipment Procedures, Non Essential - Routine correcove maintenance on non-essenhel stehon systems and equipment.

5) System indicehon that provides crthcel information during normal or abnormal operations.

Plant improvement - Norw:orrective meintenance and plant i

This indecator tracks treintenance performance for SEP #36.

NUMBER OF MISSED SURVEK. LANCE TESTS RESULTING IN LICENSEE EVENT REPORTS MAXIMUM INDIVIDUAL RADIATION EXPOSURE The number of Surveillance Tests (STs) that result in Licensee The tabel maamum amount of redehon received by an intlMdual Event Reports (LERs) during the reporhng month. This indicator porean working et FCS on a monthly, quarterly, and annual beeis.

tracks missed STs for SEP #60 8 61, MWO PLANNING STATUS (CYCLE 17 REFUELING OPEN HCIDENT REPORTS OUTAGE)

The indcator dispisys the total number of open incident Reports The total number of Maintenance Work Orders that have been (irs), the number of irs that are greater then six months old and apprmed for inclusion in the Cycle 17 Refuehng Oute0e and the the number of open significant irs.

number that are ready to work (ports staged, plannmg compkte, and el otwr papenwurk ready for field use). Also included is the fHITSTANDING MODIFICATIONS number of MWOs that have been engmeenng holds (ECNs, 84 i

PERFORMANCE INDICATOR DEFINITIONS The number of ModRuhon Regusets (MRs) in any state between The percent of the number of completed maintenance actrvihes he neuence of a Modtyon Number and the complebon of the as compared to the number of scheduled meteenance actMhos drew 6ng update, each month. This percentage is shown for all momeonance crafts. Also shown are the number of emergent MWOs.

1) Form PC 1133 Backlogan Progress. This number Maintenance actMhes include MWRs, MWOs, STs, PMOs, represents modellcation requests that have not been plant calibrations, and other mecellaneous actMhes. This indcator approved during the reportog month.

tracks Maintenance performance for SEP #33.

2) Mosencation Requests Being Reviewed. This category PERFORMANCE INDICATORINDEX includes:

The indcolor hdex is calculated from a wesghted combinataan of A) Modificehon Requests that are not yet reviewed ten overperformance indicator values, which include Unit Capability Factor, Unit cepetWilty Loes Factor, HPSI, AFW, B) Modfication Requests being reviewed by the Nuc6eer Energericy AC Power System Unpionned Automehc Screme, Projects Review Committee (NPRC).

Collective Redehon Exposure, Fuel Rolleiblity. Thermal Performance, Secondary Syolem Cherrustry, Redehon Weste, C) Modfication Requests being reviewed by the Nuclear and Industrial Safety Accident Rate.

Projects Committee (NPC).

PREVENTABLE / PERSONNEL ERROR LERs These Modification Requests may be reviewed several tunes before they are approted for accomplishment or canceled Some This indicator is a breakdown of LERs. For purposes of LER of these Modencehon Requests are retumed to Engmeenng for event casesincehon, a

Preventable LER" is defined as:

mose informetson, some approved for evoluehon, some approved for study, and some approved for pionnmg Once pionning is An event for which the root cause is personnel error (ie.,

completed and the scope of the work is cieerty donned, these inappropnete schon by one or more indrviduais), inodoquele ModAcesion Requeels may be approved for accomphehment with administratrve controls, a design construction, installabon, a year anagned for construction or they may be canceled All of irdahahan, fabrication problem (invoMng work completed by these different phases require review.

or egerveed by OPPD personnel) or a maintenance problem (attributed to inodoquele or improper upkeep /repeir of plant

3) Design Engineering Backlogan Progrees Nuclear equipment). Also, the cause of the event must have occurred Plannmg has assagned a year in which constructen will be wilhin approdmetely two years of the " Event Date" specmed in completed and design work may be in progress the LER (e g., an event for which the cause is attributed to e problem with the onginal design of the plant would not be

4) Construction Backlogan Progrees. The Construction considered preventable).

Padege has been neued or construction has begun but the modification has not been accepted by the System For purposes of LER event classencebon, a " Personnel Error" Acceptance Committee (SAC).

LER is denned as follows:

5) Design Engineering Update Backlog 4n Progrees FE0 An event for which me root cause is inappropriate schon on the has received the Modification Compistion Report but the part of one or more indMduals (as opposed to being attributed drawings have not been updated to e department or a general group). Also,the inappropriale action must have occurred within approedmetely two years of The aim menhoned C _ 4,i, modrRcations do not include the " Event Dele" speciRed in the LER.

modifications which are proposed for cancellation-OVERALL PROJECT STATUS (REFUEUNG OUTAGE)

This indicator shows the status of the projects which are in the Addhonelly, each event cleosihed as a " Personnel Error" should I

scope of the Refusing Outage also be classilled as

Preventable

The indicator trends personnel performance for SEP llem #15.

I PERCENTAGE OF TOTAL MINDS COWLETED PER MONTH i

IDENTIFED AS REWORK PRIMARY SYSTEM CHEMISTRY % OF HOURS OUT OF I

UMIT l

The percentage of total h4Nos completed per month idonened as I

rewont Rework adMhos are idenhned by maintenance planning The percent of hours out of limit are for six pnmary chemetry and craft. Rework is: Any addihonal work required to correct parameters dMded by the total number of hours pannihia for the dotciencess decovered during a failed Poet Memtenance Test to month. The key parameters used are: Lithium, Chlortde, ensure the component / system posses subsequent Post Hydrogen, Deeolved Oxygen, Fluoride and Suspended Solids.

Maintenance Test.

EPRI hmits are used.

PERCENT OF COMPLETED SCHEDULED MAINTENANCE PROCEDURAL NONCOMPUANCE INCIDENTS ACTIVITES (MAINTENANCE) 85 1

PERFORMANCE INDICATOR DEFINITIONS The number of idenhfied incidents concoming maintenance Accident Monitoring instrumentaten Aunihery (and procedural protdems,the number of closed irs reisted to the use Emergency) Feedweler System, Combustible Gas Control, of procedures (includes the number of closed irs caused by Component Cooling Weier Syelem, Containment and procedural nancompimnos), and the number of closed procedural Cortenmort lecletion, Containment Cooient Systems, Control j

noncomptanoe lRs. TNe indcutor trende personnel performance Room Emergency Ventdation System, Emergency Core for SE #15,41 and 44.

Coolne Systems, Engineered Safety Features Instrumentation, Essenhol Compressed Air Systems, Essenhol or Emergency PftOGRESS OF CYCLE 17 OUTAGE MODIFICATION Service Water, Fire Delechon or Suppression Systems, i

PLANNING lecinhon Condoneer, Low Temperature Overpressure Protechon, Main Steam Line leoistoon Velves, Onette TNs indmetor shows the status of modifications approved for Emergency AC & DC Power w/Dietribuhon, Redishon-compiehon during the Refuehng Outege.

Monitortig Instrumentehen, Reactor Coolant System, Reector Core teoistion Cooling System, Reactor Trip System and l.

PROGRESS OF 19 ties ON4.INE MODIFICATION PLANNING instrumentehon, Recwculation Pump Trip Actuohon Instrumentshon, Residual Heat Removal Systems, Safety TNs indicator shows the status of modefleetions approved for Velves, Spent Fuel Systems, Standby Uquid Control System completion during 1995.

and Ultimate Heat Sink.

RADIOLOGICAL WORK PRACTICES PROGRAM SECONDARY SYSTEM CHEMISTRY PERFORMANCE INDEX The number of identrfled poor redmiogical work practices (PRWPs) for the reportmg month. This indeslor tracks The Chemistry Performance indau (CPI) is e cales dahan bened on redelogeel work performance for SEP #52.

the concentrabon of key impurities in the secondary side of the l

plant. These hoy impurities are the most likely cause of RADIO OF PREVENTIVE TO TOTAL MAINTENANCE &

detertorshon of the steem generators. Criterie for ceiculehng the PREVENTIVE MAINTENANCE ITEMS OVERDUE cpi are:

The robo of provereve mantenance (includmg survoiNence techng

1) The plant is et greater then 30 percent power; and and cohbrahon procedures) to the sum of non outage correctrue l

maintenance and preventive maintenance completed over the

2) the power is changing lues then 5% per day, i

l reporting period. The ratio, empressed as e percentage, is calculated bened on men-hours Also dispieyed are the percent The CPI is calculeled using the fonowing equehon l

l of preventive meintenance items in the rnonth that were not cortpleted or admmetratively closed by the scheduled dele plus CPI = (sodium /0 90) + (Chionde/1.70) + (Sulfste/t.90) +

e grace ponod equel to 25% of the scheduisd intervel. This (Iron /4.40) + (Copper /0.30)/5.

indestor tracks preventive maintenance actMties for SEP 841.

Where: Sodlum, sulfate and chionde are the montNy everage j

RECORDASLE INJURY / ILLNESS CASES FREQUENCY blowdown concentretens in ppb, iron and copper are montNy j

RATE time weighted everage feedwater concentrations in ppb. The denominelor for each of the five fadors is the INPO medan The number of injuries requiring more then normel first aid per value. If tie mordNy evere0s for a specific parameter is less then 200,000 man-hours worked TNs indmetor trends personnel the INPO median value, the median value is used in the performance for SEP #15,25 and 26.

calme=han.

REPEAT FAILURES i

SIGNIFICANT EVENTS The number of Nucteer Plant Rehabihty Date System (NPRDS) components with rnore than one failure and the number of SqpilAcert events are the events identified by NRC staff through NPRDS components wei more tim two feMuros for the eighteen-detailed acreening and evenustion of operating exponence. The month CFAR period.

screening process includes the daily review and reme"====) of al L

reported operahng reactor events, as wel es other operational SAFETY SYSTEM FAILURES data such as special tests or construchon actMhes An event identified from the screening process as e engruficant event Safety eyelem fetures are any events or conditens that could condulate is further evolusted to determine if any actual or prevent the fulflument of the enfaty functens of structures or potereld thrust to the heelh and eriety of the public was involved eyelems. If a system conents of multiple redundant outmystems Specific examples of the tyn of criteria are summertred as or trains, failure of eN trains constitutes e esfety system feMure.

fonows:

Failure of one of two or more trains is not counted as e oefety system failure. The definiten for the indcator parefois NRC

1) Degradation of important enfety equipment, reporhn0 requiremerts ln 10 CFR 50.72 and 10 CFR 50.73. The fotowmg is a het of the mejor esfoty systems, sul> systems, and

2) Unexpected plant response to e transient; components monitored for this indicator:

3) Degradshon of fuel integrtty, pnmary cootent pressure l

l 86 l

-- a-

---am-a-.- r u

m

---r ym-,

7 g

m

.o PERFORMANCE INDICATOR DEFINITIONS boundary,importent maa*=8 features; UNIT CAPASIUTY FACTOR

4) Scramwehcompicehon, The rate of the eveNebie energy genershon over a given tone period to the reference energy genershon (the energy that could

5) Unpoonned reisees of rodeactMty, be produced if the unit were operated conhnuously at fur power under reference ambient condihons) over the some time period,

6) Opershon outside the hmits of the Techneel Specmcohans, expressed es e percentage

7) Other.

UNIT CAPACITY FACTOR INPG signecent events reported in this indicator are SERs The not electncel energy generated (MWH) dMded by the (Signmcent Event Reports) whch inform utthhos of signmcent product of mammum dependable capacey (not MWe) hmos the events and lessons loomed identmed through the SEE-IN groes hours in the reportmg period empressed as e percent Not screening process.

electrical energy generated is the groes electrical output of the unit measured at the output terminais of the turbine generator SPARE PARTS INVENTORY VALUE rrunusthe normal station eennce loads during the groes hours of the reportmg period, expressed in megewett hours.

The doner value of the spare puts inventory for FCS during the reportmg perted.

UNPLANNED AUTOMATIC REACTOR SCRAMS PER 7,000 CRfTICAL HOURS STAFFING LEVEL This indcolor is denned as the number of unplanned automanc The octund stofRng level and the authonaed stoffmg level for the screms (reactor pretschon system logic actuohons) that occur per Nucteer Opershons DMeion, The Production Fngmeenng 7,000 hours0 days 0 hours 0 weeks 0 months of critical operation DMoun and me Nucteer Services DMaion This indicator tracks performance for SEP #24.

The value for this indcator is e=Armar8 by multiplying the total number of unplanned sulomate reactor screme in a specirc time STATION NET GEfERATION period by 7,000 hours0 days 0 hours 0 weeks 0 months , then dMdlng that number by the total number of hows crecel in the some hme period. The indicator is The not genersten (sum) produced by the FCS during the further denned as follows:

I reportmg rnonth.

f

1) Unplanned means1 Pet the scram was not en enhcipated part 1

TEMPORARY MODIFICATIONS of a planned test.

The number of temporary mechancel and electrical

2) Scram means the automehc shutdown of the reactor by a j

cortrigurohons to the plant's systems rapid inserton of nogshve reactMty (e g., by control rods, j

ligJld 61pecton system, etc.) that la caused by aceumswwt of the

1) Temporary conngurohons are denned as electnceljumpers, reactor protocean system. The scram signal may have I

elodrical blocks, mechancel jumpers, or macherucal blocks resulted from murandng e est point or may have been whch are kistened in the plant operating systems and are not spunous shown on the latest revision of the PalD, schemste, connection, wiring, or flow disgrams

3) Automesic means that the initial signal that ci.uesd ar*=hrwt

2) Jumpers and blocks which are instoned fu Surveulence of the reactor protect 6cn eyelem logic was provided from one Tests, Montenance Procedures, Ceutrebon Procedures, of the sensor's montonng plant parameters and condmons, j

Specol Procedures or Operehng Procedures are not remer men tu, manusi scram swechos or, manued turbine trtp consulered as temporary modmcebens unises the jumper or seedios (or pusMmmons) provided in the mein control room.

tweck romams in piece ener me test or procedure is comp 6ste l

Jumpers and blocks instoned in test or lab instruments are

4) Crtteel means that dunne the steady-state condition of the not corsidered es temporary modincatens.

reactor prior to the scram, me effective trumi er=*wwt (k, )

I f

was essenheNy equel to one,

3) Scaffoid is not considered a temporary medlAcehen.

Jumpers and blocks which are installed and for which MRs UNPLANIED CAPABILITY LOSS FACTOR have been submMed wil be conodored es temporary modmcobons untu fined resolution of the MR and the jumper The reto of 91e unplanned energy losses during a given period of or block is removed or is permanently reconied on the tme,to the rulerance energy genershon (the energy that could be dnewmps This indcator tracks temporary medlReshons for produced if the unit were opereled conhnuously at fun power SEP ss2 and 71.

under reference omtuent condmons) over the same time period, expressed as a percentage T>ERMAL PERFORMANCE UM'LANNED SAFETY SYSTEM ACTUATIONS. (INPO The rebo of the design groes heet rate (corrected) to the edpusted

+ DEFINITION) ectuel props heat rete, expressed es a poi.mntege 87

... = -... _. ~ -

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

4 PERFORMANCE INDICATOR DEFINITIONS l

The indcator is deAnod as Bio sum of the foHow6ng safety system actuohone

1) The number of unplanned Emergency Core Cockng System (ECCS) actushons that resuR from rescNng an ECCS actuation est point or from a spurioueAnadvertent ECCS signol.

2) The number of unplanned emergency AC power system actuations that result from a loss of power to a safeguards bus. An unplanned safety system actuation occurs when an actuation est pont for a esfoly system is reached or when a optstaus or inadvertent signal is generated (ECCS only), and major equipment in the system is actueled. Unplanned means that the system actuation was not part of a pionned test or evoluhon The ECCS actuohone to be counted are actuohons of the high preneure injection system, the low preneure insechen system, or the estely inseccan senis.

UNPLANNEO SAFETY SYSTEM ACTIONS.(NRC DEFINITION)

The number of safety system actuohone which include (gok) the High Preneure Safety :ngschon System, the Low Pressure Safety Ingscean System, the Safety injechon Tanks, and the Emergency Dieset Generators The NRC cinesificehon of esfoty system 1

actusbons includes achJebons when maior equipment is operated add when the logic systems for the above safety systems are chenenged.

VIOLATION TREND TNs indlcatoris defined as Fort Calhoun Stabon Cited Vloinhons and Non-Cited Vioishone trended over 12 months Additionally, Ceed Vloinhons for the top quartie Region IV plant is trended over 12 months (leggeng the Fort Calhoun Station trend by 2-3 morths). It is the Fort Calhoun Station goal to be at or below the ened v6onshon trend for the top quartde Region IV plant.

VOLUME OF LOW 4.EVEL SOUD RADIOACTIVE WASTE This indicator is defined as the volume of low-level eclid redoective weste actually eNpped for burtet This indmetor also shows the volume of low-level redloocthe weste which is in temporary storage, the amount of radioactive ou that has been shipped off-site for processeg. and the volume of solid dry redcocthe veste which has been sNpped off-elle for processing Low-level sohd rartmar*ve weste consists of dry active weste, sludges, reoris, and evaponster bottoms generated as a result of nucteer power pier t opershon and maintenance Dry redmectrve l

weste inchdas conernineted rags, oisenmg malertels, re rmaa j

protecthe ekshrig, penehe carneiners, and any other materted to be disposed of at a low-level redmecthe weste rearmaal elle, oncept resin, esudge, or evaporetor bottoms. Low-level refers to en redmeethe weste that is not spent fuel or a by-product of opent fuel procesemg This indmeter tracks radiciogmel work performance kr SEP #54.

88 l

SAFETY ENHANCEMENT PROGRAM INDEX The purpose of the Safety Enhancement Program (SEP) Performance Indicators Index is to list performance indicators related to SEP ltems with parameters that can be trended.

SEP Reference Number 15 Pese

. Increase HPES and IR Accountability through use of Per"rmance indicators Procedural Noncompliance incidents (Maintenance)........

52 Recordable injury / Illness Cases Frequency Rate...........

.......... 4 Clean Controlled Area Contaminations 11,000 Disintegrations / Minute Per Probe Area 5

Preventable / Personnel Error LERs............................

............ 6 SEP Reference Number 24

. Complete Staff Studies Staffing Level................................

45 SEP Reference Numbers 25. 26. & 27

. Training Program for Managers and Supervisors implemented

. Evaluate and implement Station Standards for Safe Work Practice Requirements

= implement Supervisory Enforcement of industrial Safety Standards Disabling injury /11l ness Frequency Rate........................

3 Recordable injury /lliness Cases Frequency Rate.............

4 SEP Reference Number 31

. Develop Outage and Maintenance Planning Manual and Conduct Project Management Training MWO Planning Status (Cycle 17 Refueling Outage) 6g Overall Project Status (Cycle 17 Refueling Outage)..

.. 70 Progress of Cycle 17 Outage Modification Planning

.................................. 71 SEP Reference Number 33

. Develop On-Line Maintenance and Modification Schedule Percent of Completed Scheduled Maintenance Actmbes (All Maintenance Crafts)

..... 53 SEP Reference Number 36

= Reduce Corrective Non-Outage Backlog Maintenance Workload Backlogs (Corrective Non-Outage)...........................

48 SEP Reference Numbers 41 & 44

. Develop and implement a Preventive Maintenance Schedule

. Compliance With and Use of Procedures Ratio of Preventive to Total Maintenance & Preventive Maintenance items Overdue............. 4g Procedural Noncompliance incidents (Maintenance).........

. 52 SEP Reference Number 46

. Design a Procedures Control and Administrative Program Document Review..............

58 89

O SAFETY ENHANCEMENT PROGRAM lNDEX SEP Reference Number 52 Eggs

. Establish Supervisory Accountability for Workers Radiological Practices Radiological Work Practices Program............................................ 57 SEP Reference Number 54

. Complete implementation of Radiological Enhancement Program Clean Controlled Area Disintegrations 11.000 CountsMinute Per Probe Area....

............ 5 Collective Rediation Exposure

..................17 Volume of Low-Level Solid Radioactive Weste.............

38 Contaminated Radiation Controlled Area

... 56 SEP Reference Number 58

. Revise Physical Security Training and Procedure Program Loggable/ Reportable incidents (Security)................

59 SEP Reference Numbers 60 & 61

. Improve Controls Over Surveillance Test Program

. Modify Computer Program to Correctly Schedule Surveillance Tests Number of Nhased Surveillance Tests resulting in Licensee Event Reports 21 SEP Reference Number 62

. Establish interirn System Engineers Temporary Modifications

........ 60 Engineering Assistance Request (EAR) Breakdown..................

62 Engineering Change Notice Status

........ 63 Engineering Change Notices Open...

...... 64 SEP Reference Number 68

. Assess Root Cause of Poor Operator Training and establish means to monitor Operator Training License Operator Requalification Training....................................... 66 License Candidate Exams

...................................................67 SEP Reference Number 71

. Improve Controls over Temporary Modifications Temporary Modifications

.................................... 60 90

4 REPORT DISTRIBUTION blST R. L. Andrews Nuclear Licensing K. L. Belek

& Industry Affairs (8)

B. H. Blome J. T. O'Connor C. E. Boughter W. W. Orr C. J. Brunnert T. L. Patterson C. A. Carlson R. J. Phelps G. R. Cavanaugh W. J. Ponec J. W. Chase C.R. Rice A. G. Christensen A. W. Richard O. J. Clayton D. G. Ried R. G. Conner T.G.Ronne J. L. Connolley M. J. Sandhoefner G. M. Cook F. C. Scofield S. R. Crites H. J. Sefick D. W. Dale C. F. Simmons D.C.Dietz E.L.Skaggs T. R. Dukarski J. L. Skilos M. L. Ellis F. K. Smith H. J. Faulhaber R. D. Spies (2)

M. T. Frans D. E. Spires S. K. Gambhir R. L. Sorenson J. K. Gasper K. E. Steele W. G. Gates M. A.Tesar S. W. Gebers J. J. Tesarek L. V. Goldberg J. W. Tills D. J. Golden D. R. Trausch D. C. Gorence J. M. Waszak R. H. Guy G. R. Williams A. L. Hale S. J. Willrett K. R. Henry J. B. Herman T. L. Herman K. C. Holthaus L. P. Hopkins C. K. Huang R. L. Jaworski R. A.Johansen J. W. Johnson W. C. Jones D. D. Kloock J. B. Kuhr (5)

L.T.Kusek M. P. Lazar B. R. LMngston O. L. Lovett N. L. Marfice T. J. Mcivor l

K. G. Melstad K. A. Miller P. A. Mruz j

l 91

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o FORT CALHOUN STATION OPERATING CYCLES AND REFUELING OUTAGE DATES EVENT DATE RANGE PRODUCTION (MWH)

CUMULATIVE (MWH)

Cycle 1 09/26/73 -02/08/75 3,299,639 3,299,639 1st Refueling 02/08/75 -05/11/75 Cycle 2 05/11/75 -10/01/74 3,853,322 7,152,961 2nd Refueling 10/01/76-12/13/76 Cycle 3 12/13/76 - 09/30/77 2,805,927 9,958,888 3rd Refueling 09/30/77 -12/09/77 Cycle 4 12/09/77-10/13/78 3,026,832 12,985,720 4th Refueling 10/13/78-12/24/78 Cycle 5 12/24/78 - 01/18/80 3,882,734 16,868,454 Sth Refueling 01/18/80 - 04/11/80 Cycle 6 04/11/80 - 09/18/81 3,899,714 20,768,188 Sth Refueling 09/18/81 -12/21/81 Cycle 7 12/21/81 -12/03/82 3,M1,866 24,330,034 7th Refueling 12/03/82 - 04/06/83 Cycle 8 04/06/83 -03/03/84 3,406,371 27,736,405 8th Refueling 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 - 01/14/86 Cycle 10 01/14/M -03/07/87 4,354,753 34,834,646 10th Refueling 03/07/87 - 06/08/87 Cycle 11 06/08/87 - 09/27/88 4,934,859 41,771,505 11th Refueling 09/27/88 - 01/31/89 Cycle 12 01/31/89 -02/17/90 3,817,954 45,589,459 12th Refueling 02/17/90 -05/29/90 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 54,022,013 14th Refueling 09/25/93 -11/26/93 Cycle 15 11/26/93 -02/20/95 5,043,887 61,065,900 15th Rofueling 02/20/95-04/14/95 FORT CALHOUN STATION CURRENT PRODUCTION AND OPERATIONS " RECORDS" First Sustained Reaction August 5,1973 (5:47 p.m.)

First Electricity Supplied to the System August 25,1973 Commercial Operation (180,000 KWH)

September 24,1973 Achieved Full Power (100%)

May 4,1974 Longest Run (477 Days)

June 8,1987-Sept. 27,1988 Highest Monthly Not Generation (364,448,800 KWH)

October 1987 Most Productive Fuel Cycle (5,451,069 MWH - Cycle 13)

May 29,1990-Feb.1,1992 Shortest Refueling Outage (52 days)

Feb. 20,1995-April 14,1995

_ _ _ _ _ _ _ _ _ _ _ _ _ _ _

ML20097H144

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