Text

FCS Performance Indicators Rept Mar 1996
	ML20108D079
Person / Time
Site:	Fort Calhoun
Issue date:	03/31/1996
From:	; OMAHA PUBLIC POWER DISTRICT
To:	;
Shared Package
ML20108D056	List: LIC-96-0060, Forwards FCS Performance Indicators Rept Mar 1996; ML20108D079;
References
	NUDOCS 9605070268
	Download: ML20108D079 (100)
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OMAHA PUBLIC POWER DISTRICT FORT CALHOUN STATION PERFORMANCE INDICATORS REPORT i

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l MARCH l

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l Production Engineering Division System Engineering i

MARCH 1996

FORT CALHOUN STATION March 1996 Monthly Operating Report OPERATIONS

SUMMARY

During the month of March 1996, the Fort Calhoun Station (FCS) operated at a nominal 100% power until March 14,1996, when power was reduced to start a scheduled maintenance outage. The pre-planned maintenance outage began on March 15,1996 at 1910 hours0.0221 days 0.531 hours 0.00316 weeks 7.26755e-4 months , when the plant was taken off-line and Mode 4 (Cold Shutdown) was entered at 1813 hours0.021 days 0.504 hours 0.003 weeks 6.898465e-4 months on March 18th. During control rod insertion, the Control Element Drive Meclanism (CEDM) #15 seal failed, resulting in an increased Reactor Coolant System (RCS) leak rate and causing a significant increase in containment activity.

While on-line during March, normal plant maintenance, surveillance, equipmerit rotation activities, and scheduled on-line modifications were performed.

Major activities scheduled and completed during the pre-planned maintenance outage included: replacement / rebuild of three CEDM seals; performance of minor maintenance on the Reactor Coolant Pumps (RCPs); reduction of operator work-arounds; and repair of Control Room Deficiencies (CRDs).

A scheduled modification replaced seven of thirteen 480 VAC breaker trip devices, with the%

remaining six motor feeder breaker trip devices scheduled to be replaced on-line.

On March 14th at 0843 hours0.00976 days 0.234 hours 0.00139 weeks 3.207615e-4 months , a 480 VAC Motor Control Center MCC-4A2 was removed from service for maintenance, and an eight-hour Limiting Condition for Operation (LCO) was entered in accordance with Technical Specification (TS) 2.7(2)g. At 0858 hours0.00993 days 0.238 hours 0.00142 weeks 3.26469e-4 months , while troubleshooting instrument loop noise, a technician shorted the AC leads causing the Al-40B instrument bus inverter to transfer power to the bypass transformer. The inverter transfered to bypass, and required entry into an eight-hour LCO in accordance with TS 2.7(2)h. However, TS 2.7 only allows one condition to exist at a time.

Per emergency procedure EPIP-OSC-1, Emergency Classification, a forced shutdown required by a TS requires a Notification of Unusual Event (NOUE). The Al-40B instrument bus was returned to its normal supply at 0905 hours0.0105 days 0.251 hours 0.0015 weeks 3.443525e-4 months . A notification was made to the NRC, as well as to the states of Nebraska and lowa, that conditions existed for declaration of a NOUE, but the NOUE was not declared since the condition was corrected in an expedient time frame. Subsequently, a Technical Specification Interpretation of Section 2.7 was generated and approved and the NRC notification was retracted.

i

On March 18th, while starting a containment purge release, a valid Ventilation isolation Actuation Signal (VIAS) occurred. A four-hour non-emergency notification was made to the NRC pursuant to 10 CFR 50.72(b)(2)(ii) for Engineered Safety Feature (ESF) Actuation. The Containment Stack Radiation Monitor (RM-052) initiated the VIAS while monitoring the Auxiliary Building Ventilation Stack. The RM-i 052 count rate exceeded its set point; however, through operator action to reduce the purge flowrate, the RM-052 count rate decreased below its set point and VIAS was reset. No release limits were exceeded at the site boundary. This event is described in Licensee Event Report (LER)96-001.

On March 21st he circulating water outfall to the Missouri Fiver was sampled for hydrazine, whicn is used as an oxygen scavenger in the condensate system, and was found to be 143 ppb. The National Pollution Discharge Elimination System (NPDES) permit limit is 100 ppb. A four-hour non-emergency notification was made to the NRC pursuant to 10 CFR 50.72(b)(2)(vi) due to the notification of other govemment agencies. The condensate system flush, which was the source of the hydrazine release, was terminated. A second sample was taken and indicated the release level dropped to 3 ppb. The cause for the high level of hydrazine is currently being investigated.

The maintenance outage was completed and the reactor was taken critical on March 24th. On March 25th at 0457 hours0.00529 days 0.127 hours 7.556217e-4 weeks 1.738885e-4 months , the turbine was placed on-line. A nominal 100% power was achieved on March 28th.

Following return to power operations, indications of a condenser tube leak appeared. On March 29th, a power reduction from 99% to 50% was started to allow a condenser to be isolated in order to troubleshoot and repair the suspected tube leak (s). At 2000 hours0.0231 days 0.556 hours 0.00331 weeks 7.61e-4 months , during the power reduction, the condenser tube leakage increased significantly, causing the plant to enter steam generator chemistry Action Level 2, requiring a power reduction to 30% power. At 2048 hours0.0237 days 0.569 hours 0.00339 weeks 7.79264e-4 months , a NOUE was declared to heighten management's awareness of a degrading plant condition. At 2018 hours0.0234 days 0.561 hours 0.00334 weeks 7.67849e-4 months , notification of the NOUE was made to the NRC pursuant to 10 CFR 50.72(a)(1)(i). At 2200 hours0.0255 days 0.611 hours 0.00364 weeks 8.371e-4 months , the condenser inleakage increased to a Chemistry i

Action Level 3, requiring the plant to reduce power below 5%. On March 29th, at 1

2235 hours0.0259 days 0.621 hours 0.0037 weeks 8.504175e-4 months , the reactor was manually tripped due to lowering condenser vacuum.

The NRC was notified of the termination of the NOUE and the manual reactor trh at 2312 hours0.0268 days 0.642 hours 0.00382 weeks 8.79716e-4 months on March 29th per 10 CFR 50.72 (b)(2)(ii). The condenser tubes were tested; the leaking tube was identified and plugged; and the plant was placed on-line March 31st at 0942 hours0.0109 days 0.262 hours 0.00156 weeks 3.58431e-4 months .

ii l

l

Five additional incore nuclear detectors failed in March 1996, rendering seven of the twenty-eight detector strings inoperable. All failures have occurred in detectors that were installed during the 1995 refueling outage. These failures are under investigation with assistance from ABB/CE and the incore detector vendor.

iii

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-w-. Industry Median Index Value 88 90 87 84 83 82 81 80.

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ChJarterly Value for 96/1 is 80.TI%

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93/3 93/4 94/1 94/2 94/3 94/4 95/1 95/2 95/3 95/4 96/1 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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FORT CALHOUN STATION PLANT PERFORMANCE INDICATOR INDEX 95/4 vs 96/1 Maximum Qtr 4,1995 Qtr 4,1995 Qtr1,1996 Qtr 1,1996 Index Point Index Point FCS Value INDEX POINTS FCS VALUE INDEX POINTS CHANGE (+/-)

UCF 16.0 89.10 15.70 87.89 15.34

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UCLF 12.0 5.70 7.40 5.37 7.7 0.30 HPSI 9.0 0.002 9.00 0.002 9.00 0.00 I

AFW 9.0 0.003 9.00 0.004 9.00 0.00 EACP 9.0 0.012 8.60 0.016 7.65

-0.95 Unplanned Auto. Scrams 8.0 0.90 8.00 0.44 8.00 0.00 Collective Rad.

Exposure 8.0 81.00 8.00 84.91 8.00 0.00 FR1 7.0 5.60E-03 1.30 7.57E-03 0.64

-0.66 Thermal Performance 6.0 99.30 4.00 99.32 3.96

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Second System CPI 6.0 1.49 3.40 1,41 3.93 0.53 RADWASTE 5.0 23.00 5.00 20.4 5.0 0.00 Ind. Safety Accident Rate 5.0 1.08 2.70 1.13 2.55

-0.15 Station index Value 82.10 80.77

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NRC Performance Indicators i

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FORT CALHOUN STATION PERFORMANCE INDICATORS REPORT March 1996 -

SUMMARY

POSITIVE TREND REPORT ADVERSE TREND REPORT A performance indicator with data representing three A performance indicator with data representing three consecutive months of improving performance or three consecutrve months of declining performance or three consecutive months of performance that is supenor to consecutive months of performance that is trending the stated goalis exhibiting a positive trend per Nuclear toward declining as determined by the Manager -

Operations Division Quality Procedure 37 (NOD-QP.

Station Engineering, constitutes an adverse trend per 37).

Nuclear Operations Division Quality Procedure 37 (NOD-QP-37). A supervisor whose performance The folowing performance indicators exhibited positive indicator exhibits an adverse trend by this definition trends for the reporting month:

may specify in written form (to be published in this report) why the trend is not adverse.

Safety System Failures (Page 7)

The following performance indicators exhibited adverse trends for the reporting month:

Hiah Pressure Safet r iniection System Safety System i

Performance Fuel Reliability Index (Page 8)

(Page 14)

Emeraenev A C. Power System Thermal Performance (Page 10)

(Page 33)

Emeraenev Diesel Generator Unreliabi!*v Maintenance Workload Backloas (Page 11)

(Page 47)

Diesel Generator Reliability f25 Demands)

Preventative Maintenance item Overdue (Page 12)

(Page 48)

Emeroenev Diesel Generator Unreliabihty End of Adverse Trend Report.

(Page 13)

INDICATORS NEEDING INCREASED Sionificant Events (Page 20)

MANAGEMENT ATTENTION REPORT Missed Surveillance Tests Results in Licensee Event A performance indicator with data for the reporting Reports period that is inadequate when compared to the OPPD (Page 21) goal is defined as *Needing increased Management Attention" per Nuclear Operations Division Quahty Secondary System Chemistry Procedure 37 (NOD-QP-37).

(Page 39)

Industrist Safety Accident Rate Contaminated Radiation Controlled Area (Page 2)

(Page 56)

Disablino Iniurv/Itiness Frecuenev Rate End of Positive Trend Report.

(Page 3) vil

FORT CALHOUN STATION PERFORMANCE INDICATORS REPORT March 1996 -

SUMMARY

INDICATORS NEEDING INCREASED MANAGEMENT ATTENTION REPORT (continued)

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

Forced Outaae Rate (Page 24)

Eauioment Forced Outaae Rate (Page 35)

Cents Der Kilowatt Hour (page 44)

Percentaae of Total MWOs Comoleted oer Month Identified as Rework i

(Page 50) j Temoorary Modifications 1

(Page 60) j PERFORMANCE INDICATOR i

REPORT IMPROVEMENTS / CHANGES 4

This section lists significant changes made to the report and to specific indicators within the report since the previous month.

No new additions were made to the P.I. book this month.

End of Report improvements / Changes Report.

i l

viii j

i

-1

Table of Contents / Summary G OA LS..............................................................

. xii SAFE OPERATIONS Industrial Safety Accident Rate - INPO.................................................. 2 Disabung injury / Illness Cases Frequency Rate........................................... 3 Recordable injury / Illness Cases Frequency Rate......................................... 4 Clean Controlled Area Contaminations

>1,000 Disintegrations / Minute 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 DieselGenerator Unit RehabiHty............................................................ 11 Reliability (25 Demands)

.......................................................12 Unreliability........

........................................................13 Fuel ReRabilty Indicator............................................................ 14 Control Room Equipment Deficiencies................................................... 15 On-Une and outage Control Room Deficiencies............

............................16 Collective Radiation Exposure..........

.........................................17 Maximum individual Radiation Exposure

.................................................18 Violation Trend

..............................................................19 Sig nificant Events........................................

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

...........23 Forced Outage Rate 24 Unit Capacity Factor

................25 Equivalent Availability Factor.......................................

.... 26 ix l

l l

Table of Contents / Summary PERFORMANCE fcontinued)

E&gg Unit Ca pa bi Bty Fa cto r............................................................. 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 Thennal Output..............................

............................ 34 Equipment Forced Outages per 1,000 Critical Hours

..................................35 Component Failure Analysis Report (CFAR) Summary

............. 36 Repeat Failures 37 Volume of Low-Level Solid Radioactive Waste

...........................................38 Secondary System Chemistry........................................................ 3 9 Chemistry Action Leve's Exceeded - Event Days....................................., 40 Primary System Lithium % Hours Out of Limit

...................................... 41 GSI.I Cents Per Kilowatt Hour........................................................ 43 Staffing Level 44 i

l Spare Parts inventory Value...............

......................................45 DIVISION AND DEPARTMENT PERFORMANCE INDICATORS Maintenance

)

Workload Backlogs (Corrective Non-Outage) 47 Ratio of Preventive to Total Maintenance & Preventive Maintenance Items Overdue 48 Percentage of Total IMos Completed per month identified as Rework 49

)

Overtime 50 Procedural Noncompliance Incidents 51 Daily Schedule Performance - Percent of Completed Scheduled Activities 52 X

l 1

l

Table of Contents / Summary DMSION AND DEPARTMENT PERFORMANCE INDICATORS PAGE in-Line Chemistry Instruments Out-of-Service......

...............................53 Hazardous Waste Produced...................

.............................. 54 Contaminated Radiation Controlled Area............

. 55 Radiological Work Practices Program............................................... 56 Document Review 57 Loggable/ Reportable incidents (Security)....................

.... 58 Modifications Te mpo ra ry........................................

59 Outstanding..........

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

61 Engineering Change Notices Status 62 O pe n........................

63 Licensee Event Report (LER) Root Cause Breakdown................

64 Licensed Operator Requalification Training..........................

.............65 License Candidate Exams.........

..... 66 Open incident Reports...........

............67 Cycle 17 Refueling Outage MWO Planning Status

......................................................68 Overall Project Status...........................................

70 Outage Modification Planning

.............. 71 On-Line Modification Planning.

72 Progress of 1996 On-Line Modification Planning.

72 ACTION PLANS. DEFINITIONS. SEP INDEX & DISTRIBUTION LIST Action Plans

. 73 Performance indicator Definitions 80 Safety Enhancement Program index 88 i

Report Distribution List........

. 90 xi I

a-OPPD NUCLEAR ORGANIZATION GOALS 1996 Priorities MISSION The safe, reliable and cost effective generation of electricity for OPPD customers through the p-ofessional 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 open communication.

1 l

1996 Priorities:

)

improve SALP ratings.

e lmprove 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.

6 OBJECTIVE 1-1:

I No challenges to a nuclear safety system.

4 OBJECTIVE 1-2:

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 1-4:

Achieve all safety-related 1996 performance indicator goals in the Performance Indicator Report.

OBJECTIVE 1-5:

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

4 4

1 xii

OPPD NUCLEAR ORGANIZATION GOALS 1996 Priorities Goal 2:

PERFORMANCE i

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.

1996 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 82% and a unit capability factor of 83.56%.

OBJECTIVE 2-2:

Execute the 1996 refueling outage in 42 days; emphasize shutdown plant safety.

OBJECTIVE 2-3 Achieve all performance related 1996 performance indicator goals in the Performance Indicator Report.

OBJECTIVE 24:

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 j

individuals as measured by the successful completion of department goals & objectives and other speciHc measures.

i Xiii

OPPD NUCLEAR ORGANIZATION GOALS 1996 Priorities Goal 3:

COSTS Supports: April 1994 Corporate Strategic Plan Goal 2, Obj: 1,2 and 3, and Goal 6, Obj: 1 l

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.

1996 Priorities:

Maintain total O&M and Capital Expenditures within budget.

Streamline work process to improve cost effectiveness.

Objectives to support COSTS:

OBJEC11VE 3-1:

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

OBJECTIVE 3-2:

Implement nuclear related Opportunity Review recommendations according to approved schedules ane attain the estimated cost savings.

1 l

Goals Source:

Scofield (Manager) xiv l

l

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.

1

+ Year-to-Date FCS Industrial Safety Accident Rate (INPO Definition)

,_. FCS Average Rate (Last 12 Months)

+ ICS Year-t:nd Goal <0.50

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c Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb Mar INDUSTRIAL SAFETY ACCIDENT RATE As stated in INPO's December 1993 publication ' Detailed Descriptions of Worid 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."

The INPO industrial safety accident rate value year-to-date was 0.61 at the end of March 1996.

The value for the 12 months from April,1995, through March 31,1996, was 1.13.

There were no restricted-time and one (1) lost-time accident in March 1996, following 178 days without a lost time accident.

The values for this indicator are determined as follows:

{ number of restricted-time accidents + lost-time accidents + fatalities) x 200.000 (ni:r.1;er of station person-hours worked)

The 1996 Fort Calhoun year 'end goal is 50.50. The Year 2000 INPO industry goalis 50.40. 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

1996 Disabhng Injuryfillness Frequency

__x_1995 Disabling injury / Illness Frequency

+ Average Rate (Last 12 Months)

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0 Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb Mar l1996l DISABLING INJURY / ILLNESS FREQUENCY RATE (LOST-TIME ACCIDENT RATE) 3 This indicator shows the 1996 disabling injury / illness frequency rate. The 1995 disabling injury /

illness frequency rate is also shown.

The disabling injury / illness frequency rate year-to-date was 0.607 at the end of March 1996.

There was one disabling injury / illness cases reported for the month.

The disabling injury / illness frequency rate for the 12 months from April 1,1995, through March 31,1996, was 1.56.

The 1996 Fort Calhoun year-end goal for this indicator is a maximum value of 0.5.

Data Source:

Sorensen/Skaggs (Manager / Source)

Accountability:

Chase / Bishop Trend:

Need increased Management Attention SEP 25,26 & 27 3

_ 1996 Recordable injuryAliness Frequency x

1995 Recordable injurylltiness Frequency I 0000 1 Average Rate (Last 12 Months)

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0 Apr May Jun Jul Aug sep oct Nov Dec Jan Feb Mar l1996l RECORDABLE INJURY /lLLNESS FREQUENCY RATE This indicator shows the 1996 recordable injury / illness frequency rate. The 1995 record-able injury / illness cases frequency 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 3 recordable injury / illness cases in 1996. The recordable injury / illness cases frequency rate year-to-date was 1.82 at the end of March 1996. There were 3 recordable injury / illness cases reported for the month of March.

The recordable injury / illness cases frequency rate for the 12 months from April 1,1995, through March 31,1996, was 1.56.

The 1996 Fort Calhoun year-end goal for this indicator is a maximum value of 1.5.

Data Source:

Sorensen/Skaggs (Manager / Source)

Accountability:

Bishop Trend:

None SEP 15,25,26 & 27 4

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[i3oODl FCS Goal (39 for 1996) 60 1 P 50 40..

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o $m-Jan Feb Mar Apr May Jun Jul Aug sep oct Nov Dec l1996l 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 21,000 disintegrations / minute per probe area for the reporting month.

There were 2 contamination events in March 1996. There has been a total of 3 contami-nation event in 1996 through the end of March. This compares to 28 at this time last year.

Data Source:

Chase /Cartwright (Manager / Source)

Accountability:

Chase /Gebers Trend:

None SEP 15 & 54 5

i e PersonnelErrors (Each Month)

+ Preventable (18-MonthTotals) g PersonnelError(18-MonthTotals) 20..

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sep Oct Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb l1996 PREVENTABLE / PERSONNEL ERROR LERs 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 February 1996, there were no events which were subsequently reported as an LER.

No LERs were categorized as Preventable or as Personnel Error for the month of Febru-ary. The total LERs for the year 1996 (through February 29,1996) is zero. The total i

Personnel Error LERs for the year 1996 is zero. The total Preventable LER9 for the year is zero.

The 1996 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:

Tills /Cavanaugh (Manager / Source)

Accountability:

Chase Trend:

None SEP 15 6

J

, ltartup Shutdown Operations l

}

...o... Industry Average Trend 2--

V i

S l

1 3

's 1 -.

G-..a......a

,,,.a,.....a,...,,

...a

...a.,,,

o zo 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 j

SAFETY SYSTEM FAILURES This indicator illustrates the number of NRC Safety System Failures as reported by the Nuclear Regulatory Commission's Office for Analysis and Evaluation of Operational Data in the biannual" Performance 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 for the borated water source of the safety injection system was not seismically qualified. This could have resulted in a failure of the system to meet design requirements during a seismic event.

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 iow 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 detennined 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 and 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

g Monthly High Pressure safety injection system Unavailability value

Year-to-Date High Pressure safety injection system Unavailability Value Good l Fbrt Calhoun Goal (0.003)

Year 2000 lNPO lndustry Goal (0.02) l f 0.02..

6 0.015.

0.01.

0.005.

o o

e o

o 0

O O

O o

0

- ; = =, x x ; _,

1994 1995 Jan Feb Mar Apr May Jun Jul Aug sep Oct Nov Dec C"' I HIGH PRESSURE SAFETY INJECTION SYSTEM SAFETY SYSTEM PERFORMANCE This indicator shows the High Pressure Safety injection System unavailability value, as defined by INPO in the Safety System Performance Indicator Definitions, for the reporting month.

The High Pressure Safety System unavailability value fer the month of March 1996 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 unavailability, during the month. The 1996 year-to-date HPSI unavailabiiity value was 0.0 at the end of the month. The unavailability value for the last 12 months was 0.00047.

There has been a total of 0.0 hours0 days 0 hours 0 weeks 0 months of planned unavailability and 0.0 hours0 days 0 hours 0 weeks 0 months of unplanned unavailability for the high pressure safety injection system in 1996 There was 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 unplanned unavailability for the high pressure safety injection system in 1995.

The 1996 Fort Calhoun year-end goalfor this indicator is a maximum value of 0.003. The Year 2000 INPO industry goal is 0.02.

Data Source:

Skiles/Schaffer (Manager / Source)

Accountability:

Skiles/Schaffer Trend:

Positive 8

m Monthly AuxiliaryFeedwater system Unavailability x

Year-to.Date AFW Unavailability l GOOD [

...o...

Fort Calhoun Goal (0.01)

Year 2000 INPO Industry Goal (0.025) 0.02,

3 3

3 0.018..

0.016..

0.014 0.012.-

0.01..

o.....o.....o.....o....e.....o.....o.....a.....e.....o.....o.....o 0.008..

o.co4ss 0.006..

o,co4sy

{

0.004.4.002s

.=

0.002..

O i

1994 1995 Jan Feb Mar Apr May Jun Jul Aug sep Oct Nov Dec l1996 l 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 March 1996 was 0.0019. There were 2.0 hours0 days 0 hours 0 weeks 0 months of planned and 0.0 hours0 days 0 hours 0 weeks 0 months of unplanned unavailability during the month.

The year-to-date unavailability value was 0.0005 and the value for the last 12 months was 0.0049 at the end of the month.

There has been a total of 2.0 hours0 days 0 hours 0 weeks 0 months of planned unavailability and 6.8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months of unplanned unavailability for the auxiliary feedwater system in 1996. The unplanned unavailability on FW-10 was due to a failed relay on HCV-1045B.

The 1996 Fort Calhoun year-end goal for this indicator is a snaximum value of 0.01.

The Year 2000 INPO industry goal is 0.025.

Data Source:

Skiles/Fritts (Manager / Source)

Accountability:

Skiles/Fritts Trend:

None 9

e Monthly Ernergency AC Power Unavailability Value x

Year-to-Date Emergency Ac Power Unavailability Value

1996 Fort Calhoun Goal (0.024) l Good l

_ Year 2000 INPo industry Goal (0.025) y 0.14._

0.12._

0.1._

0.08._

0.06 __

0.04 0.02.. 0 0

0 mx(1 x

x 0.

x @ x h x.

_x x.

x l

l Apr May Jun Jul Aug sep oct Nov Dec Jan Feb Mar 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 March 1996 was 0.0066. Dur-ing the month, there were 9.8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months of planned unavailability, and 0.0 hours0 days 0 hours 0 weeks 0 months of ur)olanned unavailability for testing and repairs. The Emergency AC Power System unavailability value year-to-date was 0.014 and the value for the last 12 months was 0.012 at the end of the month.

There has been a total of 30.5 hours5.787037e-5 days 0.00139 hours 8.267196e-6 weeks 1.9025e-6 months of planned unavailability and 0.0 hours0 days 0 hours 0 weeks 0 months of unplanned unavailability for the emergency AC power system in 1996.

The 1996 Fort Calhoun year-end goal for this indicator is a maximum value of 0.024.

The Year 2000 INPO industry goal is 0.025.

Data Source:

Skiles/Ronning (Manager / Source)

Accountability:

Skiles/Ronning Trend:

Positive due to performance better than goal.

10

m railuresI20 Demands a Failuresl50 Demands l

m Failuresf100 Demands lGoGDl

.__ Trigger Valuesco Demands Trigger Values /50 Demands l

E Trigger Values 100 Demands II 8..

7..

6 5..

4.

m. _.

2_

g9 y9 99 y9 y3 3

9y y

9 9

9 o

Apr May Jun Jul Aug sep Oct Nov Dec Jan Feb Mar l1996l 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 1996 goal is to have fewer failures than these trigger values.

i 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 i

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:

Skiles/Ronning (Manager / Source)

Accountability:

Skiles/Ronning Trend:

Positive due to performance better than goal.

11

DG1 Failures /25 Demands i

.. DG2 Failures /25 Demands CDODl o

1996 Goal 5.

4.

e 2

3 3.

2.

1 1

1

1. q q

0 0

0 0 0

0 0 ~

0 0

0 l

Apr May Jun Jtd Aug Sep Oct Nov Dec Jan Feb Mar 1996 DIESHL GENERATOR RELIABILITY (25 DEMANDS)

This indicator shows the number of failures experienced by each emergency diesel gen-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 1996.

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-ures during the last 25 demands on the unit. Diesel Generator DG-2 has experienced 1

one failure during the last 25 demands on the unit.

Special diesel testing during hot weather took place during July. This testing enabled the i

diesel high temperature operability limits to be raised.

l l

Data Source:

Skiles/Ronning (Manager / Source)

Accountability:

Skiles/Ronning Trend:

Positive due to performance batter than goal.

12

m DG1 UnreliabilityValue DG2 UnreliabilityValue

+ Station UnreliabilityValue l GOOD l

+ 1996 Goal 0.07 Y

0.06 0.05 __ e 0.04 __

0.03._

E"

'1' ' '

8 '88 c.02 s 0.02 0.01..

0 Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb Mar l1996l 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 March 1996 was 0.0. The 1996 goal for this indicatoris a maximum value of 0.05.

For DG-1:

There were 6 start demands for the reporting month with 0 failures.

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

For DG-2:

There were 6 start demands for the reporting month with 0 failures.

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

Emergency diesel generator unreliability is calculated as follows:

value per DG = SU + LU - (SU x LU) where SU = Start Unreliability

= number of unsuccessful starts number of valid start demands LU = Load-run Unreliability = number of unsuccessfulload-runs number of valid load-run demands Station Value = average of DG-1 and DG-2 values Data Source:

Skiles/Ronning (Manager / Source)

Accountability:

Skiles/Ronning Trend:

Positive due to performance better than goal.

13

Fuel Heliability(E-4)

{ GOOD l Year 2000 INPO Industry Fuel Defect Reference (5 x 10-4 Microcuries/ Gram)

_o 1996 Goal (9/1/96 through 12/31/96) 90. -

80 -_

i I

I I

i 1

1 Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb Mar l1996l FUEL RELIABILITY INDICATOR The FUEL RELIABILITY INDICATOR (FRI) for March 1996 was 78.42 X 104 microcuries/ gram. The purpose of the FRI is to monitor industry progress in achieving and maintaining a high level of fuelintegrity.

An effective fuel integrity and performance monitoring program provides a means to detect fuel failures and assess it.e fuel failure number, physical condition, exposure, mechanism, and location.

The March FRI value is based on data from March 1" through 14*. 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*,1995.. 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 March 14,1996. On March 15, a mini-outage powerdown commenced and the plant remained at zero per cent power until March 24, when power ascension began.

The plant then tripped on March 29. Ascension to 100% power began on March 31,1996.

The March FRI value of 78.42 X 10d microcuries/ gram indicated an increase from the February FRI value of 73.40 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 normalincrease 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 February 29,1996, performed by nuclear engineering, indicated five to ten 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 fuelinspection project.

The INPO "WANO Performance Indicator Program Utility Data Coordinator Reference Notebook" (INPO l

No.94-009, Rev.1) states the Industry Goal for fuel reliability is: " units should strive to operate with zero fuel defects". The 1996 Fort Calhoun Station FRt Performance Indicator goalis to maintain a monthly FRI below 5.0 x 10d microcuries/ gram. A value largerthan 5.0 x 10d microcuries/ gram indicates a high probability of reactor core operation stith one or more fuel defects. The 1996 year end goal can be met after the 1996 RFO. See page iii.

Data Source:

Bostelman/Riva Accountability:

Chase /Stafford Trend:

Adverse 14 i

1

!i i

e ControlRoom Deficiencies Added

, ControlRoom Deficiencies completed i

e Completed within Target Completion Date 50 _.

. 100.0 %

Goal.Conplate80%of C.R.Datumeruzes by Target ConpletenDate 40

"S' 80.0%.

as g

g

.g

3. s s s.e s ss 75 c

^

30 __

e s__60.0% y l

.g, ss.es g

i 9

T 2i

? 20 __

i 40.0 % I is

$s is g

g i

U to l

10 __

__ 20.0 % 8 O

0.0%

i Aug Sep Oct Nov Dec Jan-96 Fe b-96 Mar-96 f

Control Room Deficiencies i

j l

NUMBER OF CONTROL ROOM EQUIPMENT DEFICIENCIES l

This indicator measures the timeliness of closing Control Room Deficiencies.

Target Completion Dates are established by the Emergent Work Committee. The goal is l

to close at least 80% of all CRDs within the Target Due Date.

There were 36 Control Room Deficiencies completed during March 1996, and 29 were l

completed within the target completion date.

i 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 j

more timely completion of CRDs.

l i

l Data Source:

Chase /Kermoade (Manager / Source)

Accountability:

Short/Faulhaber Trend:

None f

15 i

i

Overdue Number of On-Une Control Room Deficiencies 30..

s.

[

25..

ss 2:

20 __

11 11 Goal. Lass then s overde n

i Aug Sep oct Nov Dec Jan46 Feb46 Mar 46 l Number of On-Une CRDs l Overdue Number of Outage control Room Deficiencies sy 15 -

Note: Overdue tems are those older than 18 rnorths 10 _

o,,,,y,,,,,,,,,,

5--

e a

s s

s 2

s s

0 Aug Sep oct Nov Dec Jan46 Fei46 Mar 46 l Number of Outage CRDs l NUMBER OF ON-LINE AND OUTAGE CONTROL ROOM DEFICIENCIES i

This indicator shows the total number of On-Line and Outage Control Room Deficiencies, and the number of overdue Control Room Deficiencies.

There were 11 on-line (4 were overdue) and 21 outage (2 were overdue) Control Room Deficiencies at the end of March 1996.

The 1996 Fort Calhoun goal for these indicators are less than 8 overdue on-line and no overdue outage Control Room Deficiencies.

Data Source:

Chase /Kermoade (Manager / Source)

Accountability:

Short/Faulhaber/ Herman Trend:

Needs increased Management Attention - Number of On-Line CRDs

<8 Overdue exceeds goal i

16 J

i g Monthly Personnel Radiation F.xposure

__,__ Cumulative Personnel Radiation Exposure

_.o___ Fcs Goal 136 person-REM g acoo-g U

li o

130._

120._

110..

100._

90..

l 80 __

70._

60._

50..

40._

30._

20 10..

O e Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec l 1996 l COLLECTIVE RADIATION EXPOSURE The 1996 Fort Calhoun goal for collective radiation exposure for the year is set a 138.0

.I person-REM.

The exposure for March 1996 was 9.009 person-Rem (ALNOR).

The year-to-date exposure through the end of March was 12.495 person-Rem (ALNOR).

j i

The Year 2000 INPO industry goal for collective radiation exposure is 120 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 4/93 through 3/96 was 108.63 person-1 rem per year.

[

Data Source:

Chase /Cartwright (Manager / Source)

Accountability:

Chase /Gebers Trend:

None SEP 54 s

17

l l

e Hghest WrtNy hdrvdual Exposure (1996) e_. Fort Calhoun Lirnt 1000 900.

800.

700_

600.

j 500.

400.

300.

244 200.

1CD.

O Jan Feb Wr Apr hy Jun Jul Aug Sep Oct ibv Dec 1996 MAXIMUM INDIVIDUAL RADIATION EXPOSURE During March 1996, an individual accumulated 244 mrem, which was the highest indi-vidual exposure for the month.

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

year. The 1996 Fort Calhoun year-end goal is a maximum of 1,000 mrem.

Data Source:

Chase /Cartwright (Manager / Source)

Accountability:

Chase /Gebers Trend:

None 18 i

l

1 e rc51:HeiFVl51strons (Monthly) r-~l FCS Non. Cited Violations (Monthly) c FCS Cited Violations (12 Month Average)

{Nl e

FCS Non Cited Violations (12. Month Average)

Region IV Cited Violations (12-Month Average for Region IV top quartile) l I q

14..

1 ((

6 - e 4..

-o

.C b

.E O

m

e

,m m

,m 1

D E

E D

2

,5 i

O E

c5 e

4 2

y u.

2 1996 VIOLATION 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 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 l

other Region IV plants.

The following inspections were completed during March 1996:

lER No.

Title 96-01 Resident Monthly inspection To date, OPPD has received three violations for inspections conducted in 1996.

Level 111 Violations O

LevelIV Violations 3

LevelV Violations 0

Non-Cited Violations 0

Total 3

The 1996 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:

Tills /Cavanaugh (f(anager/ Source)

Accountability:

Tills Trend:

None 19

NRC SigntScant Eivents B

,_. Industry Average Trend l

l GOOD l s

1 1 --

1 P 0.5._

0 m

r 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 lNPO Significant Events (SERs) 0000 2 T 1 1

1 1

1 lf 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 SIGNIFICANT 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 the biannual " 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:

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 rnain 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 quader of i992 and the 1st Quader of i995:

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.

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

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

Data Source:

Nuclear Regulatory Commission & INPO Accountability:

Chase Trend:

Positive 20

Missed STs Resulting in LERs 3..

GOOD l

V 2._

1 1__

0 0

i 93 94 95 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov 1996 NUMBER OF MISSED SURVEILLANCE TEST RESULTING IN LICENSEE EVENT REPORTS This indicator shows the number of missed Surveillance Tests (STs) that result in Lic-ensee Everit 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 March 1996.

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

The 1996 Fort Calhoun monthly goal for this indicator is 0.

Data Source:

Monthly Operating Report & Plant Licensee Event Reports (LERs)

Accountability:

Chase /Skiles Trend :

Positive SEP 60 & 61 21

I i

i l

I 1

l PERFORMANCE l

1 i

l l

Goal: To strive for Excellence in Operations utilizing the high-l est standards of performance at Fort Calhoun Station that j

result in safe, reliable plant operation in power production.

i I

l 1

i l

1 I

I 4

q i

i

Net Generation (10,000 MWh) l 34.75 35.08 M.12 g3 30.46 30.

Mini.

2 22.82 20.16 g 20..

15.29 g

g 10 l

0 l

I I

l' i

i l

I Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb Mar 1996 STATION NET GENERATION During the month of March 1996, a net total of 201699.5 MWh was generated by the Fort Calhoun Station. Cumulative net generation for Cycle 16 was 3548240.'l MWh at the end of the month.

Energy losses for March 1996 were attributed to (1) a planned mini-outage, and (2) con-denser tube leakage.

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 i

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.

Data Source:

Station Generation Report Accountability:

Chase Trend:

None 23

- - - ~

a Forced Outage Rate (Monthly)

+ Forced Outage Rate (12 Months) l GOOD l

+ 1995 Fort Calhoun Goal (1.4%)

40%..

3r 36%..

30%

25%

20%..

15%

10%

e s e

4 5

5 5

[

93 94 95 Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb Mar 1996 FORCED OUTAGE RATE The forced outage rate (FOR) was reported as 3.79% for the twelve months from April 1, 1995, through March 31,1996. The 1996 year-to-date FOR was 1.8% at the end of the month.

Energy losses for the month of March were attributed to a forced shutdown due to a condenser tube leak.

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 two separate shutdowns to repair com-ponent cooling water leaks in the lube oil system of RC-3D reactor coolant pump motor oil.

The generator was put on-line after replacement of all four of the reactor coolant pump lube oil cooler heat exchangers.

The 1996 Fort Calhoun year-end goal for this indicator is a maximum value of 1.4%.

Date Source:

Monthly Operating Report Accountability:

Chase Trend:

Naeds increased Management Attention 24

i Monthly Unit Capacity Factor i

...m... Year-to.Date Unk Capacky Factor g

Unit Capacity Factor for Cycles 15 & 16 36-Month Average Unit Capacky Factor l 0000 l 110 %

1996 FCS Goal (81.49%)

100 %

-a......a.....,,,

90% --

j

-=

.2

'~ E E

E 1---

.b.

N-N

.sr

.a 60%..

-[

50 %

40%..

30%..

20 %

10%..

0%

l l

l i

Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb Mar 1996 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 90.67%, and the Unit Capacity Factor for the last 36 months was 81.69%. The 1996 Fort Calhoun annual goal for this indicator is 82.00%.

The year-to-date value is 98.15%

Energy losses for March 1996, are due to the unit being shutdown for: 1) a planned mini-outage and 2) condenser tube leak repair.

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

The Unit Capacity Factor is computed as follows:

Net Electrical Enerov Generated (MWH)

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

Monthly Operating Report Accountability:

Chase Trend:

None 25

Monthly EAF Year-to-Date Average MonthlyEAF

+ 12-Month Average EAF

industry Median Value (74.7% for a 3. Year Average) 100%

e r.a s r

3 1

e s.s s A

L k~

L d

/

80%

?

=

x

=

r

=

f Q

60%. "O

~

40%..

j 4

20%..

0%

92 93 94 95 Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb Mar 1996 EQUIVALENT AVAILABILITY FACTOR This indicator shows the plant monthly Equivalent Availability Factor (EAF), the year-to-date average monthly EAF, and the year-end average monthly EAF for the previous three years.

The EAF for March 1996 was reported as 56.03%. The year-to-date monthly average EAF was 84.6% at the end of the month.

Energy losses for March 1996 are due to a scheduled " mini-outage" and condenser maintenance.

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 87.4%.

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

{

76.7%.

l Data Source:

DietzNandervort (Manager / Source)

Accountability:

Chase Trend:

None 1

26

Monthly Unit Capability Factor

...s...

Year.to-Date Unit CapabilityFactor O

36-Month unit Capability Factor 1996 Fort Calhoun Goals GOOD 2

INPo industry Goals Year 2000 h,0%..

,....,'.., N 80%..

3- - - - f - - +

3 5

j, 1

-V 7'~--

T

-^

.....e -

60%.

g.....

4*

40%..-

)

20%..

0%

i Apr May Jun Jul Aug sep oct Nov Dec Jan Feb Mar 1996 UNIT CAPABILITY FACTOR This indicator shr. us 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 March 1996 was reported as 54.5%. The year-to-date UCF was 81.2%, the UCF for the last 12 months was 87.4%, and the 36-month average UCF was reported as 83.9% at the end of the month.

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

Energy losses for March 1996 are due to a scheduled mini-outage and condenser tube repair.

The Year 2000 INPO industry goalis 87% and the industry current best quartile value (for the three-year period ending 12/94) is approximately 85%. The 1996 Fort Calhoun an-l nual goal for this indicator is a minimum of 83.56%.

Data Source:

Generation Totals Report & Monthly Operating Report Accountability:

Chase Trend:

None 27

l Monthly Unplanned Capability Loss Factor

-e Year-To-Date Unplanned CapabilityLoss Factor l GOOD l

+ 12-Month Average Unplanned Capability Loss Factor y

+ fort Calhoun Goal (3.00%)

e Year 2000 INPO Industry Goal (4.5%)

+ Industry Current Best Quartile 30%.

20%..

~~~

10 %

0%

bX

=

l Jan Feb Mar Apr May Jun Jul Aug sep Oct Nov Dec l1996l UNPLANNED CAPABILITY LOSS FACTOR This indicator shows the plant monthly Unplanned Capability Loss Factor (UCLF), the year-to-date UCLF and the goal. UCLF is defined as the ratio of the unplanned energy losses during a given period of time, to the reference energy generation (the energy that could be produced if the unit were operated continuously at full power under reference ambient conditions), expressed as a percentage.

The UCLF for the month of March 1996 was reported as 12.75%. Unplanned energy 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 4.34%, the UCLF for the last 12 months was 5.19%, and the 36-month average UCLF was reported as 4.9% at the end of the month.

The Year 2000 INPO industry goal is 3.0% and the industry current best quartile value is approximately 3.2% or lower. The 1996 Fort Calhoun year-end goal for this indicator is a maximum value of 3.0%.

Data Source:

Generation Totals Report & Monthly Operating Report Accountability:

Chase Trend:

Needs increased Management Attention.

28

._m

. e.-

FCS Reactor 5 crams Per 7,000 Hours Critical Year to-Date

+ FCS Reactor scrams Per 7,000 Hours Critical for last 36 rnonths

+ Fort calhoun Goal (04) i i

Year 2000 INPoindustry Goal (1)

--e-.

Industry Upper 10%(1 per 7,000 hours0 days 0 hours 0 weeks 0 months critical) 3..

A N

1 c a

e i

/;

A E

A O

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

{

1996 FCs Reactor scrams -1996 4..

3.

2 2

1 1

1_.

0 0

l i

92 93 94 95 Jan Feb Mar Apr May Jun Jul Aug sep oct Nov Dec

)

UNPLANNED AUTOMATIC REACTOR SCRAMS PER 7000 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 "snt 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 0.0 at the end of March 1996. The value for the 12

.nonths from April 1,1995, through March 31,1996 was 1.0. The value for the last 36 months was 1.22.

The 1996 Fort Calhoun goal for this indicator is 0. The Year 2000 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 Got I) 29

k e Safety System Actuations (INPo Definition)

+ FCS Goal (0)

+ IndustryUpper10 Percentile (0) 3..

2_.

I 1

1 1

1..

O o

o o

0 Ahw May [un Jul Aug sep Oct F[ov Dec [an ihb Mar 92 93 94 95 96 UNPLANNED SAFETY SYSTEM ACTUATIONS -(INPO DEFINITION)

There were no INPO unplanned safety system actuations during the month of February 1996.

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 gererator was brought back on-line at 3:43 p.m. on August 26th, after 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 1996 Fort Calhoun goal for this indicator is 0.

Data Source:

Monthly Operating Report & Plant Licensee Event Reports Accountability:

Skiles/Foley/Ronning Trend:

Positive 30

m safety System Actuations (NRC Definition)

(---) ICS Goal (0)

+ CriticalHours 12-Month Running Total SsAs (NRC Definition) 10..

.. 800 cyc= s

.. 700 Refumimg 8..

osse.

.. 600 8

6.

500 5

i E

.. 400 :E I

4

'il N 4.

3

.. 300 g

.. 200 2.

_=====-

.. 100 0

O

.... i i - > i i i i -

1 - > - ' -

92 93 94 95 FMAMJJAsONDJ FMAMJJASONDJFM

[1994l l1995j UNPLANNED SAFETY SYSTEM ACTUATIONS -(NRC DEFINITION)

This indicator shows the number of unplanned safety system actuations (SSAs), which includes the High and Low Pressure Safety injection Systems, the Safety injection Tanks, and the 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 1996 Fort Calhoun goal for this indicator is 0.

Data Source:

Monthly Operating Report & Plant Licensee Event Reports (LERs)

Accountability:

Skiles/Foley/Ronning Trend:

None 31

- - = - -. -

l i'

[

g Gross Heat Rate l

+ Year-to-Date Gross Heat Rate lGoool e._ Fort calhoun Goal 10.75..

q 7 10.5..

10.25.

e2n

,2, eme

~

M 10..

=

3

]

9.75..

1 f

9.5..

l 9.25 92 93 94 95 Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb Mar l

1996 GROSS HEAT RATE i

This indicator shows the Gross Heat Rate (GHR) for the reporting month, the year-to-date l

GHR, the goals and the year-end GHR for the previous three years.

l The gross heat rate for Fort Calhoun Station was 10,205 for the month of March 1996.

j The 1996 year-to-date GHR was 10,070 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 1996 Fort Calhoun year-end goal for this indicator is 10,166.

Data Source:

Bostelman/Willett (Managar/ Source)

Accountability:

Chase /Skiles Trend:

None*

32

g MonthlyThermalPerformance g

i 12-Month Average i

+ Year-to.Date Average MonthlyThermalPerformance o__ Fort Calhoun Goal (99.65Q l GOOD l

+ Year 2000 INPO Industry Goal (99.57.)

100%..

c c

c o

c ff 99%.

98 %

Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec l1996l j

l 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 1996 INPO industry goal and the approximate upper ten percentile value.

The thermal performance value for March 1996 was 99.02. The year-to-date average monthly thermal performance value was 99.10, at the end of the month. The average monthly value for the 12 months from April 1,1995, through March 31,1996, was 99.3%.

The 1996 Fort Calhoun year-end goal for this indicator is a minimum of 99.6%. The 1995 Fort Calhoun goal was a minimum of 99.5%. The Year 2000 INPO industry goalis 99.5%.

l j

Data Source:

Skiles/Naser(Manager / Source)

Accountability:

Skites/Gorence j

Trend:

Adverse 33

f

--*-- Thermal Output

-e-Fort Calhoun 1495 MW Goal

-*- Tech Spec 1500 MW Limit 1600 -

1400 -

)

1200 -

j 1000 -

800 -

z 600 -

400 -

200-0 s

1 2 3 4 5 6 7 8 9 10111213141516171819202122232425262728293031 DAILY THERMAL OUTPUT The thermal output graph displays the daily operating power level during March 1996, the 1500 thermal megawatt average technical specification limit, and the 1495 thermal megawatt Fort Calhoun goal.

Data Source:

Bostelman/Willett (Manager / Source)

Accountability:

Chase /Short Trend:

None 34

+ Number of Equipment Forced Outages (Monthly)

{coog Equipment Forced Outage Rate /1,000 CriticalHrs. (12-Month interval)

,_ Fort Calhoun Year-End Goals (0.2) q7 2..

1..

I c

=1

=

~

=

a 0

93 94 96 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec EQUIPMENT FORCED OUTAGES PER 1,000 CRITICAL HOURS The equipment forced outage rate per 1,000 critical hours for the 12 months from April 1, 1995, through March 31,1996, was 0.374. The year-to-date rate per 1,000 critical hours for the months from January 1996 through March 1996 was 0.51.

An equipment forced outage occured at the end of the March due to condenser tube leakage.

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 1996 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 /Skiles Trend:

Needs increased Management Attention 35

l

--9 b 39^a " A g

+

18.

- wcdegmes i

14 N

/

s/

j 6:

[

E 4

2.

0 N

D J-,6 F

M A

M J

J A

5 O

N D

J-96 F

M A gelN o rmal Us e is.s initial la s tallatio n 2.3 %

T estin, Actio n 4.7 %

M alate na nc e M a nuf a c turin, A c t6o n Defect

- ;;;;"=

.......,n,,D..,,,

m%

4.7 %

i l

COMPONENT FAILURE ANALYSIS REPORT (CFAR)

SUMMARY

The top chaft 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 June 1994 through November 1995). Fort Calhoun Sta-1 tion reported a higher failure rate in 5 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, con-trol 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 this report for descriptions of these categories) for the 43 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 72 failure rmorts were submitted to INPO with discovery dates within the 18-monm CFAR period.

Data Sou ca:

Skiles/ Frank (Manager / Source)

Accountability:

Skiles/ Dowdy Trend:

None 36

+ Components with more than One Failure

]

+ Components with more than Two Failures 15.

y 10..

7 6

6

\\

5 5.-

4 4

3 3

1 1

0:

Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb Mar 1996 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).

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

During tne last 18-mor2n CFAR period, there were 5 NPRDS components with more than one failure. One of these 5 NPRDS reportable components had more than two failures. Recommendations and actions to correct these 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:

125 VDC/120 VAC Static Inverter

+

HPSI Attemate Header isolation Valve Operator Air Intensifier, HCV-2987-O-1 (NPRDS Database specific tag number)

Reactor Coolant Pump Motor RC-3D-M Containment Cooling Coil VA-8B, CCW Outlet Valve V/P-403C (> 2 failures)

+

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

Skiles/ Frank (Manager / Source)

Accountability:

Chase Trend:

None 37

m Radioactive Waste Buried This Month (cu.ft.)

.ei Year-tocate Cumulative Radioactive Waste Buried l GOOD l

._o__ Fort Calhoun Goal (600 cu.ft.)

Y 6.00..

5.00..

ADO..

$ 3.00..

su 2.00..

i 1.00..

0.00 7

1 Jan Feb Mar Apr May Jun Jul Aug Sep oct Nov Dec 1996 VOLUME OF LOW-LEVEL RADIOACTIVE WASTE This indicator shows the volume of the monthly radioactive wr.ste buried, the cumula-tive year-to-date radioactive waste buried, the Fort Calhoun and INPO goals, and the approximate industry upper 10%.

Cu.Ft.

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

Volume of solid radwaste buried during current month

.6 Cumulative volume of solid radioactive waste buried in 1996

.8 Amount of solid radwaste in temporary storage 132.0 The 1996 Fort Calhoun goal for the volume of solid radioactive waste (buried) is 600 cubic feet. The Year 2000 INPO industry goal is 45 cubic meters (1,589 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 /Gebers Trend:

None SEP 54 38

l m secondarysystem GP1

_ o_12-Month Average l GOOD l

+ Fort Calhoun Goal (1 A) 1.6..

l f 1.5..

1A.

1.3..

.4

\\

l 1

i I

i i

1-1 l

l l

Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb Mar 1996 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 March 1996 was 1.26. The 12-month average CPI value was 1.28 at the end of the month.

The Chemistry Performance Index (CPI) has risen in January 1996 because the new INPO industry median values are in affect. These values are generally lower, while the Fort Calhoun Station values have not changed. This will continue to cause the Chemistry Perfromance Index to be higher than in the past.

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:

Spires /Reneaud (Manager / Source)

Accountability:

Spires Trend :

Positive due to performance better than goal 39

CHEMISTRY ACTloN LEVELS EXCEEDED l

Event Days + Average Event Days + Lrnit j 6..

5.

C 4.

5 s.

2

=

g 9

ins 0

E E

Y I

k I

f

[

k k

(

3 3

8 3

3 8

3 3

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

An action level is 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 level in 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 4

separately and there can be multiple events per day.

The 1996 Fort Calhoun goal for this indicator is the 12 month average of two event 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.

Two events occured in which hydrazine was low out of specification in the feedwater sys-tem due to problems with the chemical injection system. Four events occurred when a condenser tube failed causing four steam generatror parameters to exceed action levels.

Data Source:

Chase / Spires Accountability:

Spires Trend:

None 40

_. ~ =...

Goal 5.00 4.00 3.00 g

2.00 1.00 0.00 hy Jun Jul Aug Sep oct ibv Dec hn Feb Mar 1996 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 4.92% for the month of March 1996.

The 1996 Fort Calhoun monthly goal for this indicator is a maximum of 5% hours out of limit Data Source:

Chase / Spires (Manager / Source)

Accountabili'.y:

Spires Trend:

None 43

COST i

Goal: Operate Fort Calhoun Station in a manner that cost offectively maintains nuclear generation as an economi-cally viable contribution to OPPD's bottom line. Cost con-sciousness is exhibited at all levels of the organization.

42

Actual

_a__ Revised Budget Original Budget

+ Plan 4.

3.15..

3.s __

3.25..

3 3f_

E O 2.75..

2.5..

2.25.

2 D91 D92 D93 D94 D95 J96 F M A M

J J

A s

O N

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

The cents per kilowatt hour indicator represents the budget and actual cents per kilowatt hour on a 12-month rolling average for the current year. The basis for the budget curve is the approved 1995 and 1996 revised budgets. The basis for the actual ct.rvs is the Financial and Operating Report.

The December 31 amounts are also shown for the prior years 1991 through 1995. In addition, the report shows the plan amounts for the years 1997 through 2000 for refer-ence. The basis for the dollars are the Nuclear Long Range Financial Plan and the 1996 Corporate Planning and Budget R9 view. The basis for the generation is provided by Nuclear Fuels.

The 12-month rolling average unit price (period of March,1995 through February,1996) averaged below the budget due to 12-month rolling generation exceeding the budget expectations, even though the 12-month rolling expenses exceeded the budget. The 12-month rolling average (03/95 through 02/96) is 3.10 cents per kilowatt hour.

Cents per KWH Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Budget Y-T-D 2.79 2.84 2.76 2.76 2.78 2.76 2.73 2.75 2.81 2.97 3.10 3.11 Actual Y-T-D 2.91 2.77 Data Source:

Lounsberry/Jamieson (Manager / Source)

Accountability:

Lounsberry Trend:

Needs Management Attention 43

l l

i I

g Nuclear Serwces Division i

O Production Engineering Division g Nuclear Operations Division g TotalNur: lear

)

800__

7' '

7ss 7ss j

72 7 727 721 7,7 700--

ser j

600__

500..

487 4ss 4s2 a

m o

m 400.

l 300 "2

200-.

too tra 17s 57, l

tu 117 1

tu its 15 tu j

l 100 o

[

3 j

i j

Jan-93 Jan-94 Jar 95 Mar 95 Jun-95 Sep-95 Dec-95 Feb.96 Jun-96 ActualStarfing Level

)

STAFFING LEVEL l

{

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

l The authorized staffing levels for 1995 and 1996 are:

i Authorized Staffing 1995 1996 439 432 Nucisar Operations Division 185 175 Production Engineering Division 115 113 Nuclear Services Division 739 720 Total i

l Data Source:

Ponec \\Balis (Manager) l Accountability:

Ponec Trend:

None SEP 24 I

j 44 i

i

l Spare Parts inventoryValue ($ Minion) 16.3.

16.2.

l 16.1..

$ 16..

b 5

Eo E 15.9._

E 15.8..

15.7.

e 15.6 Apr May Jun Jul Aug Sep oct Nov Dec Jan Feb Mar 1996 SPARE PARTS INVENTORY The spare parts inventory value at the Fort Calhoun Station at the end of March 1996 was reported as $15,648,501.

Data Source:

Steele/Huliska (Manager / Source)

Accountability:

Willrett/McCormick l

Trend:

None*

45

l i

1 i

l i

i I

l DIVISION AND i

DEPARTMENT l

PERFORMANCE e

l INDICATORS l

l l

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

i i

?

i 1

]

i 1'

46 1

)

4

Corrective Maintenance e Preventive Maintenance Non-Corrective / Plant improvements Fort Calhoun Goal 1000..

759 771 782 800.. 760 668 671 726 752 600..

400_.

200..

o j

j j

i i

Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb Mar l Non-Outage Maintenance Work Order Backlog l l1996l Total MWos MWos Past a Total MWOsl 46%

Completion 1

0.

t '

'fM

'm i

i Priorty Priorty Priorty Priorty Priorty 1

2 3

4 5

MAINTENANCE WORKLOAD BACKLOG 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 1996 goal for this indicator is 400 non-outage corrective maintenance MWOs. The current backlog of corrective MWOs is 443. 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

Data Source:

Chase /Schmitz (Manager / Source)

Accountability:

Chase /Faulhaber Trend:

Adverse SEP 36 47

l l

l Ratio of Preventive to Total Maintenance 90%

l Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb Mar j1996l g Preventive Maintenance items Overdue l

_o_ Fort Calhoun Goal t

l 2%

1 P l

1%..

N ns i

i i

]

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

i RATIO OF PREVENTIVE TO TOTAL MAINTENANCE PREVENTIVE MAINTENANCE ITEMS OVERDUE i

The top graph shows the ratio of completed non-outage preventive maintenance to total com-j pleted non-outage maintenance. The ratio was 43.93% for the month of March 1996.

i

}

The lower graph shows the percentage of scheduled preventive maintenance items that are l

overdue. During March 1996,633 PM items were completed.

l The 1996 Fort Calhoun monthly goal for the percentage of preventive maintenance items over-due is a maximum of 0.5%

i Data Source:

Chase /Schmitz/Meistad (Manager / Sources)

Accountability:

Chase /Faulhaber i

Trend:

Adverse SEP 41 & 44 k

j 48 i

m Rework as identWied by craft e__ Fort Calhoun Goal (<3%)

6%..

s.e s 5%..

I 1

3: 4%__

.e s y

3.7%

s.2 %

s.2 s f3%_.

2%

2 %

t

... s I

j 2%..

2 1%._

1.;;iii g

j us o*4 i

_p_

_4 Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb Mar I "l PERCENTAGE OF TOTAL MWOs COMPLETED PER MONTH IDENTIFIED AS REWORK This graph indicates the percentage of total MWOs completed per month identified as rework. Rework activities are identified by maintenance planning and craft.

This indicator is calculated from the 15th of February to the 15th of March, due to the l

delay in closing open MWOs at the end of each month.

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

Data Source:

Faulhaber/Schmitz (Manager / Source)

Accountability:

Chase /Faulhaber Trend:

Improving

_.m.

..___m_.-

m Maintenance overtime

12. Month Aserage Maintenance Overtime IGooDI i

_s Fort Calhoun "on-Line" Goal (10%)

I I

35%..

I I I

)

l 30%.

25%..

j i

20%..

15%..

i 10%..

____o e

o o__ _.o___

0%

i i

.... q.

..p.

i.

j Apr May Jun Jul Aug Sep oct Nov Dec Jan Feb Mar F'*1 MAINTENANCE OVERTIME The Maintenance Overtime Indicator monitors the ability to perform the desired mainte-nance activities with the allotted resources.

The percent of overtime hours with respect to normal hours was reported as 28.00% for the month of March 1996. The 12-month average percentage of overtime hours with respect to normal hours was reported as 12.0 % at the end of the month. The high overtime value for the month can be attributed to the planned " MINI-OUTAGE".

The 1996 Fort Calhoun monthly "on-line" goal for this indicator is a maximum value of 10%.

i i

Data Source:

Chase /Schmitz (Manager / Source) l Accountability:

Chase /Faulhaber Trend:

None 50

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

}

l l

l Human Performance CRs(Maintenance) 20 _ _

{

18.

j i

16.

14.

13 3 12..

i 10.

5 2

g 8.

6" No information Available for Oct.

4..

2__

0 i

l I

I i

l Oct Nov Dec Jan Feb Mar PROCEDURAL NONCOMPLIANCE INCIDENTS (MAINTENANCE)

This indicator shows the number of Condition Reports related to procedural noncompli-ance incidents assigned to the Maintenance Department.

i Data Source:

Faulhaber Accountability:

Chase /Faulhaber Trend:

None SEP 15,41 & 44 51

i A

l g% Scheduled Activities Completed I

i

{ GOOD]

l 0% Emergent Activities 100.0%..

87.6%

l 90.0%..

85.1 %

83.2%

80.0%..

70.0% -_

67.0%

i l

60.0%

l l

50.r4 i

l 40.rs..

30.0%.-

4.7%

3.4%

.8%

i 9.0%

9.0%

20.0%..

l 10.0%..

i l

0.0%.

l l

i

- -t i

Nov Dec-95 Jan 86 Feb-96 Mar-96 l

DAILY SCHEDULE PERFORMANCE PERCENT OF SCHEDULED ACTIVITIES COMPLETED i

l This indicator shows the percent of Integrated Plant Schedule activities completed on l

schedule. All work groups and activities are included.

i i

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

I The 1996 Fort Calhoun monthly goal for completed scheduled maintenance activities is j

85%.

l Data Source:

Chase /Schmitz (Manager / Source) l Accountability:

Chase /Faulhaber Trend:

None SEP 33 a

j' 52 i

i 4

m % of Hours the in4.ine Chemistry instruments are Inoperable GOOD 1996 Fort Calhoun Goal (10%)

i 26%..

Y 24%..

22%.-

20%..

Un::

14%._

12%._

10%-.

8%..

M i

i j

i

.i i

,i i

i i

Apr May Jun Jul Aug sep oct Nov Dec Jan Feb Mar l1996l IN-LINE CHEMISTRY INSTRUMENTS OUT-OF-SERVICr 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 March 1996, the percentage of hours the in-line chemistry system instru-ments were inoperable was 6.18%. The following instruments were out of service during the month:

SL PASS Containment Grab Sample; leaking fitting in sample circuit.

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 /Skiles Trend:

None 53

e Waste PrMeari Each Month (Kilograms) e_ Fort Calhoun Monthly Average (bal(150 kilograms)

Federal & state Monthly Limit (Max. of 1,000 kg) 1000; x

x x

i 800..

i

, 600..

E P

E 2 400.

200.

c a

O i

i Apr May Jun Jul Aug Sep oct Nov Dec Jan Feb Mar l1995l HAZARDOUS WASTE PRODUCED This indicator shows the total amount of hazardous waste produced by the Fort Calhoun Station each month, the monthly average goal and the monthly average total for hazard-ous wast produced during the last 12 months. This hazardous waste consists of non-halogenated hazardous waste, halogenated hazardous waste, and other hazardous waste i

produced.

l During the month of March 1996,0.0 kilograms of non-halogenated,0.0 kilograms of halogenated and 0.0 kilograms of other hazardous waste was produced. The total haz-crdous waste produced during the last 12 months is 51.5 kilograms.

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

The 1996 Fort Calhoun monthly average goal for hazardous waste produced is a maxi-mum of 150 kilograms.

Data Source:

Chase /Shubert (Manager / Source)

Accountability:

Chase / Spires Trend:

Positive 54

m contaminated Radiation Controlled Area Fort Calhoun Goal (10%)

I I 10%._

e I

9%..

8%

l.

l

.. g g

.g g

4

_ _9_

g y

g Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb Mar 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 1996 monthly non-outage goal is a maxi-mum of 10.0% contaminated RCA.

At the end of March 1996, the percentage of the total square footage of the RCA that was contaminated was 9.4%

Data Source:

Chase /Gundal(Manager / Source)

Accouritability:

Chase /Gebers Trend:

Positive SEP54 1

l 55 2

=- -

IdentiSed PRWPs (Year to Date)

+ Fort Calhoun Goal (<20) 20 -

18 __

16..

3 14 _

1 n.12._

1 10._

8._

a:

g 6..

a.

4..

2 2._

0 0

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

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 March 1996, there were 2 PRWPs identified.

There have been 2 PRWPs in 1996.

The 1996 year-end goal for PRWPs is a maximum of 20.

Data Source:

Chase /Cartwright (Manager / Source)

Accountability:

Chase /Gebers Trend:

None SEP 52 se

g Documents scheduled for Review g Documents Reviewed g Documents Overdue 300.

~

l 250..

200..

150.

~

100.

50.

i 0

Apr May Jun Jul Aug Sep oct Nov Dec Jan Feb Mar 1M j

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

During March 1996, there were 276 document reviews scheduled, while 51 reviews were completed. At the end of the month, there were 11 document reviews more than 6 months overdue. There were 16 new documents initiated during March 1996. Beginning in September 1995, these figures include PED and NOD procedures.

l Data Source:

Chase /Plath Accountability:

Chase /Skiles Trend:

None SEP 46 57

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

I t

i g System Failures G00Dl j

1 a Non-System Failures 30..

y

\\

s..

l l

20..

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

l LOGGABLE/ REPORTABLE INCIDENTS (SECURITY) l This graph shows the Loggable/ Reportable incidents (Security) Indicator and depicts (1) the total number of loggable/ reportable incidents conceming system failures which oc-curred during the reporting month, and (2) the total number of loggable/ reportable inci-l dants non-system failures conceming Security Badges, Access Control and Authoriza-

]

tion, Security Force Error, and Unsecured Doors.

I j

During the month of March 1996, there were 19 loggable/ reportable incidents identified.

j System failures accounted for 93% of the loggable/ reportable incidents. The five (5) microwave system failures were attributed to one zone. The vendor is scheduled to trouble-shoot and repair the problem April 96. The seven (7) environmental failures were due to l

cxtremely inclement weather (snow, wind, ice) during the reporting period.

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

i i

Data Source:

Sefick/Woemer(Manager / Source)

Accountability:

Sefick Trend:

None SEP 58 i

i j

58 l

a

, Temporary Modmcations >1 cycle old (nrv required for removal) i m Temporary Modifications >6 months old (Removable on-line)

- w_. Fort Calhoun Goals for >1-cycle and >6 months old

(

7 Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb Mar 1996 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 greater than six months old. The 1996 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).

Upon further review of RC-3D cover gasket pressure indicator, it was determined that this tempo-rary modification should/could remain installed. Consequently, ECN 96-058 was prepared to allow this installation. Therefore RC-3D gasket pressure indicator has been removed from the overdue list of our first goal and added to the over due list of our second goal.

There are currently no temporary modifications that are greater than one-fuel cycle old requiring a refueling outage to remove. In addition, at the end of March 1996, there were 4 temporary modifications installed that were greater than six months old that can be removed on-line. These were: 1) Local indication for BAST CH-11 A and CH-11B, which is awaiting completion of MWO 930137, scheduled start date of 05/29/96; 2) RC-3D cover gasket pressure indicator which is awaiting installation of ECN 96-058, scheduled for completion 7/96; 3) Low Level Alarm Switch LA-1054, which is awaiting installation of ECN 95-375, scheduled for completion 6/98..

At the end of March 1996, there was a total of 13 TMs installed in the Fort Calhoun Station. 4 of the 13 installed TMs require an outage for removal and 9 are removable on-line. In 1996, a tota:

cf 5 temporary modifications have been installed.

Data Source:

Skiles/ Turner (Manager / Source)

Accountability:

Skiles/Gorence Trend:

Continued Management Attention is Needed SEP 62 & 71 59

4 m Total Modification Packages Open

_e Fori Calhoun Year-End @al(68) 100..

90.

l 80 --

yo n

IO

o 60..

50 40.

30..

20.

10 0

i i

93 94 95 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 96 OUTSTANDING MODIFICATIONS This indicator shows the total number of outstanding modifications (excludina outstandina modifications which are proposed to be cance!!ed).

j Reporting Cateaory

'93

'94

'95

'96

'97

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

0 0

0 1

1 1

Mod. Requests Being Reviewed 0

0 0

2 0

0 3

Design Engr. Backlog /In Progress 0

0 0

14 2

11 33 Construction Backlog /In Progress 4

0 10 17 0

0 26 i

Design Engr. Update Backlog /in Progress 1

3 6

0 0

0 8

Totals 5

3 16 33 3

12 72 (Outage + OnLine)

(3+2)

(0+3) (7+9) (23+10) (0+3) (12+0)

(42+28) i At the end of March 1996,4 modification requests have been issued this year and 1 modification request has been cancelled. The Nuclear Projects Review Committee (NPRC) has conducted 17 backlog modification request reviews this year. The Nuclear Projects Committee (NPC) has completed 6 backlog modification request reviews this year.

The 1996 year-end Fort Calhoun goal for this indicator is a maximum of 68 outstanding 2

modifications.

Data Source:

Jaworski/ Walling (Mansger/ Source) 4 j

Scofield/Lounsberry (Maneger/ Source)

Accountability:

Scofield/Skiles Trend:

None i

60

~.

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

80...

EARS Requiring Engineering Closeout.Not in Closeout 60 --

g sE O DEN 40.

20..

b:

O;O;O-O

n,O ;O,

,E;E E;

Jan Feb Mar Jan Feb Mar Jan Feb Mar Jan Feb Mar 0 3 Months 3 6 Months 612 Months

>12 Months O Engineering Response g Closeout (sE) 30..

20..

10 -_

0 M

Priority 0 Priority 1 Prior:ty2 Priority 3 Priority 4 Priority 5 Priority 6 i

l,

, Priority 1 & 2 Priority 3

...o... Total Open EARS l 200..

$ $g _,

G.......G.

- - - G*

--G.

g...... G...... c...... q...... q ' * * *..G.......s...... O O

Apr May Jun Jul Aug sep oct Nov Dec Jan Feb Mar 1995 1996 78 EARS 37 EARS 57 EARS on Requiring R es olv ed 20 overdue schedule Res se end n R epo nses 62.4 %

10.3 %

s ENGINEERING ASSISTANCE REQUEST BREAKDOWN This indicator shows a breakdown of the number of EARS assigned to Design Engineering and System Engineering. The 1996 year-end goal for this indicator is a maximum of 140 outstanding EARS.

Total EAR breakdown is as follows:

EARS opened during the month 9

EARS closed during the month 16 Total EARS open at the end of the month 113 Data Source:

Jaworski/Livingston (Manager / Source)

Accountability:

Skiles/Jaworski Trend:

None SEP 62 61

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

j j

96 15 7 1

CLO SEOUT S1 DEN 0 3 M onths 3*

7 4

3.s M onths ECN Status -Overall Backlog g Bacidogged O Received g Completed 1

u.4 l

250.

i m

m a

e a

w So.

,_, u,,,3, oct Nov Dec Jan Feb Mar l

Design Engineering T

y 200.

ss o.:

>s Months Months

{

150.

75%

- e.

1 100.

7e 72 7'

3Se i

oct Nov Dec Jan Fe b M ar i

System Engineedng i

j 250.

j 200.

7 78

.us iLLLLLL 12+

ap*

j oct Nov Dec Jan Feb Mar e.s Procurement / Construction 4

m hbrths

[

Oct N>v Dec Jan Feb Feb Drafting / Closeout ENGINEERING CHANGE NOTICE STATUS l

Data Source:

Jaworski/Livingston (Manager / Source)

Accountability:

Jaworski/Skiles Trend:

None SEP 62 1

1 62 u

M d

~

I 1

4 i

)

W3 92 73 l

C E

P Nmy M

OC TYP E Sa8 Pr!ority 1&2 P'

"Y ss j

smiN%P 8 Total Open ECNs = 541 es%

s Total Open ECNs = 541 l

l O DEN. Closeout or Drafting Not Complete 28 26 i

3 Maintenance / Construction /P rocurement. Work Not Complete fy P flofMy

)

E system Engineering. Response, Confirmation Not Conglete 22 y

5 DEN. Engineering Not Complete I

I I

I i

i I

P riomy i

Oct Now og g6 et>9S Mar 96 3a4 l

i 261 288 22 P riority P riority 250.

3 50 7

sas 22 51 12 %

25%

2 3

I i

1 I

i l

l P riority Oct Ncw M

Jaim Few Mer-96 sa4 j

Substitute Replacement item ECNs Open sas 100.

4 Prtorsty 80.

s2 11 se 32 i

i i

Oct Nov De c-95 Jan 96 Fe b-96 Ear 96 P

p Document Change ECNs Open 44g sad 51%

ENGINEERING CHANGE NOTICES OPEN j

Data Source:

Jaworski/Livingston (Manager Source)

Accountability:

Skiles/Jaworski l

Trend:

None j

63

O Administrative Control Problem a LicensedoperatorError g other Personnel Bror g Maintenance Problem O DesignConstructionlinstallation/ Fabrication Problem g EquipmentFailures 2..

1.

O Mar Apr May Jun Jul Aug sep oct Nov Dec Jan Feb l1295l l1996l 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 March 1,1995, through February 29,1996. 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. Fcr de-triled descriptions of these codes, see the " Performance Indicator Definitions" section of this report.

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

Data Source:

Tills /Cavanaugh (Manager / Source)

Accountability:

Chase Trend:

None 64 i

O Total Requalmcation Training Hours a sirnulator Training Hours a Non-Requalification Training Hours g Number of Exam Failures 40..

37 35.5 34.5 35 35.-

32

""1 30..

26 25..

20 _.

97 16 15.

1.5 2

2 10.

.5 8

6 5

.5 5

.5 4

5..

3 2.5 3

2 0

0 0

I 0__

i i

j j

i Cycle Cycle Cycle Cycle Cycle Cycle 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.

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

LICENSED OPERATOR REQUALIFICATION TRAINING This indicator provides information on the total number of hours of training given to each crew during each cycle. The simulator training hours shown on the graph are a subset of the total training hours. Non-Requalification Tra.'ing 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.

Requalification Training Rotation 95-7 wa~ not completed during March. Therefore, s

no new data is available.

Data Source:

Conner /Guliani(Manager / Source)

Accountability:

Conner /Guliani Trend:

None SEP 68 65

g SROExams Administered

{

O SRO Exams Passed O ROExams Administered g ROExams Passed 10 5..

0 Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb Mar LICENSE CANDIDATE EXAMS This indicator shows the number of Senior Reactor Operator (SRO) and Reactor Opera-tor (RO) quizzes and exams taken and passed each month. These internally adminis-t:: red quizzes and exams are used to plot the SRO and RO candidates' monthly progress.

During the month of March 1996, there were O RO and 0 SRO exams given, due to Requalification Training Rotation 95-7 not being completed during the month.

Data Source:

Conner /Guliani(Manager / Source)

Accountability:

Conner /Guliani Trend:

None SEP 68 66

m open irs >6 Months Old

, Open significant irs

+ TotalOpenIRs 600..

500..

400._

aff 304 300__

,y 2s4 249 228 22 0

Ap May Jun Jul Auj sep Oct Nov Dec Jan Feb Mar

(

L 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 March 1996, there were 304 open irs. 304 of these irs were greater than 6 months old. There were 86 Open Significant irs at tne end of the month. These numbers have been restated to reflect the elimination of CARS from the system. As of April 21,1995, CARS ere no longer being issued. As of September 21,1995 incident Reports are no longer issued. All future corrective actions wlIl be documented on Condi-tion Reports.

Data Source:

Conner /Plott (Manager / Source)

Accountability:

Andrews/Gambhir/Patterson Trend :

None 67

I O TotalOutage MWOs a MWOs ReadytoWork 900..

800 gg 700..

System Egerrg 600.

N 200..

NFEh/EW G

100..

0..

-q----

_ m.

g.......

g Dec Jan46 Feb.86 Mar 96 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 Comple's, 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 68

1996 Outage Projects Status Report g Last Month g This Month 100..

O For schedale l

90.

80.

70..

a s

60..

c s

as ss 4

,, s.

55 -

u

a..

.u 40 _.

i i

4 1

j F

l y

2 38 h

1:

5 i

i e

i j

Il 51 lj i

a j

H j

i I

as I

E 6

gj s

g SPECIAL SERVICES ENGINEERING DEPARTMENT OVERALL PROJECT STATUS (Cycle 17 Refueling Outage)

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:

Skiles/Sweamgin (Manager / Source)

Accountability:

Skiles/Boughter Trend:

None SEP 31 69 t

--*-- Baseline Schedule f or P RC Approval

- ProJocted/ActualScheduleforPRC Approval

Fsnal Desgn P kg hsued (2 FD DCP ksued P rcrto 05/0795)

Total M odif cation P acka0es (23)(S Added After 05/0795) 9 w 8-S

! 7-

.i f 8 -

h} 5.

m I"L 1;

I. l-f

/

C... L 7

3 z}

suo!.

Bill!!!!!!ilill!

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.

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. 12 Modifications added after May 1, 1995, not included.

March 1996 Modifications added: 0 Deleted = 0 Graph corrected to represent the baseline schedule.

Data Source:

Jaworski/ Walling (Manager / Source)

Accountability.

Gambhir/Jaworski Trend:

None SEP 31 70 l

l l

a '

/

+ Baseline Schedule for PRC Approval

,_ Projected / Actual Schedule for PRc Approal 10 -.

!69 o

1.I

a i} s i

a-o oE7-

s

$}

=

2 W 6--

O e

g s

_:::3: ;. ;

1555 2/1055 3/1755 4/2155 5/2655 6/3055 8/455 9445 10/1355 PROGRESS OF 1995 ON-LINE MODIFICATION PLANNING (FROZEN SCOPE OF 9 MODIFICATIONS)

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 cunent schedule. This information is taken from the Modification Variation 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.

March 1996 Modifications Added: 0 Deleted = 0 l

l l

Data Source:

Jaworski/ Walling (Manager / Source)

Accountability:

Gambhir/Jaworski Trend:

None SEP 31 71

dl he for RC Approval

+ otal ackages (10)(4 Added After 052145) 6, x x ;;.:,: x j

,x

- - y x

,x x, x x x x x

,x 5__

} 4.

f Js__

i I

2 1__

1--

0 l

E E

l E

E g,

8 9

E E

S e

e e

el E

R j

R e

5 2

e 3

n 4

g 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 25,1996.1 Modification added after May 1, 1995, not included.

March 1996 Modifications Added: 0 Deleted = 0 Graph corrected to represent the baseline schedule.

Data Source:

Jaworski/ Walling (Manager / Source)

Accountability:

Gambhir/Jaworski Trend:

None SEP 31 72

e ACTION PLANS 73

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.

i 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":

. Fuel Reliability index (page 14)

. Thermal Performance (page 33)

. Maintenance Workload Backlogs (page 47)

THERMAL PERFORMANCE IMPROVEMENT ACTION PLAN A.

PROBLEM STATEMENT Plant Heat Rato as measured by the INPO Performance Indicator has shown a i

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 i

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:

1. Improve Plant Heat Rate as measured 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.

74 1

(

s C.

Action (s) Reouired to Accomolish Goals Resp.

Date Comments 1.

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

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

2.

Evaluate the temperature correction factor utilized to correct actual plant heat rate data to design conditions for S.E.

Completed White Paper submitted INPO reporting purposes. This mathematical correlation to Supervisor - System may not accurately reflect the plant derating experienced Engineering on 12/07/95 at elevated river water temperatures 1

3.

Review current operations procedures for condensate cooler operations. Implement changes required to ensure a minimum amount of heat is rejected to the river implement changes to while providing sufficient protection for operating S.E.

Completed OI-ST-1, P.C. No. 44466 equipment.

approved 10/11/95.

4.

Continue to evaluate operating plant systems to determine components operating at less than optimum Currently, S.E.

velues or requiring maintenance to ensure no impact on S.E.

Ongoing reviewing all plant station efficiency.

parameters on a daily basis.

75

i l

Action (s) Recuired to Accomolish Goals Resp Date Due Comments 5.

Continue to develop better tools to monitor plant S.E.

Ongoing Currently, working performance, development of better computer models to toward another program i

predict and quantify equipment performance impacts on that will provide station efficiency.

computer analysis and troubleshooting assistance.

6.

Complete EAR 95-077, Evaluation of Best Method of r

Measuring Circulating Water Flow DEN /SYE Complete EAR response received

[

10/30/95 t

7.

Implement corrective actions as outlined in EAR 95-077 using the ECN process DEN /SYE Later Date to be determined by NPRC i

i i

76 f

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.

EliEl The plan below is compromised of both short term corrective actions to address the Cycle 16 operations goals identified above and long term corrective actions for Cycle 17 and beyond.

SHORT TERM (CYCLE 16 OPERATIONS)

JIEM ACTION BES.P_.

DATE DUE STATUS 1.

Evaluate replacement of two-micron firer in CVCS with one-Hothaus Completed Complete.1/#96. Firer replacement will micron firer.

resuR in improved particulate removal 01mm and consequently lower dose rates.

1 a.

Install one-micron Sters in CVCS 01/31/96 Csi.4:;;;d 03/13/96 2.

Evaluate benetts ofincreasing letdown flow.

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

I 3.

Evaluate need for and effectveness of more frequent of Holthaus Completed Complete. 01/04/96. Resin bed effechve puri5 cation and cationion beds.

01/04/96 in minimizing RCS activity. Resin beds replaced in November 1995.

77

-__.a.___.m.-

ITEM ACTION RESP.

Date Due STATUS 3a.

Replace resin beds during Spring 1996 outage.

Spires 03/22/96 Canceled 4.

Prepare and issue Nuclear Network request for industry Completed Complete. 01/12/96. Transmitted experiencein reducing FRI.

01/12/96 proposed inquiry to Licensing for Nuclear Network entry.

5.

Evaluate installation of silver mordenite titration system Holthaus/ Spires Completed Received general (unclassited) forincreased iodine removal.

01/26/96 information on system used at Savannah River Project.

6.

Identify number of old design assemblies to be placed Completed Previously identi8ed eight asse.ablies to in peripherallocations for second cycle and consider Holthaus/Guinn 01/12/96 be placed on core periphery for second replacement with new design assembly.

cycle.

7.

Evaluate whether these assembhes could be used for Holthaus/Guinn Completed more than one cycle to reduce cost.

01/19/96 8.

Determine if Westinghouse can supply the above fuel Completed Complete. 01/12/96. Westinghouse has assembles for Cycle 17. Also, can Fuels Division Holthaus/ Hanger 01/12/96 indicated that they can fabricate the provide necessary uranium.

assemblies. Cost estimates by Fuels Division is approx.12M. Discount from Westinghouse also requested.

9.

Evaluate Cycle 18 preNminary pattem same as 5 & 6 Holthaus/Guinn Completed Cycle 18 prelminary pattem indicates 01/17/96 four additionalassembEes would be required. Cost $1.0M 10.

Evaluate Cycle 19 prelminary pattem same as S& 6 Holthaus/Guinn Completed Cycle 19 prelminary pattem indicates 01/17/96 eight additional assemblies would be required. Cost $2.0M 11.

Analyze additional assembhes to be procured Holthaus/ Hanger Completed Total costis $5.0M for 20 additional 01/17/96 assemblies.

12.

Evaluated cost /bsnett with assumption of Holthaus/ Hanger Completed

$10,000/ person exposure.

01/25/96 78

The action plan for Maintenance Workload Backlog (page 47) 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 79

PERFORMANCE INDICATOR DEFINITIONS AUXILIARY FEEDWATER SYSTEM SAFETY SYSTEM CLEAN CONTROLLED AREA CONTARENATIONS ?,.1,000 PERFORMANCE DISMTEGRATIONS/RANUTE PER PROBE AREA The sum of the known (pionned and unplanned) unevadshie The personnel cordammelon events in the clean controsed area.

hours and the eshmeted unavadable hours for the auxNiery This indicator tracks personnel performance for SEP #15 & 54.

h.waar system for the reporting period divided by the critical hows for the reporting period muniplied by the number of trains CONTARENATED RADIATION CONTROLLED AREA in the auxHiery feedwater system.

The percentage of tie Radlebon ControHed Area, which includes COLLECTIVE RADIATION EXPOSURE the auxHiery buHding, the redweste buildmg, and areas of the C/RP buBding, that is contammated based on the total square Conective redinhon exposure is the total extemal whole-body footage This indcator tracks performance for SEP #54.

does recahed by as ordene personnel (includmg contractors and visitors) during a time period, as measured by the DAILY THERMAL OUTPUT thermoluminescent dosimeter (TLD). Conective redebon exposure is reported in units of persorwom. This indicator This hicator shows the daily core thermat output as measured tracks radiological work performance for SEP #54.

tom computer point XC105 (in thermal megawatts). The 1500 MW Tech Spec limit, and the unmet porton of the 1495 MW COMPONENT FALURE ANALYSIS REPORT (CFAR)

FCS doNy goal for the repotting month are sieo shown.

SUMMARY

DIESEL GENERATOR REUABluTY (25 Demands)

The summary of INPO categones for Fort Calhoun Station witn sqpniecenty higher (1.645 standard deviations) fagure rates then This indestor shows the number of fouures occumng for each the rest of the industry for en eighteerHnonth time period.

emergency diesel generator during the last 25 start demands Fagures are reported as component (i.e., pumps, motors, main and the lost 25 lood-run demands.

steam stop valves, control element rnotors, etc.) categories DISABUNG INJURYALLNESS FREQUENCY RATE Failure Cause Categones are:

(LOSS Tite ACCSENTRATE)

AgelNormal Use -thought to tu the consequence of This hecator is desned as the number of accidents for al utiNty expected weer, aging, end-of-life, or normel use.

personnel permanently assegned to the station, involving days away from work per 200,000 manhours worked (100 man-Manufacturing Defect a failure attributable to inadequate years). This does not include contractor personnel This assembly or initial quauty of the responsible component or indmetor tracks personnel performance for SEP #25,26 & 27.

system.

DOCUSENT REVEW(BENNIAL)

Engineeringcesign - a iniure attributable to the inadequate design of the responsible component or system.

The Document Review indcator shows the number of documents reviewed, the number of documents scheduled for Other Devices - a failure attributable to a faGure or revow, and the number of document reviews that are overdue miooperation of another component or system, includmg for the reporting month. A document review is considered a==-8ad devices.

overdue if the review is not complete within six months of the assigned due date. This indcator tracks performance for SEP MaintenanceIAction - resummg from improper maintenance,

46.

Back of maintenance, or personnel errors that occur dunng maintenance sctivitieson the component..

EtERGENCY AC POWER SYSTEM SAFETY SYSTEM PERFORMANCE TeeNng Acdon. reeueng from improper toebng or personnel errors that occur during testing activities.

The sum of sie known (pienned and unplanned) unavanable and the eshmeted unevalimbe hours for the emergency AC power initial Instagation Error caused by improper initial system for the reportmg period divided by the number of hours instamation of equipment in the reporbng period muniplied by the number of trains in the emergency AC power system CENTS PER KE.OWATT HOUR EhERGENCY DESEL GENERATOR UNIT RELIAB1U1Y The purpose of this indestor is to quantify the econommel operation of Fort Calhoun Stabon. The cents per kilowett This hdiossar shous sw number of secures that note reported during the hour indmetor represents the budget and actual cents per last 20,50, and 100 emergency diesel gerwrator demands at #w Fort knowes hour on a twelve-month everage ker the current year.

C88""" 8"'"" "'""* ** Ingen veenhich con *w k a high The beeis for tw budget curve is the approved yearly budget.

The been for the actual curve is the Financial and Operatng i,,, y,,n y, gri,,, %

Report.

80

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

l PERFORMANCE INDICATOR DEFINITIONS i

i and the successful test that fotows repair to verify operabelty

1) Number of Start Domends: AE valid and inadvertent start should not be counted as demands or faRures when the EDG

{

demands, k ciudmg nu start-only demands and al start has not been declared operable again.

demands that are fogowed by lood run demands, whether

- by automebe or manuel inlhetion. A ste t-only demand is EhERGENCY DIESEL GENERATOR UNRELIABILITY j

a demandin which he emergency generator is started, but no allempt is made to load the generator This indmotor measures the total unreeabisty of emergency diesel generators in general, unrollabNity is the ratio of I

2) Number of Start Failures: Any faRure within the ur====H operabons (starts or load-runs) to the number of emergency generator system that prevents the generator valio demands. Total unrobabulty is a combinsbon of start tom adusvmg et-end toquency and votage is classited unreliability and lood run unreliebHity as a valid start fagure. This includes any conddion identleed in the course of maintenance inspections (with ENGINEERING ASSISTANCE REQUEST (EAR) the emergency generator in standby mode) that deGnitely BREAKDOWN would have resulted in a start feaure N a demand had occuned.

This indmetor shows a breakdown, by age and priority of the EAR, of the number of EARS assigned to Design Engineering

3) Number of LeedJtun Demands: For a valid lood-run Nuclear and System Engmoenng This indcator tracks demand to be counted, the lood run attempt must meet performance for SEP 862.

one or more of the fobowing critetta:

ENGINEERBIG CHANGE NDTICE (ECN) STATUS l

A) A load-run of any duration that results from a real automatic or manueliniteten The number of ECNs that were opened. ECNs that were completed, and open bacidag ECNs awaiting completion by

(

B) A lood rm test to satisfy the plant's load and duration DEN br the reporting month. This indicator tracks performance as stated in each test's speciscations, for SEP #62.

C) Olhor spedal tests in which the emergency generator ENGEIEERSIG CHANGE NOTICES OPEN is expected to be operated for at least one hour while loaded with at loest 50% of Rs design loed.

This incBeetor breaks down the number of Engmeeting Change l

Nobces (ECNs) that are assigned to Design Engineenng

4) Numberof LoadJtun Failures: A load-run failure should Nuclear (DEN), System Engmeenng, and Maintenance The be counted for any reason in which the emergency graphs provide data on ECN Facitly Changes open, ECN j

generator does not pick up load and run as predicted.

S*=NH= R 7-d llems open, and ECN Document i

Failures are counted during any valid load.run demands.

Changes open. This indicator tracks performance for SEP #62.

5) Exceptions: Unsuccessful attempts to start or lood-run EQUrhENT FORCED OUTAGES PER 1,000 CRITICAL should not be counted as valid demands or failures when HOURS i

they con be attributed to any of the following:

Equpment breed outages per 1,000 crtical hours is the inverse l

A). Spmous trips that would be bypassed in the event of of the mean tme between forced outages caused by equipment an emergency, failures. The mean time is equal to the number of hours the roedor is crtlcalin a period (1,000 hours0 days 0 hours 0 weeks 0 months ) divided by the numtwr B) Malfuncbon of equipment that is not required during of forced outages caused by equipment feMuros in that period.

an emergency.

EQUNALENT Avan ans :TY FACTOR I

C) Intenllonaltermmation of a test because of abnormal I

condibons that would not have resulted in major This indcator is defined as the ratio of gross avaasbie dieselgenerator demoge or repair.

generation to groes maximum generation, expressed as a percentage Avausbie generation 4 the energy that can be j

D) Malfunctions or operating errors which would not produced K the unit is operated at the maximum power level have prevented the emergency generator from being permitted by equipment and regulatory limitations Maximum restarted and brought to load within a few minutes generation is the energy that can be produced by a unit in a i

given period r operated conhnuously at maximum capocay.

E) A fagure to stort because a portion of the startng system was disabled for test purpose, if fogowed by FORCED OUTAGE RATE a successful start with the startmg system in Rs normal alignmort This indestor is deflned as the percentage of time that the unit was unevalable due to forced events compared to the time Each emergency generator failure that results in the generator planned for electrical generation. Forced events are failures or being declared inoperable should be counted as one demand other unplanned conditens that require removing the unit from and one feture. Exploratory toets during corrective maintenance service t:afore the end of the next weekend. Forced events 81

_ - ~

PERFORMANCE INDICATOR DEFINITIONS include start-up failures and events irubeled while the unit is in Contractor personnel are not included for this indmetor reserve shutdown (Le., the unit is available but not in service).

W LWE CHERESTRY WSTRURENTS OUT OF SERVICE FUEL REUABlWTYINDICATOR Total number of inline chemistry instruments that are out-of-This 5dmetor is defined as the steady-state primary cooient l-service in the Secondary System and the Post Accident 131 activity, corrected for the tramp uranium contribubon and Sampling System (PASS).

normatted to a common purleestion rate. Tramp uranium is fuel which has been deposited on reactor core intomais from UCENSE CANDIDATE EXAMS t

previous defective fuel or is present on the surface of fuel elements from the manufacturing process Steady state is Thisindcolor shows the rusnber of SRO and/or RO quttzes and defined as conbnuous operation for at least three days at a exams that are administered and poseed each month. This power level that does not very more than + or -5%. Plants indcator tracks training performance for SEP #68.

should colect dels for hs indmator at a power level above 85%,

when poseblo. Plants that dd not operate at steady-etate power UCENSED OPERATOR REQUAUFICATION TRAWING above 85% should collect data for this indmetor at the hsghest steady-state power level attained during the month.

Thetotal number of hours of training given to each crew during each cycle. Also provided are the simulator training hours The density correction factor is the ratio of the specific volume (which are a subset of the total training hours), the number of of cociert at the RCS operating temperature (540 degrees F., Vf non REQUAUFICATION training hours and the number of exam

= 0.02146) divided by the specinc volume of coolant at normal failures. This indmetor tracks training performance for letdown temperature (120' F at oubet of the letdown cooling heat SEP #68.

exchanger, Vf = 0.016204), which results in a density correction factor for FCS squelto 1.32.

UCENSEE EVENT REPORT (LER) ROOT CAUSE BREAKDOWN GROSS HEAT RATE This indmetor shows the number and root cause code for Gross heat rate is deilned as the ratio of total thermal energy in Licensee Event Reports. The root cause codes are as fotows:

Brtish Thermal Units (BTU) produced by the reactor to the total groes electrical energy produced by the generator in kilowatt-

1) Administrative Control Problem - Management and hours (KWH).

supervisory denciencies that affect plant programs or activities (i.e., poor planning, breakdown or lack of I

HAZARDOUS WASTE PRODUCED adequate management or supervisory control, incorrect procedures, etc).

The total amount (in Kilograms) of non-halogensted hazardous waste, halogensted hazardous waste, and other hazardous

2) Licensed Operator Error - This cause cede captures waste produced by FCS each month.

errors of ommeenA.m...

, by iconeed reactor operators during plant activities.

HIGH PRESSURE SAFETY WJECTION SYSTEM SAFETY SYSTEM PERFORMANCE

3) Other Personnel Error - Errors of orrussen/commesion committed by norWicensed personnel involved in plant The sum of the known (planned and unplanned) unavailable actmbes hours and tie echmeted unavailable hours for the high pressure safety injection system for the reporting period divided by the

4) Maintenance Problem. The hient of this cause code is to craical hours for the reporting period mulupiiod by the number of capture the fuH range of problems which can be attributed trains in the high pressure safety injection system.

In any way to programmatic detciencies in the rnertsnance functional organization. Activities included in INDUSTRIAL SAFETY ACCIDENT RATE INPO this category are maintenance, testing, survemance, cabbration and redeten protection.

This indicator is delnad as the number of accidents per 200,000 rnen hours worked for an utsty personnel permanentty assigned 5) abrication Problem-to the staten that result in any of the following:

This cause code covers a fun range of pingrammate deficiencies in the areas of design, construchon,

1) One or more days of restncted work (excludeng the day of hetallation, and fabrication (i.e., loss of control power due the accident);

to underrated fuse, equipment not qualiRed for the environment, etc.).

2) One or more days away from work (excluding the day of the accident); and

6) Equipment Failures (Electronic Piece # arts or Environmental Related Failures) This code is used for

3) Fatauties.

spurious failures of electronic piece-parts and failures due to meteorological condibons such as lightning, ice, high 82

i PERFORMANCE INDICATOR DEFINITIONS winds, etc. Generally, it includes spurious or one-tune MAXIMUM INDIVDUAL RADIATION EXPOSURE leiures. Eiednc components included in this category are circut cards, recuers, bietables, fuses, capacitors, diod==.

The total maximum amotst of radiation received by an individual resistors, etc.

person working at FCS on a monthly, quartetty, and annual basis.

LOGGABLE/ REPORTABLE INCIDENTS (SECURITY)

MWO PLANNING STATUS (CYCLE 17 REFUELING The total number of security incidents for the reporting month OUTAGE) depicted in two graphs. This indicator tracks security performance for SEP #58.

The total number of Maintenance Work Orders that have been approved for heiunion in the Cycle 17 Refueling Outage and the MAINTENANCE OVERTilWE runnberthat are ready to work (ports staged, planning complete, and al other paperwork ready for fleid use). Also included is the The percent of overtime hours compared to normal hours for number of MWOs that have been engineenng holds (ECNs, maintenance. This includes OPPD personnel as wel as procedures and other miscopeneous engineering holds), parts contract personnel.

hold,(parts staged, not yet inspected, parts not yet arrived) and planning hold Gob scope not yet completed). Maintenance Work MAINTENANCE WORKLOAD BACKLOGS Requeels (MWRs) are also shown that have been idenkfled for the Cycle 17 Refusing Ondage and have not yet been converted This indicator shows the becedog of non-outage Maintenance to MWOs Work Orders remaining open at the end of the reportmg month.

Maintenance clase6Heations are defined as folows:

NUtBER OF CONTROL RDOM EQUPAENT DEFICIENCIES Corrective - Repair and restoration of equipment or A control room equipment donesency (CRD) is deAned as any components hat have Isiled or are malfuncboning and are not component which is operated or controlled from the Control performing their intended funchon.

Room, provides indicehon or alarm to the Control Room, provides tooting capabilities from the Control Room, provides Preventive Actions taken to meintain a piece of equipment automatic actions from or to the Control Room, or provides a within design operstmg condibons, prevent equipment failure, pesolve funceon forhe Control Room and has been identined as and extend its Nie and are performed prior to equipment deGcierd,i.e., does not perform under al condibons as designed failure.

This doention also applies to the Altemete Shutdown Panels Al-179, Al-185, and Al-212.

Non Corrective &lant knprovements Maintenance adMbes performed to implement station improvements or to A pierd component which is deflosent or inoperable is coneadored repair non-plant equipment.

an" Operator Work Around (OWA) 16em* If some other action is required by an operator to compensate for the condibon of the Maintenance Work Priorities are defined as:

component. Some examples of OWAs are:

~~

, 7 Condibons which signancantly degrade station

1) The control room level indicator does not work but a loca:

safety or availability, sight glass can be read by an Operator out in the plant; immediate Action Equipment deficiencies which

2) A detcient pump cannot be repaired because replacement significantly degrade station reliability. Potential W unit parts require a long lead time for purchase /deEvery, thus shutdown or power reduchon requring the redundant pump to be operated continuously; Operations Concern - Equipment donciencies which hinder

3) Special actions are required by an Operator because of station operation.

equipment design problems. These actions may be described in Operations Memorandums, Operator Notes, Essential - Rouhne cocective maintenance on essential or may require changes to Operating Procedures; station systems and equiprr=rt

4) Detesert piera equipmert that is required to be used during Non Essential - Routine corrective maintenance on non-Tw, g Operstmg Procedures or Abnormal Operstmg essential station systems and equipmert Procedures, Plant ;,,,,.- _ Z - Nort,orrective maintenance and plant

5) System indication that provides critical information during improvernents.

normal or abnormal operations.

This indicator tracks maintenance performance for SEP #36.

83

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PERFORMANCE lNDICATOR DEFINITIONS NUBSER OF ISSSED SURVEILLANCE TESTS RESULTING TNs indcator shows the status of the projects which are in the IN LICENSEE EVENT REPORTS scope of the Refueling Outage.

The number of Survenance Tests (STs) that resun in Licensee PERCENTAGE OF TOTAL MWOs COWLETED PER Event Reports (LERs) dureig the reporting month. This indcator MONTH IDENTIFIED AS REWORK trads missed STs for SEP #60 & 61 The percentage of total MWOs completed per month identmed OPEN INCIDENT REPORTS as rework. Rework activities are identmed by maintenance planrung and croll Rework is: Any addihonal work required to This indcolor deploys the total number of open incident Reports conect detosordes discovered during a failed Post Maintenance (irs), the number of irs that are greater than six months old and Test to ensure the component / system passes subsequent Post the number of open signmcent irs.

Maintenance Test.

OUTSTANDING MOO 1FICATIONS PERCENT OF COWLETED SCHEDULED MAINTENANCE ACTIVITIES The number of Modecahon Requests (MRs) in any state between the leeuence of a Modecation Number and the The percent of the number of W.i-A1 maintenance schvities complebon of the drawing update.

as comprred to the number of scheduled maintenance schvities each month. This percentage is shown for au maiMenance

1) Form FC.1133 Backlogan Progress. This number crafts. Also shown are the number of emergent MWOs represents modlAcetion requests that have not been plant Maintenance activities include MWRs, MWOs, STs, PMos, approved during the reporting month.

calibrations, and other miscegeneous actmbos This indicator tracks Maintenance performance for SEP #33.

2) na wana*==i Requests Being Reviewed. This category includes PERFORMANCE NDICATORINDEX A) Modecation Requests that are not yet reviewed.

This indicator index is calculated from a weighted comtunebon of ten overperformance indcolor values, which include Unit B) Modtcetnn Requests being reviewed by the Nuclear CapabiNty Factor, Unit Capability Loos Factor, HPSI, AFW, Projects Review Committee (NPRC).

Emergency AC Power System, Unplanned Automate Scrams, CoNective Radiation Exposure, Fuel Reliaihtly, Thermal C) Modiceten Requests being reviewed by the Nexlear Performance, Secondary System Chemistry, Radiation Weste, Projects Committee (NPC).

and Induetnal Safety Accident Rate.

These ModiGcation Requests may be reviewed several times PREVENTABLFJPERSONNEL ERROR LERs before they are approved for accomphehment or canceled.

Some of these ModtAcahon Requests are retumed to This indicator is a breakdown of LERs. For purposes of LER q

Engineenng for more informehon, some approved for evaluation, event classacehon, a Preventable LER" is detned as:

some approved for study, and some approved for planning.

Once planning is completed and the scope of the work is clearty An event for which the root cause is personnel error (i.e.,

deRned, these Modecation Requests mey be approved for inappropriate action by one or more individuals), inadequate accomplishment with a year assigned for construction of they adninistrative controls, a design construchon, instaNetion, may be conceled. AN of these dflerent phases require review.

inelatebon, fabrication problem (irwolving work completed by or supervised by OPPD personnel) or a maintenance problem

3) Design Engineering Bacidogan Progress Nuclear (attributed to inadequate or improper upkeep / repair of plant Planning has assigned a year in which construction wiR be equpment). Also, tie cause of the event must have occurred

w.,--O ;j and design work may be in progress, wRhin approximately two years of the Event Date" specited in the LER (e.g., an event for which the cause is attributed to i

4) Construction BacklogAn Progress. The Construction a problem with the original design of the plant would not be Package has been issued or construction has begun but coneadored preventable).

i the modmcahon has not been accepted by tie System Acceptance Committee (SAC).

For purposes of LER event classmcahon, a " Personnel Error" LERis deflned as follows:

5) Design Enginsonng Update Backlogan Progress PED has received the Modificaten Completion Report but the M event for which the root cause is inappropnote action on drawinge have not been updated.

the Frt of one or more individuals (as opposed to being attritWed to a department or a general g oup). Also, the The above menboned outstanding modecabons do not include inapptcpiele acton rnuet have occurred within approximately modscotens whch are proposed for canceHaten.

two years of the " Event De'.# specelled in the LER.

OVERALL PROJECT STATUS (REFUELNG OUTAGE) 84

PERFORMANCE INDICATOR DEFINITIONS Addlbonapy, each event classified as a Personnel Error" should SAFETY SYSTEM FAILURES also be classi6ed as " Preventable." This indicator trends personnel performance for SEP ltem #15.

Safety system failures are any events or condnions that could prevent the fulfillment of the safety functions of structures or PRIMARY SYSTEM LITHlUM % OF HOURS OUT OF LihET systems, if a system consuds of multiple redundant subsystems or trains failure of all trains constRutes a safety system failure.

The percent of hours out of limit are for lithium divided by the Failure of one of two or more trains is not counted as a safety total number of hours possible for the month.

system failure. The dennition for the indicator paranels NRC reporing requremerts in 10 CFR 50.72 and 10 CFR 50.73. The PROCEDURAL NONCOWLIANCE INCIDENTS fotowing is a ist of the major safety systems, sub-systems, and (MAINTENANCE) components monitored for this indicator:

The number of identrfied incidents concoming maintenance Accident Monitoring instrumentation, Auxiliary (and procedural problems, the number of closed irs related to the Emergency) Feedwater System, Combustible Gas Control, use of procedures (includes the number of closed irs caused by Component Cooling Water System, Containment and procedural noncompliance), and the number of closed Contanmort isolaton, Cortainmort Coolant Systeme, contnM proceduralnoncompliance irs. This indicator trends personnel Room Emergency Ventilation Systern, Emergency Core performance for SEP #15,41 and 44.

Cooling Systems, Engmeered Safety Features Instrumentation, Essential Compressed Air Systems, PROGRESS OF CYCLE 17 OUTAGE MODIFICATION Essenhal or Ernergency Service Water, Fire Detechon or i

PLANNING Suppression Systems, isolation Condenser, Low Temperature Overpressure Protection, Main Steam Line This indicator shows the status of modi 6 cations approved for Isolation Valves, Onsite Emergency AC & DC Power completion during the Refueling Outage.

w/Distnbubon, Radiation Montoring Instrumentation, Reactor Coolant System, Reactor Core isolation Coohng System, i

PROGRESS OF 1996 ON-LINE MODIFICATION PLANNING Reactor Trip System and instrumentation, Recirculation Pump Trip Actuabon instrumentation, Residual Heat Removal This indicator shows the status of modi # cations approved for Systems, Safety Valves, Spent Fuel Systems, Standby Lkluid completion dunng 1995.

Control System and Ultimate Heat Sink.

RADIOLOGICAL WORK PRACTICES PROGRAM SECONDARY SYSTEM CHEMISTRY PERFORMANCE INDEX The number of identined poor radiological work practices (PRWPs) for the reportog month. This indicator tracks lhe Chemistry Per ormance Index (CPI) is a calculation based r

radiological work performance for SEP #52.

on the concentrabon of key impuribes in the secondary side of the plant. These key impurities are the most likely cause of RADIO OF PREVENTIVE TO TOTAL MAINTENANCE &

determrabon of thc oteam generators. Criteria for calculating the PREVENTIVE MAINTENANCE ITEMS OVERDUE CPI are:

The ratio of prevertive maintenance (including surveinance

1) The plant is at greater than 30 percent power; and testing and calibration procedures) to the sum of non-outage corre@ve mairtenance and preventive maintenance completed

2) the power is changing less than 5% per day.

1 over the reporting penod. The rabo, expressed as a percentage, 1

is calculated based on man-hours. Also displayed are the The CPI is calculated using the foHowing equation:

percert of preventrve maintenance tems in the rnonth that were not completed or administratrvety closed by the scheduled date CPI = ((sodiurrJ0.79) + (Chloride /1.52) + (Sulfate /1.44) +

plus a grace period equal to 25% of the scheduled interval. This (Iron /3.30) + (Copper /0.30)+(Condensate 02/2.90))/6 indicator tracks preventive maintenance activihes for SEP #41.

Where: Sodium, sulfate, chloride and condensate dissolved RECORDABLE INJURY /lLUMSS CASES FREQUENCY oxygen are the monthly average blowdown concentrations in RATE ppb, iron and copper are r9onthly time weighted average feedwater concentrations in ppb. The denominator for each of The number ofinjuries requinng more than normal Arst aid per the hve factorp is the INPO median value. If the monthly 200,000 man-hours worked. This indicator trends personnel average for a specific parameter is less than the INPO median performance for SEP #15,25 and 26.

value, the rnedian value is used in the calculation.

REPEAT FAILURES SIGNIFICANT EVENTS 1he number of Nuclear Plant Reliability Data System (NPRDS) components with more than one failure and the number of Sagndicant events are the events identrlied by NRC staff through NPRDS components with more than two failures for the detailed screening and ovaluation of operating experience. Tht-eighteerwnonth CFAR penod.

screening process includes the daily review and discussion of 85

PERFORMANCE INDICATOR DEFINITIONS au reported operating reactor events, as well as other hatruments are not considered as temporary modrAcations, opershonal data such as special tests or construchon activities.

An event identined from the screening process as a signincent

3) Scaffold is not considered a temporary modrficabon.

event canddels is further evaluated to determine if any actual or Jumpers and blocks which are lnstalled and for which MRs potential threat to the health and safety of the put'ic was have been sutrnitted wiu be considered as temporary invoNed. Specific examples of the type of criteria are modincetions untR final resolution of the MR and the jumper summartzed as follows:

or block is removed or is permanently recorded on the drawmgs. This indicator tracks temporary modrncations for

1) Degradaten ofimportant safety equipment; SEP #62 and 71.

2) Unexpected plant response to a transient; THERMAL PERFORMANCE

3) Degradation of fuel integrity, primary coolant pressure The ratio of the design gross heat rate (corrected) to the boundary, important associated features; adjusted actual gross heat rate, expressed as a percentage.

4) Scram with compbcabon, UNIT CAPABILITY FACTOR

5) Unplanned release of radioactrvity; The ratio of the available energy generation over a gNen tirne period to the reference energy generation (the energy that could

6) Operabon outside the lirnits of the Technical SpecrAcabons; be produced f the unit were operated continuouQ at fug ower p

under reference ambient conditions) over the samt time penod,

7) Other, expressed as a percentage.

INPO sagruncant events reported in this indicator are SERs UNIT CAPACITY FACTOR (Signi6 cant Event Reports) which inform uhilbes of significant events and lessons leamed identi6ed through the SEE-IN The not electrical energy generated (MWH) divided by the screening process product of maximum dependable capacity (not MWe) times the groes hours h the repotbng period expressed as a percent. Net SPARE PARTS NdVENTORYVALUE electncal energy generated is the gross electrical output of the unit measured at the output terminals of the turbine generator The dotarvalue of the spare parts inventory for FCS dunng the minus the normal staban service loads during the gross hours of reporting period, the reporting period, expressed in megawatt hours.

STAFFING LEVEL UNPLANNED AUTOMATIC REACTOR SCRAMS PER 7,000 CRITICAL HOURS The adual stafEng level and the authortred stafRng level for the Nuclear Operatens DNision The Producten Engineering This indicator is deAned as the number of unplanned automatic Dkision, and the Nuclear Services DNision. This indicator scrams (reactor protechon system logic actuations) that occur tracks performance for SEP #24.

per 7,000 hours0 days 0 hours 0 weeks 0 months of critical operation.

STATION NET GENERATION The value for this indicator is calculated by mulbplying the total number of unplanned automate reactor scrams in a specine time The net generation (sum) produced by the FCS dunng the period by 7,000 hours0 days 0 hours 0 weeks 0 months , then dividing that number by the total reportog month, number of hours cribcalin the same time period. The indicator is further (eAned as follows:

TEWORARY MODIFICATIONS t) Unplanned means that the scram was not an anticipated The number of 'emporary mechanical and electrical part of a planned test.

configurations to the plant's systems.

2) Scram rneens the automatic shutdown of the reactor by a

1) Termorary conAgurations are defined as electncaljumpers, rapid insertion of negatNe reactivity (e.g., by control rods, elodrtcal blocks, mechanical jumpers, or mechanical blocks liquid injechon system, etc.) that is caused by actuation of which are instaNed in the plant operating systems and are the reactor protecbon system. The scram signal may have not shown on the latest revision of the P&lD, schematic, resulted from exceeding a set point or may have been connecten, wiring, or flow diagrams, spurious.

2) Jumpers and blocks which are installed for Surveillance Tests, Maintenance Procedures, Calibration Procedures,

3) Automebo means that the initial signal that caused actuabon Special Procedures or Operating Procedures are not of the reador protechon system logic was provided from c,,1e consadored as temporary modr6 cations unless the jumper or of the sermor's monitoring plant parameters and conditions, block remains in place after the test or procedure is rather than t;e manual scram switches or, manual turbine complete. Jumpers and blocks installed in test or lab inp switches (or push-buttons) provided in the main control 86

~

1 PERFORMANCE lNDICATOR DEFINITIONS room.

shipped off-site for processing, and the volume of solid dry radioactrve weste which has been shipped off-sRe for

4) Critical means that dunng the steady-state condihon of the processang Low-level solid radioactive waste consists of dry reactor prior to the scram, the effective muRiplication (k,)

adwe weste, sludges, tooins, and evaporator bottoms generated was essentiag equal to one.

as a result of nuclear power plant operatson and rnaintenance.

y Dry radeoactive waste includes contaminated rags, cleaning UNPLANNED CAPABILffY LOSS FACTOR motonals,rE=pa=aNa protective clothing, plastic containers, and any other material to be disposed of at a low-level radioactwe The rate of the unplanned energy losses during a given period weste disposal see, except resin, sludge, or evaporetor bottoms.

of time, to th6 reference energy gereration (the energy that Low 4evel refers to a8 radioactrve waste that is not spent fuel or could be produced if the unit were operated continuously at fun a by-product of spent fuel processing. This indicator tracks power under reference ambient conditens) over the same time radiological work performance for SEP #54.

period, expressed as a percentage.

UNPLANNED SAFETY SYSTEM ACTUATIONS - (INPO

+ DEFINITION)

This indicator is defined as the sum of the following safety system actuations:

1) The number of unplanned Emergency Core Ccoling System (ECCS) actuations that resun from reaching an ECCS actuaten set point or from a spurious / inadvertent ECCS signal.

2) The number of unplanned emergency AC power system actuations that resuR from a loss of power to a safeguards bus. An Leipienned safety system actuation occurs when an actuabon set point for a safety system is reached or when a spurious or inadvertent signal is generated (ECCS only),

and major eqtapment in the system is actuated. Unplanned means that the system actuation was not part of a planned test or evolubon. The ECCS actuations to be counted are actuations of the high pressure injection system, the low pressure infection system, of the safety injection tanks.

UNPLANNED SAFETY SYSTEM ACTIONS -(NRC DEFINITION)

The number of safety system aduations which include (2Dk) the High Pressure Safety Ingeden System, the Low Pressure Safety injecten System,the Safety inieden Tanks, and the Emergency Diesel Generators. The NRC classincation of safety system actuations includes actuations when major equipment is operated gag when the logic systems for the above safety systems are chaBenged.

VIOLATION TREND This hicator is deflnad as Fort Calhoun Station Cited Volations

)

and Nor4ted Violations trended over 12 rnonths. AdditionaBy, CRed Velations for the top quartile Region IV plant is trended over 12 months (lagging the Fort Calhoun Station trend by 2-3 months). R is the Fort Cahoun Staten goal to be at or below the cRed violation trend for the top c;uartNe Region IV plant.

VOLUE OF LOW-LEVEL SOLID RADIOACTNE WASTE This indicator is defined as the volume of low-level solid rarnaareve waste aduaBy shipped for burial. This indicator also shows the volume of low-level radioactive waste which is in temporary storage, the amount of radcactive oB that has been 87

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

EEP Reference Number 15 he

. Increase HPES and IR Acr ountability through use of Performance Indicators Procedural Noncomplirace incidents (Maintenance)...............

51 Recordable injury /Ilir oss Cases Frequency Rate....................................... 4 Clean Controlled A ea Contaminations 3.1,000 DisintegrationsMinute Per Probe Area

..... 5 Preventable /Perr annel Error LERs..........

.6 SEP Referero Number 24

. Complete Staff Studies Staffir; Level

............................................................. 44 EEP deference Numbers 25. 26. & 27

. ; raining Program for Managers and Supervisors Implemented

Evaluate and implement Station Standards for Safe Work Practice Requirements

. Implement Supervisory Enforcement of Industrial Safety Standards Disabling injuryMilness Frequency Rate

.......... 3 Recordable injuryAllness 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)

.............68 Overall Project Status (Cycle 17 Refueling outage)...................

69 Progress of Cycle 17 0utage Modification Planning...............

70 SEP Reference Number 33

. Develop On-Line Maintenance and Modification Schedule Percer.t of Completed Scheduled Maintenance Activities (All Maintenance Crafts)

....... 52 EEP Reference Number 36

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

. 47 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

. 48 Procadural Noncompliance incidents (Maintenance)..............

......... 51 88

1 M

SAFETY ENHANCEMENT PROGRAM INDEX i

SEP Reference Number 46

Design a Procedures Control and Administrative Program l

Document Review.................................................................. 57 SEP Reference Number 52 P,ggg

. Establish Supervisory Accountability for Workers Radiological Practices Radiological Work Practices Program................................................ 56 SEP Reference Number 54

. Complete implementation of Radiological Enhancement Program i

Clean Controlled Area Disintegrations >1,000 Counts / Minute Per Probe Area.................. 5 Collective Radiation Ex posure....................................................... 17 Volume of Low-Level Solid Radioactive Waste.......................................... 38 Contaminated Radiation Controlled Area............................................... 55 SEP Reference Number 58 i

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

58 1

SEP Reference Numbers 60 & 61

. Improve Controls Over Surveillance Test Program

. Modify Computer Program to Correctly Schedule Surveillance Tests i

]

Number of Missed Surveillance Tests resulting in Ucensee Event Reports..................... 21 SEP Reference Number 62

. Establish Interim System Engineers i

Temporary Modifications........................................................... 59 l

Engineering Assistance Request (EAR) Breakdown.................................... 61 i

Engineering Change Notice Status.................................................... 62 Engineering Change Notices Open.................................................. 63 1

SEP Reference Number 68

. Assess Root Cause of Poor Operator Training and establish means to monitor Operator Training License Operator Requalification Training 65 Ucense Candidate Ex ams........................................................ 66 ff.P Refan.ess.Minnhat.Z1

. Improve Controls over Temporary Modifications Temporary Modifications

................................................... 59 89

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L.T.Kusek M. P. Lazar B. R. Livingston N. L. Mar 1 ice T. J. Mcivor K. G. Meistad K. A. Miller P. A. Mruz R. J. Mueller Nuclear Licensing

& Industry Affairs (8)

T. L Patterson 90

j FORT CALHOUN STATION OPERATING CYCLES AND REFUELING OUTAGE DATES i

EVENT DATE RANGE PRODUCTION (MWH)

CUMULATIVE (MWH) i Cycle 1 09/26/73 - 02/08R5 3,299,639 3,299,639 l

1st Refueling 02/08/75 - 05/11/75 Cycle 2 05/11/75 - 10/01/76 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

)

l 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 4

1 Cycle 5 12/24/78 - 01/18/80 3,882,734 16,868,454 5th Refueling 01/18/80 - 06/11/80 Cycle 6 06/11/80 - 09/18/81 3,899,714 20,768,168 8th Refueling 09/18/81 - 12/21/81 Cycle 7 12/21/81 - 12/03/82 3,561,866 24,330,034 j

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 07/12/64 - 09/28/85 4,741,488 32,477,893 i

j 9th Refueling 09/28/85 - 01/16/86 Cycle 10 01/16/86 - 03/07/87 4,356,753 36,834,646 10th Refueling 03/07/87 - 06/08/87 Cycle 11 06/08/87 - 09/27/88 4,936,859 41,771,505 11th Refueling 09/27/88 - 01/31/89 Cycle 12 01/31/89 - 02/17/90 3,817,954 45,589,459 j

12th Refueling 02/17/90 - 05/29/90 Cycle 13 05/29/90 - 02/01/92 5,451,069 51,040,528 j

13th Refueling 02/01/92 - 05/03/92 Cycle 14 05/03/92 - 09/25/93 4,981,485 56,022,013 14th Refueling 09/25/93 - 11/26/93 4

Cycle 15 11/26/93 - 02/20/95 5,043,887 61,065,900 15th Refueling 02/20/95 - 04/14/95 Cycle 16 04/14/95 - 09/21/96 18th Refueling 09/21/96 - 11/02/96 (Planned Dates)

FORT CALHOUN STATION 4

CURRENT PRODUCTION AND OPERATIONS " RECORDS" First Sustained Reaction August 5,1973 (5:47 p.m.)

First Electric Supplied to the System August 25,1973 Commercial ion (180,000 KWH)

September 26,1973 Achieved Full (100%)

May 4,1974 Longest Run (477 Days)

June 8,1987-Sept. 27,1988 Highest Monthly Not Generation (364,468,800 KWH)

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

May 29,1990-Feb.1,1992 j

Shortest Refueling Outage (52 days)

Feb. 20,1995-April 14,1995 I

...

ML20108D079

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