Text

Performance Indicators Rept, for Feb 1997
	ML20137F946
Person / Time
Site:	Fort Calhoun
Issue date:	02/28/1997
From:	; OMAHA PUBLIC POWER DISTRICT
To:	;
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ML20137F932	List: LIC-97-0047, Forwards Fort Calhoun Station Performance Indicators Rept, for Feb 1997; ML20137F946;
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FORT CALHOUN STATION PERFORMANCE INDICATORS FEBRUARY 1997 SAFE OPERATIONS PERFORMANCE EXCELLENCE COST EFFECTIVENESS E0"AO$c!oEOS$$ss R

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OMAHA PUBLIC POWER DISTRICT FORT CALHOUN STATION l

l PERFORMANCE INDICATORS REPORT i

i i

i FEBRUARY l

1997 Production Engineering Division System Engineering

FORT CALHOUN STATION February 1997

[

Monthly Operating Report OPERATIONS

SUMMARY

During the month of February 1997, the Fort Calhoun Station (FCS) operated at a nominal 100% power level. Normal plant maintenance, surveillance, equipment rotation activities and scheduled on-line modification were performed and there were no major equipment failures, plant transients or reportable events during the month.

On Wednesday February 26,1997, Component Cooling Water Heater Exchanger AC-1D, was taken out of service for scheduled cleaning and coating. This placed Fort Calhoun in a 14 day Limiting Condition for Operation (LCO). Heat Exchanger i

AC-1D was returned to service on March 7,1997.

l 1

1 e

+ Fort Calhoun Indox Value

+ Industry Afedien index Value 100..

Industry tiedian 90 -

Projected 85 85 M

83 83 83 80 79 70.

i 60.

Value for February 1997 82.44 50.

40 95/1 95/2 95/3 95/4 96/1 96/2 96/3 96/4 Jan Feb 97/1 PERFORMANCE INDEX TREND The performance index trend calculation is made up of eleven variables each weighted to arrive at an overall index value. The thermal performance, secondary system chemistry, and industrial safety accident rate values are calculated for a one-year period. Fuel reliability is calculated on a quarterly basis. The remaining values (unit capability factor, unplanned (unit) capability loss factor, unplanned automatic scrams per 7000 hours0.081 days 1.944 hours 0.0116 weeks 0.00266 months critical, safety system performance, and collective radiation exposure) are calculated for a two-year period. This method allows the index trend to be more responsive to changes in plant performance.

INPO no longer uses the volume of low-level radioactive waste as a plant indicator. The value will still be tracked, but the value will no longer be used in calculating the Stations Performance Index.

ii

g nMXMJMVALUE gJanuary 17 O ebruary17 F

6 16.00 -

14.00.

k 8

U a

im-888 888 888 NNN NNN NNN 10.

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8 888 8

8.00 8

0.00

+

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i w

UCF UCLF HPSI AFW EACP CRE uAS7 FR CF1 TF1 ISAR This graph shows the difference between the Maximum No. of points for each WANO indicator and the actual value achieved by Fort Calhoun for the fourth quarter of 1996.

UCF Unit Capability Factor TPI Thermal Performance Indicator UCLF Unplanned Capability Loss Factor CPI Secondary Chemistry Indicator HPSI High Pressure Safety injection ISAR Industrial Safety Accident Rate AFW Auxiliary Feedwater EACP Emergency AC Power UAS7 Unplanned Auto Scrams / 7000 Hours CRE Collective Radiation Exposure FRI Fuel Reliability Indicator Per INPO, the Performance Indicator for the Volume of Low Level Radioactive Waste buried, will no longer be used in calculating the Stations Performance Index. All other parameters have been adjusted to reflect this change.

iii

FORT CALHOUN STATION PERFORMANCE INDICATORS REPORT February 1997-

SUMMARY

POSITIVE TREND REPORT ADVERSE TREND REPORT A performance indicator with data representing three A performance indicator with data representing three consecubve rmnths of improving performance or three consecutive months of declining performance or three consecutive months of performance that is superior 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 following 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 ig)

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

Hioh Pressure Safety iniection System Safety System Eerformance Maintenance workload Backtoos (Page 5)

(Page 39)

Auxiilarv Feedwater System End of Adverse Trend Report.

(Page 6)

Emeroency A.C. Power System (Page 7)

INDICATORS NEEDING INCREASED MANAGEMENT ATTENTION REPORT Secondary Chemistry (Page 10)

A performance indicator with data for the reporting h4isted Surveillance Tests Results in Licensee Event period that 4 inadequate when compared to the OPPD Reports goal is defined as *Needing increased Management (Page 23)

Attention" per Nuclear Operations Division Quality Procedure 37 (NOD-QP-37).

Unolanned Safety System Actuations UNPO)

Fuel Reliabilitv Index (Page 29)

(Page 9)

Hazardous Waste Produced Ecuirwant Forced Outeae Rate (Page 45)

(Page 33)

Contaminated Radiation Controlled Area Cents ner Kilowatt Hour (Page 46)

(page 37)

Temocrary Modifications (Page 50)

End of Positive Trend Report.

iv

WANO INDICATORS (As compared to previous month)

Unit Capability Factor Incrasing Unplanned Capability Loss Factor Incresing High Pressure Safety Injection No (hirge Aux, Feedwater System No Oarge Emergency AC Power Pb Charge Collective Radiation Exposure No Charge Unplanned Reactor Scrams No Charge Fuel Reliability Decreasirg Chemistry Indicator Decreasirg Thennal Performance Incrasirg Industrial Safety Accident Rate No Charge v

l

Table of Contents / Summary Paoe GOALS...................

.. xii WANO PERFORMANCE lNDICATORS..............

.1 Unit Capability Factor.................................

.2 Unplanned Capability loss Factor...

......... 3 Unplanned Automatic Reactor SCRAMS per 7000 Hours..............

.4 High Pressure Safety injection System 5

Auxiliary Feedwater System...

..................................6 Emergency AC Power System........

..... 7 Thermal Performance.

......... 8 Fuel Reliability indicator..........

9 Secondary System Chemistry....

10 Collective Radiation Exposure...............

11 Volume of Low Level Radioactive Waste...........

...... 12 Industrial Safety Accident Rate...........

13 SAFE OPERATIONS Disabling injury / Illness Cases Frequency Rate 15 Recordable injury / Illness Cases Frequency Rate 16 Clean Controlled Area Contaminations

>1,000 Disintegrations / Minute per Probe Area 17 Preventable / Personnel Error LERs 18 Safety System Failures 19 Maximum Individual Radiation Exposure

. 20 Violation Trend.

21 Significant Events

. 22 Missed Surveillance Tests Resulting in LERs 23 vi

Table of Contents / Summary PERFORMANCE Station Net Generation

........ 25 Forced Outage Rate.............

. 26 Unit Capacity Factor 27 Equivalent Availability Factor..

. 2f; Unplanned Safety System Actuations INPO Definition.........................

29 NRC Definition...

......... 30 Gross Heat Rate 31 Daily Thermal Output 32 Equipment Forced Outages per 1,000 Critical Hours 33 Chemistry Action Levels Exceeded - Event Days

.................... 34 Primary System Lithium % Hours Out of Limit 35 COST Cents Per Kilowatt Hour.

..... 37 DMSION AND DEPARTMENT PERFORMANCE INDICATORS Maintenance Workload Backlogs (Corrective Non-Outage) 39 Ratio of Preventive to Total Maintenance

. 40 Percentage of Total MWOs Completed per month identified as Rework...

41 Overtime 42 Procedural Noncompliance incidents.

43 In-Line Chemistry instruments Out-of-Service 44 Hazardous Waste Produced 45 Contaminated Radiation Contrclied Area 46 Radiological Work Practices Program 47 Document Review.

. 48 vii i

I l

4 Table of Contents / Summary Loggable/ Reportable incidents (Security).........

................................ 49 Temporary Modifications.

50 Outstanding Modifications................

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

... 52 Engineering Change Notices S ta tu s.........................................

............ 53 O pe n........................

......... 54 Licensee Event Report (LED) Root Cause Breakdown

......... 55 Licensed Operator Requalification Training

...... 56 License Candidate Exams....................

... 57 Condition Reports......................

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

59 Overall Project Status...........................

......... 60 Outage Modification Planning...................

. 61 On-Line Modification Planning.

. 62 Progress of i996 On-Line Modification Planning

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

. 64 Performance Indicator Definitions.............

. 66 Safety Enhancement Program Index 74 Report Distribution List 76 viii

NUCLEAR PROGRAM 1997 GOALS AND OBJECTIVES FUTURE FOCUS and RELATIONSHIP to CHANGE The nation's electric utility industry is passing through a period of significant organizational, financial and cultural changes.

In this new era, change is inevitable, progress and success are not.

Fort Calhoun must react to these changes while improving capacity, SALP ratings and INP0 ratings.

We must KNOW OUR COSTS to CONTROL COSTS.

Understanding cost is essential to controlling it, and controlling cost is essential to competing in today's market.

We are a learning organization. We must BUILD ON OUR HIGH PERFORMANCE CULTURE.

Individuals at all levels must take responsibility for their actions and must be committed to improve their own performance.

OUR CULTURE MUST SUPPORT THE NEW STRATEGIES. We must continue to develop and implement strategies that will allow us to effectively compete in the evolving market while still maintaining the highest levels of safety and reliability.

Communicating is our key to improving. Follow up and feedback must be candid, forthright and timely.

We recognize that change causes disruption of work and work flow. That change requires increased management direction. We need IN DEPTH, RELENTLESS ATTENTION to our NEW FOCUS / STRATEGIES.

VISION To be recognized as the best nuclear organization in the world and to preserve nuclear energy as a viable future energy source.

HISSION The safe, reliable and cost effective generation of electricity for GPPD customers through conservative decision making and the professional use of nuclear technology.

We will conduct these operations to assure the health, safety;, and protection of our personnel, the general public, and the environment.

ix

GOALS Goal 1:

SAFE OPEF.ATIONS Supports: April 1996 Corpcrate Strategic Plan Goal 3, Objective: 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.

1997 Priorities:

Achieve an overall SALP Rating of"1"in 1997 Focus on Achieving an INPO Rating of"1"in 1998 Reduce 1997 NRC violations with no violations more severe than level 4.

No unplanned automatic reactor scrams or safety system actuations.

Objectives to support SAFE OPERATIONS.

OBJECTIVE 1-1:

No challenges to a nuclear safety system.

l l

OBJECTIVE 1-2:

Comply with applicable policies, technical specs, procedures, standing orders and work instructions.

OBJECTIVE 1-3:

Identify conditions BEFORE they affect plant safety and reliability. Address every safety concem.

OBJECTIVE 1-4:

Achieve all safety-related 1997 performance indicator goals in the Performance Indicator Report.

OBJECTIVE 1-5:

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

X

OPPD NUCLEAR ORGANIZATION GOALE 1997 Priorities Goal 2:

PERFORMANCE Supports:

April 1996 Corporate Strategic Plan Goal 3, Objective: 2; G-4, Objective: 1, 2, & 3; G-5, Objective: 2 Nuclear teamwork achieves high performance at Fort Calhoun Station as exhibited by safe, reliable and cost effective power production.

1997 PRIORITIES:

Improve Quality, Professionalism and Teamwork.

Maintain High Plant Reliability.

Pursue efficient, cost-effective work processes.

Meet or exceed INPO key parameters Reduce the number of Human Performance errors.

Identify Programmatic performance problems through effective self assessment.

Maintain a high level of readiness in the ERO.

Objectives to support PERFORMANCE:

OBJECTIVE 2-1:

Achieve an annual plant capacity factor of 92.7% and a unit capability factor of 96.0%.

OBJECTIVE 2-2:

Training meets the needs of the plant and the National Academy accreditation objectives.

Line managers use training to present, discuss & reinforce performance standards.

Line managers monitor and assess personnel performance to determine how well standards are met.

Line managers through personal involvement in training emphasize the importance of conducting activities within approved procedures / practices.

Executive Training Committee:

invites line supervisors to discuss the direction tuining is going for their specific area.

invites the line and training supervisors responsible for each accredited program to provide a status of intemal accreditation assessments.

ensures items such as training attendance, attentiveness, punctuality, etc.

are uniformly emphasized.

Xi

OPPD NUCLEAR ORGANIZATION GOALS 1997 Priorities Goal 2:

PERFORMANCE (Continued)

OBJECTIVE 2-3:

Achieve all performance-related 1997 performance indicator goals in the Performance Indicator Report. Focus on performing basic skills well while pursuing efficient, cost-effective work processes. Identify the barriers to excellence and resolve them.

OBJECTIVE 2 4:

Plan for the completion of the 1998 refueling outage in 42 days of less.

OBJECTIVE 2-5:

Teamwork is evident by improved plant reliability, an effective emergency response organization, reduced number of human performance errors and effective self assessment..

Goal 3:

COSTS Supports:

April 1995 Corporate Strategic Plan Goal 2, Objective: 1, 2 and 3, and Goal 6, Objective: 1 Operate Fort Calhoun cost effectively to contribute to OPPD's " bottom line". Cost consciousness is exhibited at all levels of the organization.

1997 Priorities:

Maintain total O&M and Capital Expenditures within budget.

Streamline work process to improve cost effectiveness.

Implement Opportunity Review recommendations.

Objectives to support COSTS:

OBJECTIVE 3-1:

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

OBJECTIVE 3-2:

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

Goals Source:

Lounsberry (Manager)

Xii s

O WANO PERFORMANCE INDICATORS 1

, Monthly unit Capability Factor

...x..

12 Month unit Capability Factor 1997 Fort Calhoun Goal (96%)

Year 2000 WANo industry Goal (87%)

100%.-

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80%.

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X-X 60%__

40%__

20%._

0%

II Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb UNIT CAPABILITY FACTOR This indicator shows the plant monthly Unit Capability Factor (UCF) value, a rolling 12-month average, the OPPD goal, and the WANO 2000 goal. UCF is defined as the ratio of the available energy g::neration over a given period of time to the reference energy generation over the same time period, cxpressed as a percentage.

The UCF for February 1997 was reported as 100.0%. The year-to-date UCF was also reported as 100%, the UCF for the last 12 months (Mar.1996 through Feb.1997) was 72.3%, and the UCF for the last 36-months (Mar.1994 through Feb.1997) was reported as 83.9%.

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

Energy losses for May 1996 are due to a reduction in power to 95% for Moderator Coefficient Testing.

Energy losses for June 1996 are due to a forced outage when the Anti-Rotation Device on Reactor Coolant Pump RC-38-M failed.

Energy losses for Sept., Oct., & Nov.,1996 due to the scheduled Refueling Outage.

Energy losses for Dec.1996 are due to MOV-CV leakage.

The Year 2000 WANO industry goal is 87% and the industry current best quartile value is approximately 85%. The 1997 Fort Calhoun annual goal for this indicator is a minimum of 96.0%.

The maximum index point value for this indicator is 16. At the end of the February 1997, the FCS Value was 12.44. This compares to the previous month's value of 12.00.

D:ta Source:

Generation Totals Report & Monthly Operating Report Accountability:

Chase Trend:

None 2

, Monthly Unplanned Capability Loss Factor

+ 12 Month Rolling Average

_.e _ Fort Calhoun Goal (1.58%)

+ Yeat 2000 WANo industry Goal (4.5%)

60%

53 %

40 %

30%..

20%__

5 5

6 6

6 5

,i 5

0

._i,7 Mar Apr May Jun Jul Aug sep Oct Nov Dec Jan Feb UNPLANNED CAPABILITY LOSS FACTOR This indicator shows the plant monthly Unplanned Capability Loss Factor (UCLF), a rolling 12-month average, the OPPD goal, and the Year 2000 WANO goal. UCLF is defined as the ratio of the unplanned energy losses during a given period of time, to the reference energy generation expressed as a percentage. Unplanned energy loss is defined as energy not produced as a result of unscheduled shutdowns, outage extensions, or load reductions due to causes under plant management control. Energy losses are considered to be unplanned if they are not scheduled at least four weeks in advance.

The UCLF forthe month of February 1997 was reported as 0.00%. The year-to-date UCLF was 0.00%, the UCLF for the last 12 months (Mar.1996 through Feb.1997) was 8.41%, and the 36-month average UCLF (Mar.1994 through Feb.1997) was reported as 6.0% at the end of the month.

The Year 2000 WANO industry goal is 3.0% and the industry current best quartile value is approximately 3.2%. The 1997 Fort Calhoun Station year-end goal for this indicator is a maximum value of 1.58%

The maximum index point value for this indicator is 12. At the end of the February 1997 the FCS Value was 5.9. This compares to the previous month's value of 4.77.

Data Source:

Generation Totals Report & Monthly Operating Report Accountability:

Chase Trend:

Needs increased Management Attention.

3

e

12. Month Rolling Average FCS Reactor Scrams Per 7,000 Hours Critical for last 36 months Fort Calhoun Goal (0.0)

_ Year 2000 WANO industry Goal (1) 3..

2..

1 i

i~ _.

0; Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb FCS Reactor Scrams -1997 4..

3..

2..

1 1..

0 0

1 95 96 Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb UNPLANNED AUTOMATIC REACTOR SCRAMS PER 7000 HOURS CRITICAL The upper graph shows the 12-month rolling average, the 36-mnnth average, the OPPD goal for 1997 end the Year 2000 WANO goal. The lower graph shows the number of unplanned automatic reactor scrarns that occurred during the last 12 months. This indicator is defined as the number of unplanned tutomatic scrams that occur per 7,000 hours0 days 0 hours 0 weeks 0 months of critical operation.

There were no unplanned automatic reactor scrams during the month of February 1997. The 12-month rolling average (Mar.1996 through Feb.1997) was 0. The 36-month value (Mar.1994 through Fcb.1997) was 0.304.

l The 1997 Fort Calhoun Station goal for this indicator is 0. The Year 2000 WANO industry goal is a maximum of one unplanned automatic reactor scram per 7,000 hours0 days 0 hours 0 weeks 0 months critical.

I The maximum index point value for this indicator is 8. At the end of the February 1997, the FCS Value wIs 8.0. This compares to the previous month's value of 8.0.

I Dita Source:

Monthly Operating Report & Plant Licensee Event Reports (LERs) l Accountability:

Chase Tr:nd:

Positive l

m Monthly HPslsystem UnavailabilityValue

. 12 Month Rolling Average

,__ Fort Calhoun Goal (0.003)

Year 2000 WANO Industry Goal (0.02) 0.02,

a 0.015..

0.01._

~

0 r

r y

1996 Mar Apr May Jun Jul Aug sep Oct Nov Dec Jan Feb HIGH PRESSURE SAFETY INJECTION SYSTEM SAFETY SYSTEM PERFORMANCE This indicator shows the High Pressure Safety injection (HPSI) System unavailability value, as defined by INPO in the Safety System Performance Indicator Definitions, for February 1997.

The HPSI System unavailability value for the month of February 1997 was 0.00. There was 0.0 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 12 month rolling average was (Mar.1996 through Feb.1997) was 5.7E-5, and the year-to-date HPSI unavailability value was 0.000 at the end of the month.

For the previous year there was a total of 1.2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months of planned unavailability and 0.0 hours0 days 0 hours 0 weeks 0 months of unplanned unavailability for the HPSI system.

The 1997 Fort Calhoun year-end goal for this indicator is a maximum value of 0.003. The Year 2000 WANO industry goal is 0.02.

The maximum index point value for this indicator is 10. At the end of February 1997 the FCS Value was 10. This compares to the previous month's value of 10.

Data Source:

Phelps/Schaffer(Manager / Source)

Accountability:

Phelps/Schaffer Trend:

Positive 5

l

m Monthly Auxiliary Feedwater System unavailability x_12 Month AFW unavailability Fort Calhoun Goal (0.01)

Year 2000 WANO Industry Goal (0.025) 0.02

o a

o a

0.018.-

0.016 -

0.01399 0.014.

0.012.

0.01 -

0.008 --

4 0.006..

0.00493 0.00504 l

0.004 "0.00166 0.0019

" ':_ sty, a u; L E.

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

i AUXILIARY FEEDWATER SYSTEM SAFETY SYSTEM PERFORMANCE This indicator shows the Auxiliary Feedwater (AFW) System Unavailability value, as defined by INPO in the Safety System Performance Indicator Definitions, for the month of February 1997.

The AFW System Unavailability Value for February 1997 was 0.0139. There were 0.0 hours0 days 0 hours 0 weeks 0 months of planned and 18.8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months of unplanned unavailability during the month. The 12 month rolling cverage (Mar.1996 through Feb.1997) was 0.00292, and the year-to-date unavailability vnlue was 0.0066 at the end of February 1997.

1 At the end of February 1997, there has been a of 0.00 hours0 days 0 hours 0 weeks 0 months of planned unavailability and j

18.8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months of unplanned unavailability for the AFW system.

j The 1997 Fort Calhoun Station year-end goal for this indicator is a maximum value of 0.01.

l The Year 2000 WANO industry goal is 0.025.

1 The maximum index point value for this indicator is 10. At the end of February 1997, the I

FCS Value was 10. This compares to the previous month's value of 10.

Data Source:

Phelps/Fritts (Manager / Source)

Accountability:

Phelps/Fritts Trend:

Positive 6

1 1

m m Monthly Ernergency AC Power unavailability value

-x Year-to-Date Ernergency AC Power unavailability value

+ Fort Calhoun Goal (0.024) 0.06 _

ear 000WMMusWM(0.025) 0.05 __

i 0.04..

0.03.-

0.02.

~

x 0.01.-

x x

- -x x

N E

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mum j

Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb EMERGENCY AC POWER SYSTEM SAFETY SYSTEM PERFORMANCE This indicator shows the Emergency AC Power System unavailability value, as defined by WANO in the Safety System Performance Indicator Definitions, for the rnonth of February 1997.

The Emergency AC Power System unavailability value for February 1997 was 0.005. During the month, there was 6.7 hours8.101852e-5 days 0.00194 hours 1.157407e-5 weeks 2.6635e-6 months of planned unavailability, and 0.0 hours0 days 0 hours 0 weeks 0 months of unplanned un-availability for testing and repairs. The Emergency AC Power System unavailability value year-to-date was 0.007 and the value for the last 12 months (Mar.1996 through Feb.1997) was 0.010.

There has been 20.9 hours1.041667e-4 days 0.0025 hours 1.488095e-5 weeks 3.4245e-6 months (14.2 for DG-1 and 6.7 for DG-2) of planned unavailability and 0.0 hours0 days 0 hours 0 weeks 0 months of unplanned unavailability for the emergency AC power system in 1997.

There were a total of 1167.5 hours5.787037e-5 days 0.00139 hours 8.267196e-6 weeks 1.9025e-6 months of planned unavailability and 3.7 hours8.101852e-5 days 0.00194 hours 1.157407e-5 weeks 2.6635e-6 months of unplanned unavailability for the emergency AC power system in 1996.

The 1997 Fort Calhoun year-e'nd goal for this indicator is a maximum value of 0.024.

The Year 2000 WANO industry goal is 0.025.

The maximum index point value for this indicator is 10. At the end of February 1997, the FCS Value was 10.00. This compares to the previous month's value of 10.00.

Data Source:

Phelps/Ronning (Manager / Source)

Accountability:

Phelps/Ronning Trend:

Positive 7

m MonthlyThermalPerformance

,12-Month Rolling Average

+ Fort Calhoun Goal (99.6%)

+ Year 2000 WANoindustry Goal (99.5%)

100%._

99%__

1996 RFO 98 %

Mar Apr May Jun Jul Aug sep Oct Nov Dec Jan Feb THERMAL PERFORMANCE This indicator shows the monthly Thermal Performance Value, the rolling 12-month average, the OPPD goal, and the Year 2000 WANO goal.

The thermal performance value for the month of February 1997 was 99.86%.

The year to date value was reported as 99.9%.

The 12 month rolling average (Mar.1996 through Feb.1997) was reported as 99.74%.

The 1997 Fort Calhoun year-end goal for this indicator is an index value which is > 99.7%.

The Year 2000 WANO industry goal is 99.5%.

The maximum index point value forthis indicatoris 6. At the end of February 1997, the FCS Value was 5.22 This compares to the end of the year value of 5.13.

Data Source:

Phelps/Naser(Manager / Source)

Accountability:

Phelps/Gorence Trend:

None 8

l l

m FuelReliability(E.4) f.,

Year 2000 WANO Goal (5 x 10-4 MicrocuriesKiram) 1997 Goal 147E-4 320..

299.16 E 280._

257.07 240_

217.6 E 200 -

169 y

159.9 160 --

121.9 1996 120 "

.e 78.42 RFO 2

80 -

h 40 -

16.1 18.6 A

75.

Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb FUEL RELIABILITY INDICATOR The FUEL RELIABILITY INDICATOR (FRI) for February 1997 was 18.6E-4 microcuries/ gram. While this value is similar to the January 1996 FRI of 16.1E-4 microcuries/ gram, the increase in Xe-133 during February indicates that more rods are leaking in the core. Westinghouse predicts the presence of 2 to 3 leaking rods at core average power or 6 to 9 leaking rods at lower core power levels. Cesium data indicated that one leaking fuel rod present at BOC has a bumup of approximately 24,600 MWD /

MTU which corresponds to several Batch S or T fuel assemblies. No bumup is available for the December 1996 and February 1997 leaking fuel events. The Cycle 17 FRI in the first three months of operation is trending similar to the Cycle 16 Fri FRI values. The February 1997 FRI value is based on data from the entire month at 100% steady-state power and an average letdown flow of 33.50 gpm.

The purpose of the FRI is to monitor industry progress in achieving and maintaining a high level of fuel integrity. An effective fuelintegrity and performance monitoring program provides a means to detect fuel failures and assess the fuel failure number, physical condition, exposure, mechanism, and loca-tion.

A meeting between Westinghouse representatives and FCS Management was held on February 20 1997 to discuss fuel design issues and a "zero fuel defect" action plan. Westinghouse presented an updated on the root cause for past fuel failures. Westinghouse's updated root cause is that the formation of rod - grid gaps allow large amplitude rod vibrations. The rod - grid gaps are due to a combination of irradiation relaxation, flow and base motion induced vibration of rod and fuel assembly.

Design features in the 'new' grid design (batch U, etc.) were made to climate these conditions and to provide the same dampening properties as an ABB fuel assembly.

The "WANO Performance indicator Program utility Data Coordinator Reference Notebook" (INPO No.94-009, Rev.1) states that the industry Goal for fuel reliability is as follows: " units should strive to operate with zero fuel defects". The 1997 Fort Calhoun Station FRI Performance indicator goal is to maintain a monthly FRI below 147.0 x 10d microcuries/ gram. This value was calculated based on the previous Cycles fuel performance, the results of the past fuel inspection and reconstitution campaigns, and the installation of the improved fuel failure resistant grid design in one third of the assemblies in the Cycle 17 core.

The maximum index point value for this indicatoris S. At the end of the February 1997, the FCS Value was 5.4. This compares to the previous month's value of 8.0.

Data Source:

Guinn/Guliani Accountability:

Chase /Stafford Trend:

Needs Management Attention 9

{

e MonthlyChemistryindicctor

+ 12-Month Rolling Average

+ Fort Calhoun Goal (1.4) 2.6..

2.5..

2.4..

2.3..

2.2..

2.1..

2--

1.9..

1.8..

1.7..

1.6..

1.5..

1.4 -

1.3..

1.2.. :

1996 RFO 1

- i i

i i

t i

i 1

Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb SECONDARY SYSTEM CHEMISTRY Criteria for calculating the Secondary System Chemistry Performance Index (CPI) are as follows:

1) the plant is at greater than 30% power;

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

The CPI for February 1997 was 1.27. The CPI value for the past 12 months (Mar.1996 through Feb.1997) was 1.32. The OPPD goal for 1997 is a CPI value < 1.4.

Of the six parameters used in the CPI calculation three are below the WANO mean value.

These include the steam generator chloride, sulfate, and feedwater iron. The other three, steam generator sodium, condensate pump dissolved oxygen and feedwater copper are above the mean value. However, these three values have improved significantly form the Decem-b:r 1996 values. Sodium and copper are still high based on historical data, the dissolved oxygen is considered normal. There is currently an Action Plan in place for dissolved oxygen cnd copper reduction.

The maximum index point value for this indicator is 7. At the end of February 1997, the FCS Value was 5.15. This compares to the previous month's value of 5.37 Data Source:

Spires /Reneaud (Manager / Source)

Accountability:

Spires Trend :

None r

10 l

m Monthly Personnel Radiation Exposure Cumulative Personnel Radiation Exposure

_e FCS Goal 38 person-REM 40 c

=

a 35 30 25._

E 20 --

2 15 -_

10.-

5.-

0 Jan Feb Mar Apr May Jun Jul Aug Sep oct Nov Dec COLLECTIVE RADIATION EXPOSURE The 1997 Fort Calhoun goal for collective radiation exposure is set at 138.0 person-REM.

The exposure for February 1997 was 3.0844 Person-Rem (ALNOR).

The year-to-date exposure through the end of February 1997 was 4.818 Person-Rem (AL-NOR).

This indicator is a " COLLECTIVE" indicator. WANO does not differentiate between on-line and outage exposure.

The Year 2000 WANO industry goal for collective radiation exposure is 120 person-rem per year. For the three year period (Mar.1994 through Feb.1997), the collective radiation exposure was 394.139 person-rem. This gives a Fort Calhoun Station a three year average of 131.379 person-rem per year.

The maximum index point value for this indicator is 8. At the end of February 1997 the FCS Value was 5.73. This compares to the previous month's value of 5.73.

Data Source:

Chase /Cartwright (Manager / Source)

Accountability:

Chase /Gebers Trend:

None SEP 54 11

e Monthly Volume of LLRW (cu.ft.)

x Year-to-Date cumulative Radioactive Waste Buried

_ Fort Calhoun Goal (1200 cu.ft.)

1200 --

1100__

1000-900..

800.

j 700..

600.

S 500..

400..

300..

200

_g 100_

0 xea r

Jan Feb Mar Apr May Jun Jul Aug Sep oct Nov Dec VOLUME OF LOW-LEVEL RADIOACTIVE WASTE This indicator shows the volume of the monthly radioactive waste buried, the cumulative y:ar-to-date radioactive waste buried, and the Fort Calhoun goal.

Cu Ft.

Amount of solid radwaste shipped off-site for processing during current month 1040.0 Volume of solid radwaste buried during January 1997 16.0 Cumulative volume of solid radioactive waste buried in 1997 16.0 Amount of solid radwaste in temporary storage 136.3 The 1997 Fort Calhoun Station goal for the volume of solid radioactive waste (buried) is 1200 cubic feet. The Year 2000 WANO industry goal is 45 cubic meters (1,589 cubic feet) per yrar. The industry upper ten percentile value is approximately 27.33 cubic meters (965.3 cubic feet) per year.

This indicator is no longer used by INPO. The indicator will still be tracked, but will no longer be used in computing the Stations Index Number.

D;ta Source:

Chase /Breuer(Manager / Source)

Accountability:

Chase /Gebers Trend:

None SEP 54 12

_, MonthlyIndustrial Accident Rate

_e 12 Month Rolling Average

_e_

FCs Year-End Goal (<0.50)

+ Year 2000 wANoindustry Goal (<0AO) 1.2,.

1..

0.8

'_\\

h i

D A 'T W

5

~

I T'E 5

L T

I f

-e N

0 1

Mar Apr May June July Aug sep Oct Nov Dec Jan Feb INDUSTRIAL SAFETY ACCIDENT RATE This indicator is defined as the number of accidents per 20,000 man-hours worked for all utility personnel permanently assigned to the station that result in any of the following:

One or more days of restricted work (excluding the day of the accident)

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

Fatalities 1

The purpose of this indicator is to monitor progress in improving industrial safety pe.formance for utility personnel permanently assigned to the station. Contractor man-hours are not included in the indicator.

The values for this indicator are determined as follows:

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

The Fort Calhoun Station industrial safety accident rate for the month of February 1997 was 0.00.

The 12 month rolling average (Mar.1996 through Feb.1997) was 0.29. The year to date value was 0.00 at the end of February 1997.

There were no restricted-time and no lost-time accidents in February 1997.

The 1997 Fort Calhoun year-end goal is 50.50. The Year 2000 WANO industry goal is 50.40.

The maximum index point value for this indicator is 5. At the end of February 1997, the FCS Value was 4.6 This compares to the previous month's value of 4.6.

Data Source:

Sorensen/Skaggs (Manager / Source) i Chase / Booth (Manager / Source)

Accountability:

Chase / Bishop 13

.i i

i t

i 4

I 1

l l

I l

l SAFE OPERATIONS t

l 1

i l

Goal: A proactive, self-critical and safety conscious culture is l

exhibited throughout the nuclear organization. Individuals j

demonstrate professionalism through self-ownership and l

personalinitiative and open communication.

i i

l l

14

I i

__,_ Monthly Disabling injuryAliness frequency

+ 12 Month Rolling Awrage

+ 1997 OPPD Goal 2..

1.8..

1.6 __

1.4..

1.2..

1.-

0.8 l

0.6 A-0.4.'

~' M I

~5 2

I I

0.2.

0 Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb DISABLING INJURY /lLLMESS FREQUENCY RATE (LOST-TIME ACCIDENT RATE)

This indicator shows the February 1997 disabling injury / illness frequency rate and the disabling injury / illness rate for the past 12 months (rolling average).

For the month of February 1997 the disabling injury / illness frequency rate was 0.00. For the 12 month period (tsar.1996 through Feb.1997) the disabling injury / illness rate was 0.44. There j

were no disabling injury / illness cases reported for February 1997.

The 1997 Fort Calhoun Station year-end goal for this indicator is a maximum value of 0.5.

l Data Source:

Sorensen/Skaggs (Manager / Source)

Accountability:

Chase / Bishop Trend:

Meeting OPPDs Gaol SEP 25,26 & 27 15

Monthly Recordable injury / Illness Frequency Rate a

Rolling 12 Month Average

)

Fort Calhoun Goal 4.5..

4.0..

3.5..

l 3.0.

2.5.-

o 2

2.0._

a 1.5 o...............................e.......................................................

1.0 Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb RECORDABLE INJURY /lLLNESS FREQUENCY RATE This indicator shows the monthly recordable injury / illness frequency rate, a rolling 12 month average, and the OPPD goal.

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 rolling 12 month average.

The recordable injury / illness frequency rate for the month of February 1997 was 2.12.

The recordable injury / illness frequency rate for the past 12 months (Mar.1996 through Feb 1997) was 2.2.

During the month of February 1997, there were 0 recordable injuries.

There have been a total of 2 recordable injury / illness cases in 1997.

The 1997 Fort Calhoun Station year-end goal for this indicator is a maximum value of 1.5.

Data Source:

Sorensen Accountability:

Bishop Trend:

Needs Management Attention SEP 15,25,26 & 27 16

m ContaminationEvents(Monthly)

Contamination Ewnts (YrD) 100..

90..

80.

70.

i 60..

50..

40.

30..

i 20..

10..

s 0

Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec CLEAN COHTROLLED 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 February 1997.

There were 8 contamination events in February 1997. There have been eight (8) contamination events in 1997 through the end of February 1997.

Data Source:

Chase /Cartwright (Manager / Source)

Accountability:

Chase /Gebers Trend:

Needs Management Attention SEP 15 & 54 17

i l

m PersonnelErrors(EschMonth)

+ Preventable (18-MonthTotals) e_. Personnel Error (18-Month Totals) 20 15 10.

5~ N

?=

C O

.E

,E,

.E,E Aug sep Oct Nov Dec Jan Feb Mar Apr May Jun Jul Aug sep Oct Nov Dec Jan 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.

Due to the manner in which documentation is closed out, data for this Performance Indicator is one month behind.

in January 1997, there was one event which was subsequently reported as an LER. No LERs were categorized as Preventable and no LERs were categorized as Personnel Er-ror for the month of January. The total LERs for the year 1997 is one.

The total Personnel Error LERs for the year 1997 is zero.

The 1997 goal for this indicator is that the year-end values for the 18-month totals not exceed 12 Preventable and 5 Personnel Error LERs.

Data Source:

Tills /Cavanaugh (Manager / Source) l Accountability:

Chase l

Trend:

Needs increased Management Attention SEP 15 l

l 18

l.

l l

l I

, Startup Shutdown Operations

...o...

Industry Average Trend 2

l

=

b l

1

.o......o......

,,,a,,,,

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

,,,a 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 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. This rendered the scram input inoperable at 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.

i 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 seat, excessive venting line back pressure, and cracked valve disks; 2) Calibration errors of the offsite power low signal relays could have prevented offsite power from tripping and the EDGs from starting in the required amount of time during a degraded voltage condition; 3) Both AFW pumps were inoperable when one was removed from service for testing and the control switch for the other pump's steam supply valve was out of the auto position;

4) Only one train of control room ventilation was placed in recirc when both toxic gas monitors became inoperable. Later during surveillance testing, the other train auto-started and brought outside air into the control room for a six-minute period.

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

4th Quarter 1994: An accident scenario was identified that could result in the inoperability of both control room air conditioning units. Following certain accident conditions, CCW temperature could rise causing compressor rupture disc failure and a release of freon.

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

l l

Data Source:

Nuclear Regulatory Commission Accountability:

Chase Trend:

Positive 19

m Highes' Wnthly hdividual Exposure trR a Year-to-date

+ Fort Cahoun Goal 1000 rnR 1000 900.

800.

700.

600.

500.

400.

300.

200.

100..

Jan Feb Mar Apr May Jun Jul Aug Sep oct Nov Dec MAXIMUM INDIVIDUAL RADIATION EXPOSURE This indicator shows the highest exposure for an individual during January 1997.

For the month of February 1997, an individual accumulated 544 millirem, which was the highest individual exposure for the month.

For the year to date, an individual has accumulated a total of 551 millirem.

The OPPD limit for the maximum yearly individual radiation exposure is 4,000 mrem /

year. The 1997 Fort Calhoun Station year-end goalis a maximum of 1,000 mrem.

Data Source:

Chase /Cartwright (Manager / Source)

Accountability:

Chase /Gebers Trend:

None 20

m FCS Cited Violations (Monthly)

, FCS Non-Cited Violations (Monthly) e FCS Cited Violations (12-Month Average)

FCS Non-Cited Violations (12-Month Average)

__m Region IV Cited Violations (12-Month Average for Region IV top quartile) 10 8..

6_-

~~

2 C

C 3

~

4--

c o

2 b,M

,b

,b, o

S 5'

4 A

E E

8 A

E 6

x e

cn c.

~

o e

.o 1996 VIOLATION TREND This indicator illustrates a 12-mnth 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 informa-tion on other Region IV plants.

The following inspections were completed during February 1997:

IER No.

Iltle i

96-18 Resident Monthly To date, OPPD has received no violations for inspections conducted in 1997.

Levellli Violations 0

LevelIV Violations 0

Non-Cited V;olations

_Q Total 0

i The 1997 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 (Manager / Source)

Accountability:

Tills Trend:

None 21

m NRC Significant Events

_.e._ industry Average Trend 1

1 1 -.

0.5 -.

o o

0 e

r r

r 92 93 94 95-1 95-2 95 3 954 96-1 96 2 96-3 964 Year-Quarter INPO Significant Events (SEs) 3 3

2 2

I 2

1 1

i 1

o o

DI 92 93 94 95-1 95-2 95-3 954 96-1 96-2 96-3 96-4 Year-Quarter SIGNIFICANT EVENTS NRC SIGNIFICANT EVENTS The following SEs were identified between the 2nd Quarter of 1992 and the 1st quarter of 1995 (as reported in the NRC's

Performance Indicators for Operating Nuclear Power Reactors

report dated June 30,1995):

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

INPO SIGNIFICANT EVENTS The following SEs have been identified since 2nd Quarter of 1992 by INPO:

2nd Quarter 1992:

Intake of transuranics during letdown filter change-out.

3rd Quarter 1992:

Safety Valve malfunction (RC-142).

1st Quarter 1993:

Inoperability of Power Range Nuclear Instrumentation Safety Channel D.

2nd Quarter 1993:

Inadequate control of Switchyard activities.

3rd Quarter 1993:

Loss of reactor coolant due to malfunction of Pressurizer Safety Valve.

1st Quarter 1994:

1)

Unexpected CEA withdrawal. (Event occurred November 13,1993 but was not identi'ied as an SE until 1st Quarter 1994).

2)

Unplanned dilution of Boron concentration in the Reactor Coolant System.

1st Quarter 1996:

During pressurizer solid plant operation, the Low Temperature Overpressurization (LTOP) protection for the RCS was inadvertently disabled.

2nd Quarter 1996:

RC Pump Anti-Reverse Rotation Device (ARD) failure.

No SE reports have been received frorn INPO on the 1996 SEs as of August 1, 1996.

Data Source:

Nuclear Regulatory Commission & INPO Accountability:

Chase Trend:

Positive 22

Missed STs Resultingin LERs 3..

2..

1 0

0 0

0, 96 Jan Feb Mar Apr May Jun Jul Aug sep-Oct Nov Dec NUMBER OF MISSED SURVEILLANCE TESTS RESULTING IN LICENSEE EVENT REPORTS This indicator shows the number of missed Surveillance Tests (STs) that resulted in Licensee Event Reports (LERs) during February 1997.

There were no missed surveillance tests resulting in LERs during February 1997.

The 1997 Fort Calhoun monthly goal for this indicator is 0.

Data Source:

Monthly Operating Report & Plant Licensee Event Reports (LERs)

Accountability:

Chase /Phelps Trend :

Positive SEP 60 & 61 23

)

1 i

i l

PERFORMANCE

)

l Goal:

To strive for Excellence in Operations utilizing the j

highest standards of performance at Fort Calhoun Station that l

result in safe, reliable plant operation in power production.

1 l

i t

i l

i i

i

,i 24 1

1 I

l l

... ~. -

l f

Net Generation (10,000 MWh) l 40.

34.55 34.84 34.81 34.43 35.14 32.82 30 i

1888 m.i.

l 2

0** s '

RFO j

EP 2:

20.16 Ntage g 20..

8 15.16 10..

l t

i j

0, i

l i

i i

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

l l

STATION NET GENERATION During the month of February 1997, a n# ' _

3,269.3 MWh was generated by the Fort Calhoun Station. Cumulative net g

'.; Cycle 16 was 5,418,326.6 MWh.

Cumulative net generation for Cycle 17 was b 33,775.20 MWh at the end of February 1997.

Energy losses for June 1996 were attributed to a failure of the Anti-Rotation Device (ARD) associated with Reactor Coolant Pump Motor RC-3B.

}

Energy losses for March 1996 were attributed to (1) a planned mini-outage, and j

(2) condenser tube leakage repair.

l l

Energy losses for Decemoer were attributed to a steam leak on the turbine control valves j

(MOV-CV).

Data Source:

Station Generation Report 4

Accountability:

Chase

)

Trend:

None 1

l 25 i

, Monthly Forced Outage Rate

+ Rolling 12 Month Average

+ 1997 Fort Calhoun Goal (1.4%)

50%.

45%..

40%.-

35%..

30 %

25%.-

20%-.

15% __

10%

5%._E 0

O O

O 0

0 A

0 0

0%

96 Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb FORCED OUTAGE RATE The forced outage rate (FOR) for the month of February 1997 was 0.00. The forced outage rate for the previous 12 months (Mar.1996 through Feb.1997) was 5.38%. The 1997 year-to-date FOR was 0.00% at the end of February 1997.

Energy Losses are explained on Page 25.

The 1997 Fort Calhoun Station year-end goal for this indicator is a maximum value of 1.4%.

Date Source:

Monthly Operating Report Accountability:

Chase Trend:

None 26

m MonthlyUnitCapacityFactor

...g...

Year-to-Date Unit Capacity Factor Unit Capacity Factor for Cycle 17

+ 1997 FCS Goal (81.49%)

i 110 %.

1C0% __

90% -- 85.20%

+

80%..

70%..

60%__

Cycle 17 50%.

40%__

30%__

j j

j 20%.-

10%__

1 n*4

{

C-16 Mar Apr May Jun Jul Aug sep Oct Nov Dec Jan Feb i

I UNIT CAPACITY FACTOR This indicator shows the plant monthly Unit Capacity Factor, the Unit Capacity Factor for the current fuel cycle, the year-to-date, and the 1997 OPPD Station goal.

The Unit Capacity Factor is computed as follows:

Net Electrical Energy Generated (MWH)

Maximum Dependable Capacity (MWe) X Gross Hours in the Reporting Period Cycle 16 Unit Capacity factor was 85.23%,.

At the end of February 1997, the Cycle 17 Unit Capacity Factor was 75.09%. The Unit Capacity Factor for the last 36 months (Mar.1994 through Feb.1997) was 85.68%. The 1997 Fort Cal-houn annual goal for this indicator is 82.00%.

The year-to-date value is 100.42%.

Data Source:

Monthly Operating Report Accountability:

Chase Trend:

None 27 l

f-

i

, Monthly EAF

_. Year-to-Date Average Monthly EAF

+ 12 Month Rolling Average

+ OPPD Goal 100% _.

'8 3%

vs,es 3

[

s A

III\\

i 80%

'2.L%

._}

60%

u.os 40%_

l l

20%__

1E RFO

U ; F-'I 0%

96 Feb Mar Apr May Jun Jul Aug sep Oct Nov Dec Jan Feb EQUIVALENT AVAILABILITY FACTOR This indicator shows the plant monthly Equivalent Availability Factor (EAF), the year-to-date average monthly EAF, the 12 month rolling average, and the OPPD goal.

The EAF for February 1997 was 99.2%. The 12 month rolling average (Mar.1996 through Feb.1997) was 72.4%. The equivalent availability factor for the past three years (Mar.1994 through Feb.1997) was 85.36%.

The Fort Calhoun Station goal for this indicator is an EAF of 93.00%.

Data Source:

DietzNandervort (Manager / Source) i Accountability:

Chase Trend:

None 28 i

I I

i e Safety System Actuations (INPO Definition)

FCS Goal (0)

+ Industry Upper 10 Percentile (0) 3.

l l

2__

1 1__

o 0

0 0

96 Mar Apr May Jun Jul Aug Sep oct Nov Dec Jan Feb UNPLANNED SAFETY SYSTEM ACTUATIONS -(INPO DEFINITION)

There were no WANO unplanned safety system actuations during the month.

There were no WANO unplanned safety system actuations during 1996.

The 1997 Fort Calhoun goal for this indicator is 0.

Data Source:

Monthly Operating Report & Plant Licensee Event Reports Accountability:

Phelps/Foley/Ronning Trend:

Positive 29

m SafetySystem Actuations(NRCDefinition)

FCS Goal (0) i

+ CriticalHours 10..

1996 IFo

. 800

_.700 E

__600 o

N

~~ 000 6"

E E

9

- 400 :E i

..300

s*

__200 2__

l 100 0 0 0 0

0 DJ FMAMJ JAS OND J FMAMJ J ASONDJ F 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.

There have been no unplanned safety system actuations in the last 12 months. The 1997 Fort Calhoun goal for this indicator is 0.

Data Source:

Monthly Operating Report & Plant Licensee Event Reports (LERs)

Accountability:

Phelps/Foley/Ronning Trend:

None 30

4 i

m Gross HeatRate l

+ Year-to-Date Gross Heat Rate

._,__ Fort Calhoun Goal 14.75..

14.25 13.75 __

i j

13.25.

j 12.75..

j p 12.25 _

o 11.75..

8 4 11.25 10.75..

10.25 -

/

C "'

-om7 5

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

GROSS HEAT RATE i

This indicator shows the Gross Heat Rate (GHR) for the reporting month, the year-to-date GHR, the goals, and the year-end GHR for the previous three years.

The gross heat rate for Fort Calhoun Station was 10,015 BTUlkWh for the month of Febrilary 1997. The 1997 year-to-date GHR was 10,024 BTU /kWh at the end of the month.

The GHR varies with fluctuations in river water temperature. In general, the GHR im-j 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 1997 Fort Calhoun year-end goal f ar this indicator is 10,166 BTUlkWh.

Data Source:

Guinn/Willett (Manager / Source)

Accountability:

Chase /Skiles Trend:

None 31

--e. ThermalOutput

._e Fort Cahoun 1495 fAV Goal

+ Tech Spec 1500 FAN Linit 1sa :

1499.

1498.

~ ~ ~ ~-

1497.

1496.

1495 - - - - - =

=

1494.

l 1493.

1492 1 2 3 4 5 6 7 8 9 to 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28

)

i DAILY THERMAL OUTPUT l

The thermal output graph displays the daily operating power level during February 1997, the 1500 thermal megawatt average technical specification limit, and the 1495 thermal megawatt Fort Calhoun goal.

Data Source:

Guinn/Willett (Manager / Source)

Accountability:

Chase /Short Trend:

None 32

+ Monthly Equipment FOR

+ Equipment FOR/1,000 Critical Hrs. (Rolling 12 Month interval) j Fort Calhoun Year-End Goals (0.2) 2.

I 1__

f 2

2 2

d x

x x

0 Mar Apr May Jun Jul Aug Sep oct Nov Dec Jan Feb EQUIPMENT FORCED OUTAGES l

PER 1,000 CRITICAL HOURS The equipment forced outage rate per 1,000 critical hours for the 12 months from March 1,1996, through February 28,1997, was 0.286. The year-to-date rate per 1,000 critical hours for the months from January 1,1997 through February 28,1997 was 0.00.

An equipment forced outage occured during the month of June 1996, due to the failure of the Anti-Rotation Device associated with RC-3B-M.

An equipment forced outage occured at the end of the March 1996, due to condenser tube leakage.

The 1997 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 /Phelps Trend:

Needs increased Management Attention 1

33

J CHEMISTRY ACTION LEVELS EXCEEDED mamme Event Days + Average Event Days : OFTD LMit 6,.

S.

4.

h3.

b2.

5 I

O

(

l.

E

{

E 5

k 7

4 y

5 7

7 r

8 a

s s

8 a

s a

a s

a a

MONTH 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 average of days an action level is exceeded. The parameter action levels are delineated in Chemistry 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 exception 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 separately and there can be multiple events per day.

The 1997 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.

There were no event days in February.

Data Source:

Chase / Spires Accountability:

Spires Trend:

None 34

t a% Hours out of Umit

-"'*- oPFO Goal (5%)

12.00.

10.00.

8.00.

6.00.

=

4.00.

1 2.00 -

0.00 m

R 6

6 x

e 3

m a

o e

o

~

i t

i 8

5 3

8 8

A e

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 0.00% for the month of February 1997.

The 1997 Fort Calhoun Station monthly goal for this indicator is a maximum of 5% hours out of limit.

Data Source:

Chase / Spires (Manager / Source)

Accountability:

Spires Trend:

None 35

2 i

I l

t i

i i

1 l

Cost i

l i

j Goal: Operate Fort Calhoun Station in a manner that cost offectively maintains nuclear generation as an cconomically viable contribution to OPPD's bottom line.

Cost consciousness is exhibited at all levels of the organization.

36

Actual e__ Budget Plan 4.0 0..

3.75 ;.

3.50 3.25..

3.00.

3 :::-.

L.

_ m ; ; ;

2.25..

2.00 4 4 4 ii * = < = ' ' * " o ggggg~

88{488

= a 8

Months CENTS PER KILOWATT HOUR January 1997 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 1996 and 1997 revised budgets. The basis for the actual curve is the Finan-cial and Operating Report.

The December 31 amounts are also shown for tiis prior years 1992 through 1996. In addition, the report shows the plan amounts for the years 1998 through 2002 for refer-ence. The basis for the dollars are the Nuclear Long Range Financial Plan and the 1997 Corporate Planning and Budget Review. The basis for the generation is provided by Nuclear Fuels.

The 12-month rolling average unit price (period of January,1996 through January,1997) averaged above the budget due to 12-month rolling expenses meeting the budget expec-tations, but the 12-month rolling generation not meeting the budget expectations. The 12-month rolling average (1/96 through 1/97) is 3.39 cents per kilowatt hour.

The year-to-date average is trending negatively.

Cents per KWH Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Budget Y-T-D 2.83 2.64 2.55 2.57 2.53 2.51 2.53 2.50 2.49 2.49 2.47 2.46 Actual Y-T-D 2.89 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Data Source:

Lounsberry/ Dent (Manager / Source)

Accountability:

Lounsberry Trend:

Needs Management Attention 37

Corrective Maintenance Preventive Maintenance

)

]

m Non-Correctrve/Plantimprovements

_e_. Ibrt Calhoun Goal

)

1000'-

890 870 830 780 f

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

j Non-Outage Maintenance Work Order Backlog J

1 l

Past Completion B Total MWos Completed j

MWO PRIORITY BREAKDOWN 63%

600 441 400 L"

-,-W:tM"'*

b :s c 2' 37 %

0_

b ' kt j102 yj67[lf

[dk:

200.

I b6

.--o Not Completed l

Riority Riority Riority Riority Riority i

1 2

3 4

5 j

i i

MAINTENANCE WORKLOAD BACKLOG

.i 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 prior-ity. The 1997 goal for this indicator is 350 non-outage corrective maintenance MWOs. The cur-rent backlog of corrective MWOs is 429. To ensure that the MWO backlog is worked in a timely manner, non-outage maintenance completion goals have been established as follows:

GDal Piiority 1 Immediate Action 2 days Priority 2 Urgent 5 days Priority 3 Operational Concerns 21 days Priority 4 Routine Corrective 90 days Priority 5 Non-Essential 180 days Data Source:

Chase / Johnson (Manager /Sou ce)

Accountability:

Chase /Faulhaber Trend:

Adverse SEP 36 39

l NO DATA PROVIDED I

1 i

RATIO OF PREVENTIVE TO TOTAL MAINTENANCE PREVENTIVE MAINTENANCE ITEMS OVERDUE The top graph shows the ratio of completed non-outage preventive maintenance to total com-pleted non-outage maintenance. The ratio was 60.04% for the month of January 1997.

The lower graph shows the percentage of scheduled preventive maintenance items that are over-due. During January 1997,478 PM items vere completed.

The 1996 Fort Calhoun monthly goal for the percentage of preventive maintenance items overdue is a maximum of 0.5%.

Data Source:

Chase / Johnson /Meistad (Manager / Sources)

Accountability:

Chase /Faulhaber Trend:

Meets OPPD Goal SEP 41 & 44 40

l I

e Rework as identified by Craft

+ Fort Calhoun Goal (<3%)

] 5%.

43%

f 4%.

33%

3,7%

O 3%._

3 2% _

tm ta t4%

ts%

1%.

o.8%

0.s%

03%

L'"

M E;M, i

n*4 i

i M..,

.., M, Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jar.

Feb e No. Wintenance tens Competed

% identifed as Repeat 700.

. 8.0%

600 T

526

. 6M 500 400.

35 288

. SM

. 4.0%

IIIl.Illl.i i

2 220 217 214 207

. 3.0%

)

200 o

nns Jan Feb Wr Apr Wy Jun Jul Aug sep Oct Nov Dec

)

PERCENTAGE OF TOTAL MWOs COMPLETED PER MONTH IDENTIFIED AS REWORKIREPEAT 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 November to the 15th of December, due to the delay in closing open MWOs at the end of each month.

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

Data Source:

Faulhaber/ Johnson (Manager / Source)

Accountability:

Chase /Faulhaber Trend:

None 41

_-____________-_________________-_________-_-_____________m

M i onthlyOvertime(On-Une)

+ Y T D Monthly Average (On-Une)

,_. Fort Calhoun "On-Une" Goal (10%)

8.0%.

7.0%..

6.0%..Og\\

5.0%..

4.0%..

3.0%._

2.0%.

1.0%..

0.0%.

Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 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 4.6% for the month of February 1997.

The 1997 Fort Calhoun monthly "on-line" goal for this indicator is a maximum value of 8%.

1 Data Source:

Chase / Johnson (Manager / Source)

Accountability:

Chase /Faulhaber 1

Trend:

None j

42 i

- --- -~ m I

j Human Performance CRs(Maintenance) j 20..

I 18 16..

1 14 i

g 12 e

A

}

g 10 __

O I8 -

l 6

6--

5 i

i i

Aug Sep Oct Nov Dec Jan Feb 6

i PROCEDURAL NONCOMPLIANCE INCIDENTS (MAINTENANCE)

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

Data Source:

Faulhaber

)

Accountability:

Chase /Faulhaber Trend:

None SEP 15,41 & 44 43

~

e._ % PASS oos x._ % Non-PASS ooS

._a

%TotalcoS

+ Total % ooS Goal 50%.

45%.

40%.

35%.

30%.

25%.

20%.

l 15%

h 10%-

e 5% " % x_.'~~'A~~~A

' 5 X

-X

- [ _..____.. ] _ _ { Q 0%

x-x 8

8 8

b k

k N

k b

IN-LINE CHEMISTRY INSTRUMENTS OUT-OF-SERVICE This indicator shows the percentage of hours the in-line chemistry system instruments are inoperable for the reporting month. The chemistry systems involved in this indicator in-clude the Secondary System and the Post Accident Sampling System (PASS). At the end of February 1997, the percentage of hours the in-line chemistry system instruments were inoperable was 1.47%. The following instrument was out of service for the current month:

1.

% PASS HOURS OUT OF SERVICE NONE 2.

% NON-PASS HOURS OUT OF SERVICE NONE 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 cre not operational, then the instrument 5 not performing its intended function.

Data Source:

Chase /Reneaud (Manager / Source)

Accountability:

Chase /Skiles Trend:

Positive - Better than OPPD Goal 44

m Waste Produced Each Month (Kilograms)

Fort Calhoun Monthly Average Goal (150 kilograms)

Federal & Stale Monthly Limit (Max.of1,000 kg) 1000 e,

900.

800..

700..

600..

E 500..

400.

300..

200..

=

100 O

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

During the month of February 1997,0.0 kilograms of non-halogenated,0.0 kilograms of halogenated and 0.0 kilograms of other hazardous waste was produced.

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

The 1997 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 45

i

{

g ContaminatedibdiationControlled Area l

Fort Calhoun Goal (10%)

t

=

)

t 4

l 9%..

i

.I I

111111 &

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

CONTAMINATED RADIATION CONTROLLED AREA This indicator shows the percentage of the Radiologically Controlled Area that is contami-l 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 February 1997, the percentage of the total square footage of the RCA that was contaminated was 8.2%.

1

)

I i

1 J

Data Source:

Chase / Williams (Manager / Source) i Accountability:

Chase /Gebers Trend:

None SEP 54 46 4

Poor Radiation Worker Practices

+ Fort Calhoun Goal (<125) 16 T

14.

12.

10.

8.

G.

4.

2.

0 0

0:

e Jan Feb Wr Apr my June July Aug sep oct Nov Dec 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' radiclogical performance.

During the month of February 1997, there were O PRWP identified.

There have been a total of 0 Poor Radiation Worker Practices in 1997.

The Fort Calhoun Station year-end goal for PRWPs is a maximum of 12.

Data Source:

Chase /Cartwright (Manager / Source)

Accountability:

Chase /Gebers Trend:

None SEP 52 47

---~~

O Documents ScheduledforReview g Documents Reviewed g Documenh Overdue 400..

350..

300--

250.

200.-

150..

100 -,.

50..

O___ E,_ _

n+ _

O _

+_

+

+_

y Mar Apr May Jun Jul Aug sep Oct Nov Dec Jan Feb 1996 DOCUMENT REVIEW The Document Review indicator shows the number of completed, scheduled, and over-due (greater than 6 months past the scheduled due date) biennial reviews for the report-ing month. The documents reviews are performed in-house and include Special Proce-dures, the Site Security Plan, Ulaintenance Procedures, Preventive Maintenance Proce-dures, and the Operating Manual.

During February 1997, there were 377 document reviews scheduled, while 50 reviews were completed. At the end of the month, there were 32 document reviews more than 6 months overdue. There were 3 new documents initiated during February 1997.

Data Source:

Chase /Plath Accountability:

Chase /Skiles Trend:

None SEP 46 48 l

g System Failures O Non-System Failures 3

3 25.-

21 22 20 1

Mar Apr May Jun Jul Aug sep oct Nov Dec Jan Feb LOGGABLE/ REPORTABLE INCIDENTS (SECURITY) 1 This graph shows the Loggable/ Reportable incidents (Security) Indicator and depicts (1) the total number of loggable/ reportable incidents concerning system failures which oc-curred during the reporting month, and (2) the total number of loggable/ reportable inci-dents non-system failures concerning Security Badges, Access Control and Authoriza-tion, Security Force Error, and Unsecured Doors.

During the month of February 1997, there were 10 loggable/ reportable incidents identi-fied. System failures accounted for 90% of the total failures. This is a 67% decrease from the previous reporting period. An action plan was developed and implemented at the beginning of this reporting period in an effort to decrease security system mom cystem failures. The plan appears to be having a positive influence on our indicators. Results will continue to be monitored.

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

Data Source:

Sefick/Woerner(Manager / Source)

Accountability:

Sefick Trend:

None SEP 58 49

~

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

Fort Calhoun Goals for >1. cycle and >6 mor tan old 3

3 3

7 2.5.-

2.-

1.5.

1 1

O.5.

e oo oo oo oo o

oo

>o o

k E

E 3

?

E

,E 1

o m

z 4

v3 o

z u.

TEMPORARY MODIFICATIONS This indicator provides information on the number of temporary modifications (TMs) greater than one fuel cycle old requiring a refueling outage (RFO) for removal and the number of temporary modifications removable on-line that are greater than six months old. The 1997 Fort Calhoun monthly goals for this indicator are zero.

There is currently one (1) temporary modification that is greater than one-fuel cycle old requiring a refueling outage to be removed. TM 96-014, Reactor Coolant Gas Vent Line Pressure High Alarm, was scheduled and repairs were made during the 1996 Refueling Outage, but function testing of the repairs cannot be performed because the reactor coolant gas vent line pressure is currently too high to test the equipment At the end of February 1997, there were 2 temporary modifications installed that were greater than six months old that could have been removed on-line. These TM are listed below.

At the end of February 1997, there was a total of 14 TMs installed in the Fort Calhoun Station.

Six (6) of the 16 installed TMs require an outage for removal and 8 are removable on-line in 1997, a total of 6 temporary modifications have been installed.

TM 96-018 Equipment Drain Header Soft Rubber Patch > One Fuel Cycle old TM 96-022 Containment Low Flow Purge > 6 Months old TM 96-024 Replacement of Prefilters VA-18A/B/C with Carbon Filters > 6 months old Data Source:

Phelps/ Frank (Manager / Source)

Accountability:

Phelps/Gorence Trend:

Positive SEP 62 & 71 50

i Total Modification Packages Open j

i

,_ Fort Calhoun Year-End Goal (68) 80..

E 75 ps 70.

65 96 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec OUTSTANDING MODIFICATIONS This indicator shows the total number of outstanding modifications (excluding outstanding modifications which are oroposed to be cancelled).

Reporting Cateaorv

'93

'94

'95

'96

'92

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

0 0

0 3

0 0

Mod. Requests Being Reviewed 0

0 0

0 2

0 0

Design Engr. Backlog /In Progress 0

0 0

24 20 Construction Backlog /In Progress 4

1 7

19 1

2 21 Design Engr. Update Backlog /in Progress _1

_1

_5

_6

_Q

_2R Totals 5

2 13 25 6

26 T1 (Outage + OnLine)

(3+2)

(0+2) (4+8) (16+9) (0+6) (26+1)

(49+28)

At the end of February 1997,13 modification requests have been issued this year and 0 modification requests have been cancelled. The Nuclear Projects Review Committee (NPRC) has conducted 6 backlog modification request reviews this year. The Nuclear Projects Committee (NPC) has completed 0 backlog modification request reviews this year.

The 1997 year-end Fort Calhoun goal for this indicator is a maximum of 68 outstanding modifications.

Data Source:

Jaworski/ Walling (Manager / Source)

Lounsberry/Belek (Manager / Source)

Accountability:

Lounsberry/Jaworski Trend:

None 51 l

40.

EARS Requiring Engineering Closeout - Not in Closeout 32 30..

g SE O DEN 20 " 10 8

9 11 12 0

12 1

1 1

10..

4-4 4-0

,E E

E Dec Jan Feb Dec Jan Feb Dec Jan Feb Dec Jan Feb 0-3 Months 3-6 Months 6-12 Months

>12 Mordhs 4

30 O bgineering hspnse g Ne%sq 16 20..

g 8

10 10.-

2 1

o 1

3 3

3 0

l I

l0 0

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

j Closeout 16%

40 s Ans 40 overd..

S c he d.le Repo.ses

{

43.4%

4 c.4%

Response

j 84 %

M overds.e ci..... a i

MJ%

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.

The Total EAR breakdown is as follows:

EARS opened during the month 9

EARS closed during the month 9

Total EARS open at the end of the month 101 Data Source:

Jaworski/Livingston (Manager / Source)

Accountability:

Phelps/Jaworski Trend:

None SEP 62 52

o.3x$,,,,

80 2 y

ctos our co T.

ECN Status - Overall Backlog g Backlogged O Received g Completed

,g

L50,.

... 7 a.,

v 4

..a

' 50.. ii 5

501 d

Sep Oct Nov Dec Jan Feb

,' u6 '

Design Engineering

~

3-6 o.1 Heaths 200.

n s 17 %

150 +

'00 '

r<

n n

n g

or a

74%

Sep Oct Nov Dec Jan Feb System Engineering 300..u,

sn ur us ur ilLLLLL s 97 Aug Sep Oct Nov Dec Jan Procurement / Construction f

36 I

250 W[ms go.

200-8%

150 100 77 Ot b S'I E"" h S*

S*P Oct Nov Dec Jan Feb Draf.1g/ Closeout ENGINEERING CNANGE NOTICE STATUS Data Source:

Jaworski/Livingston (Manager / Source)

Accountability:

Jaworski/Phelps Trend.

None SEP 62 53

77

,7 M4 P dodey 15 2

Pd ty

,g,,, 4 y

,gt, 's + y i

s7%

Total Open ECNs= 520 Total Open ECNs = 520 t

0 DEN. Clos sout or Drafsing Not Congdete 5 Maintennace/Co Luction/Processnent WrkNotComedeen Pd P dodry 5ami 18E2 5 sysessa Englueedng Resposse,Connnmaelom NotComplean U%

19 %

5 DEN.EsginsednghtComiplete w

m 3

I sets oct-96 v-n-,7 Fek,y es%

g as 300 P dl'Y P ' d

l a

w 250.

57 saus init c3 16 20 IF 4

100.

50.

o 4

as 7

3!,

s s,

3.

O, f

P d' *

i sepa cum seuos cace ainer r.is 3

j StiniMe RiplacemertitemB'Ns Open 5,%

, j, 70, 44 47 j

.0.

=

50,

34 45 30.

8 48 47 4

l 20.

2,k

=

o

' r ito iks 0

l Sep Oct P4w the Jan Feb see 3"

Dxanert Omnge ECNs Open l

ENGINEERING CHANGE NOTICES OPEN i

l Data Source:

Jaworski/Livingston (Manager Source) j Accountability:

Phelps/Jaworski l

Trend:

None SEP 62 i-(

54 i

1 i

l 1

O Administrative Control Problem g Ucensed Operator Error g OtherPersonnelError i

I g Maintenance Problem O Design / Construction / Installation / Fabrication ?roblem g Muc.

1 3..

l l

l 2..

1 Il.

i 1

0 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan 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 February 1,1996, through January 1,1997. To be consistent with the Preventable / Personnel Error LERs indicator, this indicator is reported by the LER event date, as opposed to the LER report date.

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

There was one event in January 1997 that resulted in a LER.

Data Source:

Tills /Cavanaugh (Manager / Source) l Accountability:

Chase Trend:

None 55

1 i

O Total Requalification Training Hours g simulator Training Hours g Non-Requalification Training Hours a Number of Exam Failures i

35 " '

34 34 32.5 32 30 __

25.

22 I.

20 __

7 l

16 15.5 l

15.

4 14 4

l 2

3 10 --

8 8

g

.5 5

2 2

2 0

0 l

l 0__

i

I i

i i

Cycle Cycle Cycle Cycle Cycle Cycle Cycle Cycle Cycle i

95-4 95-5 95_6 96-1 96-2 96-3 96-5 96-7 97 1 i

i LICENSED OPERATOR REQUALIFICATION TRAINING i

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 j

subset of the total training hours. Non-Requalification Training Hours are used for AOP/EOP verification & validation, INPO commitments, GET, Fire Brigade, Safety Meetings, and Division Manager lunches.

Exam failures are defined as failures in tr e written, simulator, and Job Performance j

Measures (JPMs) segments of the Licensed Operator Requalification Training.

i i

II Data Source:

Conner /Guliani(Manager / Source)

Accountability:

Conner /Guliani Trend:

None SEP 68 l

4 56 j

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

j 77 4

5..

d j

0000 00 0

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

LICENSE CANDIDATE EXAMS - 1997 i

This indicator shows the number of Senior Reactor Operator (SRO) and Reactor Operator (RO) quizzes and exams taken and passed each month. These intemally administered quizzes and exams are used to plot the SRO and RO candidates' monthly progress.

During the month of February 1997, there were 7 individuals who passed SRO and RO comprehensive written exams.

Data Source:

Conner /Guliani(Manager / Source)

Accountability:

Conner /Guliani Trend:

None SEP 68 57

m Ready to Close

,Cbsed 4

TotalCRs open 2000.

1500.

.a 1000-500.

O 8

8 8

e a

g g

3 4

4 e

a n

m z

5 u.

n CONDITION REPORTS BY LEVEL This indicator shows the total number of Condition Reports which are Closed, Ready to Close, Open and the Total Number of Condition Reports to date.

Level 1 Level 2 Level 3 Level 4 Level 5 Level 6 Tota!

Open 21 11 93 774 32 31 962 Closed 11 3

82 784 358 100 1338 164 Condition Reports are classified as READY to CLOSE.

At the end of February 1997, all "OPEN" Incident Reports are closed.

In response to a SARC recommendation prompted by the increasing backlog of open Condition Reports a team has been formed to review outstanding CR Action items.

Issues under review include: whether the action items are value added or over commitments, development of a meaningful performance indicator and the use (or overuse) of exten-sions. Thie team will report back to the SARC at the March meeting.

Data Source:

Tesar/Burggraf(Manager / Source) 4 Accountability:

Andrews/Gambhir/Patterson Trend :

None 58

3 i

j o Tsaapuuh a M M k R m 4 to m k eno.

a.

i Sam 300.

/

i Fhnner sv==iw

{

250.

41%

0%

$3s MWE O

i i

l l

15%

stuas thc46 Jan87 F4&T 1

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 17 Refueling Outage. This graph indicates:

- Parts Holds - Planning Complete, Awaiting Parts

- System Engineering Holds - Awaiting System Engineering Input to Planning Planner Holds - Maintenance Planner has not completed planning the work package.

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

Data Source:

Chase / Johnson (Manager / Source)

Accountability:

Chase /Faulhaber Trend:

None SEP 31 59

E Last Month g This Month O For Schedule 120..

110__

100__

90 __

80 __

70 -

g T:LE 60 __

o y 50 __

40 __

30 __

20 __

8 10 __.&.

.a.

E 5

I i

3 i

31 i

je i

a

[2 S

gj g

7 E

$4 5

07 EE h

5E

.i e

.i 99 SPECIAL SERVICES ENGINEERING DEPARTMENT OVERALL PROJECT STATUS (Cycle 18 Refueling Outage)

Data Source:

Phelps/Swearngin (Manager / Source) accentabllity:

Phelps/Boughter Trend:

None SEP 31 60

, Actual PRc Date aTarget PRc Date 9/28/97.

MW e

e a

e e

a e

e e

e a

e e

a 7/30/97.

6/30/97.

5/31/97 5/1/97.

- 4/1/97.

3/2/97.

I 1/31/97.

111/9 7 a

~

S e

o e

! ga h

m 2

s c.

PROGRESS OF 1998 REFUELING OUTAGE MODIFICATIONS CYCLE 18 This indicator shows the status of Modifications approved for installation during the Cycle 18 Refueling Outage (March 1998).

The goal for this indicator is to have all modification packages which were identified prior to March 1,1997, PRC approved by October 1,1997.

February 1997 Modifications added: 0 Deleted = 0 Data Source:

Jaworski/ Walling (Manager / Source)

Accountability:

Gambhir/Jaworski Trend:

None SEP 31 61 i

l 1

No data available for Indicator until a baseline is established.

PROGRESS OF CYCLE 18 OUTAGE MODS ADDED TO '98 REFUELING OUTAGE AFTER FREEZE DATE This indicator will show the status of modifications approved for installation during the Cycle 18 Refueling Outage. Since the baseline schedule has yet to be established, there is no information available at this time. The goal for this indicator is to have all modifica-tion packages PRC approved by their target date.

February 1997 i

Modifications Added: 0 Deleted = 0 Modifications Pre-Approved: 0 i

Data Source:

Jaworski/ Walling (Manager / Source)

Accountability:

Gambhir/Jaworski Trend:

None SEP 31 62

, Actual PRc Date a Target FHC[hte 600/97.

e a

501/97-5/1/97.

4/1/97.

3/2/97.

1/31/97.

1/1/97 95-012 96-006 96-004 95-024 PROGRESS OF 1997 ON-LINE MODIFICATION PLANNING (FROZEN SCOPE OF 5 MODIFICATIONS)

This indicator shows the status of modifications approved or in review for approval for on-line installation during 1997. Modifications added to the on-line list after May 1,1995, are not part of this indicator.

The goal for this indicator is to have all modification packages PRC approved by their scheduled date.

February 1997 Modifications Added: 0 Deleted = 0 Data Source:

Jaworski/ Walling (Manager / Source)

I Accountability:

Gambhir/Jaworski Trend:

None SEP 33 j

63

l i

i l

I i

1 j

i l

i ACTION PLANS I

l l

4 l

l l

J l

l f

1 i

)

I 2

f j

64 A

1 J

2 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 prececing month's report as Needing Increased Management Attention for three (3) consecutive months.

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

. Maintenance Workload Backlogs (page 47)

A Work management System improvement project is currently in progress. The purpose of this project is to stream line the maintenance process at Fort Calhoun Station.

This will significantly improve our " WRENCH TIME" by removing inefficiencies and related hurdles that prevent work from being accomplished in a i

timely manner. In addition, it is expected that schedule compliance will also increase and our maintenance backlog will decrease. This project is scheduled to be fully implemented by July 1997.

65

k I

4 1

PERFORMANCE INDICATOR DEFINITIONS j

I~

AUXILIARY FEEDWATER SYSTEM SAFETY SYSTEM CLEAN CONTROLLED AREA CONTAMINATIONS E1,000 PERFORMANCE DISBNTEGRATIONS/ MINUTE PER PROBE AREA The sum of the known (planned and unplanned) unavailable The personnel contamination events in the clean controlled hours and the estimated unavailable hours for the auxiliary area. This indicator tracks personnel performance for SEP feedwater system for the reporting period divided by the critical

15 & 54.

hours for the reporting period multiplied by the number of trains in the auxiliary feedwater system.

CONTAMINATED RADIATION CONTROLLED AREA 4

COLLECTIVE RADIATION EXPOSURE The percentage of the Radiation Controlled Area, which includes the auxiliary building, the radweste building, and Collective radiation exposure is the total extemal whole-body areas of the C/RP building, that is contaminated based on the dose received by all on-site personnel (including contractors total square footage This indicator tracks performance for and visitors) during a time period, as measured by the SEP #54.

j thermoluminescent dosimeter (TLD). Collective radiation exposure is reported in units of person-rom. This indicator DAILY THERMAL OUTPUT tracks radiological work performance for SEP #54.

This indicator shows the daily core thermal output as 4

COMPONENT FAILURE ANALYSIS REPORT (CFAR) rneasured from computer point XC105 (in thermal megawatts).

SUMMARY

The 1500 MW Tech Spec limit, and the unmet portion of the s

1495 MW FCS daily goal for the reporting month are also The summary of INPO categones for Fort Calhoun Station with shown.

I significantly higher (1.645 standard deviations) failure rates than the rest of the industry for an eighteen-month time period.

DIESEL GENERATOR RELIABILITY (26 Demands)

Failures are reported as component (i.e., pumps, motors, main I

steam stop valves, control element motors, etc.) categories.

This indicator shows the number of failures occurring for each emergency desel generrtor during the last 25 start demands

]

Failure Cause Cattgores are:

and the last 25 load-run demands.

Age / Normal Use -thought to be the consequence of DISABLING INJURY /lLLNESS FREQUENCY RATE expected wear, aging, end-of-life, or normal use.

(LOSS TIME ACCIDENT RATE)

Manufacturing Defect. a failure attributable to inadequate This indicator is defined as the number of accidents for all assembly or initial quality of the responsible component or utility personnel permanently assigned to the station, involving j

system.

days away from work per 200,000 man-hours worked (100 man-years). This does not include contractor personnel. This Engineering / Design - a failure attributable to the indicator tracks personnel performance for SEP #25,26 & 27.

inadequate design of the responsible wp.ga or system.

j DOCUMENT REVIEW (BIENNIAL)

Other Devices a failure attributable to a failure or i

)

misoperation of another component or system, including The Document Review Indicator shows the number of associated devices.

documents reviewed, the number of documents scheduled for review, and the number of document reviews that are overdue Maintenance / Action resulting from improper for the reporting month. A document review is considered maintent ice, lack of maintenance, or personnel errors that overdue if the review is not complete within six months of the occur di ring maintenance activitieson the component..

assigned due date. This indicator tracks performance for SEP

46.

Testing Action - reaulting from improper testing or personrni errors that occur during testing activities.

EMERGENCY AC POWER SYSTEM SAFETY SYSTEM PERFORMANCE i

Initial InstaltaiM.. tirror - caused by improper initial installation of equipment The sum of the known (planned and unplanned) unavailable j

and the estimated unavailable hours for the emergency AC CENTS PER KILOWATT HOUR power system for the reporting period divided by the number of hours in the reporting penod multiplied by the number of 4

The purpose of this indicator is to quantify the economical trains in the emergency AC power system.

operation of Fort Calhoun Station. The cents per kilowatt hour indicator represents the budget and actual cents per EMERGENCY DIESEL GENERATOR UNIT RELIABILITY kilowatt hour on a twelve-month average for the current year. The basis for the budget curve is the approved yearly This truficator shows the nurnber of fadures that were reported during trie budget. The basis for the actual curve is the Financial and tast 20. 54 and 100 ernergency d esel generator dernands at the Fort Operating Report.

Calhoun Station. Also shown are Ingger values which correlate to a high level of confidence that a unit's diesel generators have obtained a 1

J 66

PERFORMANCE INDICATOR DEFINITIONS re6atety of greater than or equal to 95% when the demand failures are Each emergency generator failure that results in the generator less than the tngger values.

being declared inoperable should be counted as one demand and one failure.

Exploratory tests during corrective

1) Number of Start Demands: All valid and inadvertent maintenance and the successful test that follows repair to start demands, including all start-only demands and all verify operability should not be counted as demands or failures start demands that are followed by load-run demands, when the EDG has not been declared operable again.

whether by automatic or manualinitiation. A start-only demand is a demand in which the emergency generator EMERGENCY DIESEL GENERATOR UNRELIABILITY is started, but no attempt is made to load the generator.

This indicator measures the total unreliability of emergency

2) Number of Start Failures: Any failure within the diesel generators. In general, unreliability is the ratio of emergency generator system that prevents the generator unsuccessful operations (starts or load-runs) to the number of from achieving specified frequency and voltage is valid demands. Total unreliability is a combination of sta't classified as a valid start failure. This includes any unreliability and load-run unreliability, condition identified in the course of maintenance inspections (with the emergency generator in standby ENGINEERING ASSISTANCE REQUEST (EAR) mode) that definitely would have resulted in a start failure BREAKDOWN if a demand had occurred.

This indicator shows a breakdown, by age and priority of the

3) Number of Load-Run Demands: For a valid load-run EAR, of the nurnber of EARS assigned to Design Engineenng demand to be counted, the load run attempt must meet Nuclear and System Engineering. This indicator tracks one or more of the following criteria:

performana for SEP #62.

A) A load-run of any duration that results from a real ENGINEERING CHANGE NOTICE (ECN) STATUS automatic or manualInitiation.

The number of ECNs that were opened, ECNs that were B) A load-run test to satisfy the plant's load and completed, and open backlog ECNs awaiting completion by duration as stated in each test's specifications.

DEN for the reporting month.

This indicator tracks performance for SEP #62.

C) Other special tests in which the emergency generator is expected to be operated for at least one ENGINEERING CHANGE NOTICES OPEN hour while loaded with at least 50% of its design load.

This indicator breaks down the number of Engineenng Change Notices (ECNs) that are assigned to Design Engineering

4) Number of Load-Run Failures: A load-run failure Nuclear (DEN), System Engineering, and Maintenance. The should be counted for any reason in which the graphs provide data on ECN Facility Changes open, ECN emergency generator does not pick up load and run as Substitute Replacement items open, and ECN Document predicted. Failures are counted during any valid load-run Changes open. This indicator tracks performance for SEP demands.

62.

5) Exceptions: Unsuccessful attempts to start or load-run EQUIPMENT FORCED OUTAGES PER 1,000 CRITICAL should not be counted as valid demands or failures when HOURS they can be attnbuted to any of the following:

Equipment forced outages per 1,000 critical hours is the A) Spurious trips that would be bypassed in the event inverse of the mean time between forced outages caused by of an emergency.

equipment failures. The mean time is equal to the number of hours the reactor is critical in a period (1,000 hours0 days 0 hours 0 weeks 0 months ) divided by B) Malfunction of equipment that is not required during the number of forced outages caused by equipment failures in an emergency.

that period.

C) Intentional termmation of a test because of EQUIVALENT AVAILABILIW FACTOR abnormal conditions that would not have resulted in major diesel generator damage or repair.

This indicator is defined as the ratio of gross available generation to gross maximum generation, expressed as a D) Malfunctions or operating errors which would not percentage. Available generation is the energy that can be have prevented the emergency generator from produced if the unit is opersted at the maximum power level being restarted and brought to load within a few permitted by equipment and regulatory limitations. Maximum minutes.

generation is the energy that can be produced by a unit in a E) A failure to start because a portion of the starting system was disabled for test purpose, if followed by a successful start with the starting system in its normal alignment.

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PERFORMANCE INDICATOR DEFINITIONS 1

FORCED OUTAGE RATE

1) One or more days of restricted work (excluding the day of I

the accident);

)

This indicator is defined as the permntage of time that the unit

2) One or more days away from work (excluding the day of I

was unavailable due to forced events compared to the time the accident); and j

planned for electrical generation. Forced events are failures

3) Fatalites.

or other unplanned conditions that require removing the unit 1

from service before the end of the next weekend. Forced Contractor personnel are not included for this indicator.

i events include start-up failures and events initiated while the

{

unit is in reserve shutdown (i.e., the unit is available but not in IN-UhE CHEMISTRY INSTRUMENTS OUT OF SERVICE service).

Total number of in-line chemistry instruments that are out-of-FUEL RELIABlU1Y INDICATOR service in the Secondary System and the Post Accident Sampling System (PASS).

This indicator is defined as the steady-state primary coolant I-131 activity, corrected for the tramp uranium contribution and LICENSE CANDIDATE EXAMS normalized to a common purification rate. Tramp uranium is fuel which has been deposited on reactor core intemals from This indicator shows the number of SRO and/or RO quizzes previous defective fuel or is present on the surface of fuel and exams that are administered and passed each month.

elements from the manufacturing process. Steady state is This indicator tracks training performance for SEP #68.

defined as continuous operation for at least three days at a power level that does not vary more than + or-5%. Plants LICENSED OPERATOR REQUALIFICATION TRAINING should mllect data for this indicator at a power level above 85%, when possible. Plants that did not operate at steady.

The total number of hours of training given to each crew during state power above 85% should collect data for this indicator at each cycle. Also provided are the simulator training hours the highest steady-state power level attained during the rnonth.

(which are a subset of the total training hours), the number of nonf.EQUALIFICATION training hours and the number of The density corre@on factor is the ratio of the specific volume exam failures. This indicator tracks training performanu for of coolant at the RCS operating temperature (540 degrees F.,

SEP # 68.

Vf = 0.02146) divided by the specific volume of coolant at normal letdown temperature (120* F at outlet of the letdown LICENSEE EVENT REPORT (LER) ROOT CAUSE cooling heat exchanger, Vf = 0.016204), which results in a BREAKDOWN density correction factor for FCS equal to 1.32.

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

Gross heat rate is defined as the ratio of total thermal energy

1) Administrative Control Problem - Management and in British Thermal Units (BTU) produced by the reactor to the supervisory deficiencies that affect plant programs or total gross electrical energy produced by the generator in activities (i.e., poor planning, breakdown or lack of kilowatt-hours (KWH).

adequate management or supervisory control, incorrect i

procedures, etc).

HAZARDOUS WASTE PRODUCED

2) Licensed Operator Error - This cause code captures The total amount (in Kilograms) of non-halogenated hazardous errors of omission / commission by licensed reactor waste, halogenated hazardous waste, and other hazardous operators during plant activities.

waste produced by FCS each month.

3) Other Personnel Error-Errors of omission / commission HIGH PRESSURE SAFETY INJECTION SYSTEM SAFETY committed by non-licensed personnel involved in plant SYSTEM PERFORMANCE activites.

The sum of the known (planned and unplanned) unavailable

4) Maintenance Problem The intent of this cause code is hours and the eshmated unavailable hours for the high to capture the full range of problems which can be pressure safety injection system for the reporting period attributed in any way to programmatic deficie. ices in the divided by the critical hours for the reporting period multiplied maintenanmfunctionalorganization. Activitiesincluded by the number of trains in the high pressure safety injection in this category are maintenance, testing, surveillance,

)

system.

calibration and radiation protechon.

INDUSTRIAL SAFETY ACCIDENT RATE INPO

5) Design / Construction / Installation / Fabrication Problem

- This cause code covers a full range of programmatic This indicator is defined as the number of accidents per deficiencies in the areas of design, construction, 200.000 man-hours worked for all utility personnel permanently installation, and fabrication (i.e., loss of control power due assigned to the station that result in any of the following:

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

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4 w

PERFORMANCE lNDICATOR DEFINITIONS

6) Equipment Failures (Electronic Piece-Parts or MAXIMUM INDIVIDUAL RADIATION EXPOSURE Environmental-Related Failures)-This code is used for spurious failures of electronic pece-parts and failures due The total maximum amount of radiation received by an to meteorological conditions such as lightning, im, high individual person working at FCS on a monthly, quarterly, and winds, etc. Generalty, it includes spurious or one-time annual basis.

failures. Electric components included in this category are circuit cards, rectifers, bistab6es, fuses, capacitors, MWO PLANNING STATUS (CYCLE 17 REFUELING diodes, resistors, etc.

OUTAGE)

LOGGABLE/ REPORTABLE INCIDENTS (SECURITY)

The total number of Maintenance Work Orders that have been approved for inclusion in the Cycle 17 Refueling Outage and The total number of secunty incidents for the reporting month the number that are ready to work (parts staged, planning depicted in two graphs. This indicator tracks security complete, and all other paperwork ready for feld use). Also performance for SEP #58.

included is the number of MWOs that have been engineering holds (ECNs, procedures and other miscellaneous engineering MAINTENANCE OVERTIME holds), parts hold, (parts staged, not yet inspected, parts not yet arrived) and planning hold (job scope not yet completed).

The percent of overtime hours compared to normal hours for Maintenance Work Requests (MWRs) are also shown that maintenance. This includes OPPD personnel as well as have been identifed for the Cycle 17 Refueling Outage and contract personnel, have not yet been converted to MWOs.

MAINTENANCE WORKLOAD BACKLOGS NUMBER OF CONTROL ROOM EQUIPMENT DEFICIENCIES This indicator shows the backlog of non outage Maintenanz Work Orders remaining open at the end of the reporting month.

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

component which is operated or controlled from the Control Room, provides indication or alarm to the Control Room, Corrective - Repair and restoration of equipment or provides testing capabilites from the Control Room, provides components that have failed or are malfunctioning and are automatic actions from or to the Contro! Room, or provides a not performing their intended function.

passive function for the Control Room and has been identified as deficient, i.e., does not perform under all conditions as Preventive - Actions taken to maintain a piece of equipment designed. This definition also applies to the Altemate j

within design operating conditions, prevent equipment Shutdown Panels Al-179, Al-185, and Al-212.

failure, and extend its life and are performed prior to equipment failure.

A plant component which is deficient or inoperable is considered an " Operator Work Around (OWA) ltem"if some Non-Corrective / Plant improvements Maintenance other action is required by an operator to compensate for the activities performed to implement station improvements or condition of the component. Some examples of OWAs are:

to repair non-plant equipment.

1) The mntrol room levelindicator does not work but a local Maintenance Work Priorities are defined as:

sight glass can be read by an Operator out in the plant; Emergency - Conditions which sigruficantly degrade statson

2) A deficient pump cannot be repaired because safety or availabihty.

replacement parts require a long lead time for purchase / delivery, thus requiring the redundant pump to immediate Action Equipment deficieneses which be operated continuously; significantly degrade station reliability. Potential for unit shutdown or power reduction.

3) Special actions are required by an Operator because of equipment design problems. These at:tions may be Operations Concern Equipment deficiencies which hinder described in Operations Memorandums, Operator Notes, station operation.

or may require changes to Operating Procedures; Essential-Routine corrective maintenance on essential

4) Deficient plant equipment that is required to be used station systems and equipment.

during Emergency Operating Procedures or Abnormal Operating Procedures; Non-Essential Routine corrective maintenance on non-essential statbn systems and equipment.

5) System indication that provides criticalinformation during normal or abnormal operations.

Plant improvement - Non-corrective maintenance and plant rmprovements.

This indicator tracks maintenance performance for SEP #36.

69

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

The number of Surveillance Tests (STs) that result in Licensee PERCENTAGE OF TOTAL MWOs COMPLETED PER Event Reports (LERs) during t!e reporting month. This MONTH IDENTIFIED AS REWORK indicator tracks missed STs for SEP #60 & 61.

The percentage of total MWOs completed per month identified OPEN INCIDENT REPORTS as rework. Rework activities are identified by maintenance planning and craft. Rework is: Any additional work required This indicator displays the total number of open incident to correct deficiencies discovered during a failed Post Reports (irs), the number of irs that are greater than six Maintenance Test to ensure the component / system passes months old and the number of open significant irs.

subsequent Post Maintenance Test.

OUTSTANDING MODIFICATIONS FERCENT OF COMPLETED SCHEDULED MAINTENANCE ACTIVITIES The number of Modification Requests (MRs) in any state between the issuance of a Modification Number and the The percent of the number of completed maintenance completion of the drawing update.

activities as compared to the number of scheduled maintenance activities each month. This percentage is shown

1) Form FC-1133 Backlog /in Progress. This number for all maintenance crafts. Also shown are the number of represents modification requests that have not been plant emergent MWOs. Maintenance activites include MWRs, approved during the reporting month.

MWOs, STs, PMOs, calibrations, and other miscellaneous activtties. This indicator tracks Maintenance performance for

2) Modification Requests Being Reviewed. This category SEP #33.

includes:

PERFORMANCE INDICATOR INDEX A) Modification Requests that are not yet reviewed.

This indicator index is calculated from a weighted combination B) Modification Requests being reviewed by the of eleven performance indcator values, which include the Nuclear Projects Review Commrttee (NPRC).

following: Unit Capability Factor, Unit Capability Loss Factor, HPSI, AFW, Emergency AC Power System, Unplanned C) Modification Requests being reviewed by the Automatic Scrams, Collective Radiation Exposure, Fuel Nuclear Projects Committee (NPC).

Rehability, Thermal Performance, Secondary System Chemistry, and industrial Safety Accident Rate.

These Modification Requests may be reviewed several times before they are approved for accomplishment or canceled.

PREVENTABLE / PERSONNEL ERROR LERs Some of these Modification Requests are retumed to Engineering for more information, some approved for This indicator is a breakdown of LERs. For purposes of LER evaluation, some approved for study, and some approved for event classification, a

Preventable LER" is defined as:

planning. Once planning is completed and the scope of the work is clearly defined, these Modification Requests may be An event for which the root cause is personnel error (i.e.,

approved for accomplishment with a year assigned for inappropriate action by one or more individuals), inadequate construction or they may be canceled. All of these different administrative controls, a design construction, installation, phases require review, installation, fabrication problem (involving work completed by or supervised by OPPD personnel) or a maintenance

3) Design Engineering Backlog /In Progress. Nuclear problem (attributed to inadequate or improper upkeep / repair Planning has assigned a year in which construction will of plant equipment). Also, the cause of the event must have be completed and design work may be in progress.

occurred within approximately two years of the " Event Date" specified in the LER (e.g., an event for which the cause is

4) Construction Backlog /In Progress, The Construction attributed to a problem with the original design of the plant Package has been issued or construction has begun but would not be considered preventable).

the modification has not been accepted by the System Acceptance Committee (SAC).

For purposes of LER event classification, a " Personnel Error" LER is defined as follows:

5) Design Engineering Update Backlog /In Progress.

PED has remived the Modification Completion Report but An event for which the root cause is inappropriate actio,1 on the drawings have not been updated.

the part of one or more individuals (as opposed to being attributed to a department or a general group). Also, the The above mentioned outstanding modtrications do not include inappropriate action must have occurred within modrfications which are proposed for cancellation.

approximately two years of the " Event Date" specified in the LER.

OVERALL PRDJECT STATUS (REFUELING OUTAGE) j 70

PERFORMANCE INDICATOR DEFINITIONS Additionally, each event classified as a " Personnel Error" NPRDS components with more than two failures for the should also be classified as " Preventable." This indicator eighteen-month CFAR period.

trends personnel performance for SEP ltem #15.

SAFETY SYSTEM FAILURES PRIMARY SYSTEM LITHlUM % OF HOURS OUT OF LIMIT Safety system failures are any events or conditions that could The percent of hours out of limit are for lithium divided by the prevent the fulfillment of the safety functions of structures or total number of hours possible for the month.

systems, if a system consists of multiple redundant subsystems or trains, failure of alltrains constitutes a safety PROCEDURAL NONCOMPLIANCE INCIDENTS system failure. Failure of one of two or more trains is not (MAINTENANCE) counted as a safety system failure. The definition for the indicator parallels NRC reporting requirements in 10 CFR The number of identifed incidents conceming maintenance 50.72 and 10 CFR 50.73. The following is a list of the major procedural problems, the number of closed irs related to the safety systems, sub-systems, and components monitored for use of procedures (includes the number of closed irs caused this indicator by procedural noncompliance), and the number of closed procedural noncompliance irs.

This indicator trends Accident Monitoring instrumentation, Auxiliary (and personnel performance for SEP #15,41 and 44.

Emergency) Feedwater System Combustible Gas Control, Component Cooling Water System, Containment and PROGRESS OF CYCLE 17 OUTAGE MODIFICATION Containment isolation, Containment Coolant Systems, PLANNING Control Room Emergency Ventilation System, Emergency

)

Core Cooling Systems, Engineered Safety Features This indicator shows the status of modifications approved for instrumentation, Essential Compressed Air Systems, completion during the Refueling Outage.

Essential or Emergency Service Water, Fire Detection or Suppression Systems, Isolation Condenser, Low PROGRESS OF 1995 0N-LINE MODIFICATION PLANNING Temperature Overpressure Protection, Main Steam Line Isolation Valves, Onsite Emergency AC & DC Power j

This indicator shows the status of modifications approved for w/ Distribution, Radiation Monitoring Instrumentation, completion during 1995.

Reactor Coolant System. Reactor Core isolation Cooling i

System, Reactor Trip System and Instrumentation, RADIOLOGICAL WORK PRACTICES PROGRAM Recirculation Pump Trip Actuation Instrumentation, Residual Heat Removal Systems, Safety Valves, Spent

)

The number of identified poor radiological work practices Fuel Systems, Standby Liquid Control System and Ultimate (PRWPs) for the reporting month. This indicator tracks Heat Sink.

radiological work performance for SEP #52.

SECONDARY SYSTEM CHEMISTRY PERFORMANCE RATIO OF PREVENTIVE TO TOTAL MAINTENANCE &

INDEX PREVENTIVE MAINTENANCE ITEMS OVERDUE The Chemistry Performance index (CPI) is a calculation based The ratio of preventrve maintenance (including surveillance on the concentration of key impuntes in the secondary side of testing and calibration procedures) to the sum of non-outage the plant. These key impurities are the most likely cause of corrective maintenance and preventive maintenance detenoration of the steam generators. Criteria for calculating completed over the reporting period. The ratio, expressed as the CPI are:

a percentage, is calculated based on man-hours. Also displayed are the percent of preventive maintenance items in

1) The plant is at greater than 30 percent power, and the month that were not completed or administrativety closed by the scheduled date plus a grace penod equal to 25% of the

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

scheduled interval.

This indicator tracks preventive maintenance activities for SEP #41.

The CPI is calculated using the following equation:

RECORDABLE INJURY /lLLNESS CASES FREQUENCY CPI = ((sodium /0.79) + (Ch;onde/1.52) + (Sulfate /1.44) +

RATE (Iron /3.30) + (Copper /0.30)+(Condensate O2/2.90))/6 The number of injunes requiring more than normal first aid per Where: Sodium, sulfate, chloride and condensate dissolved 200.000 man-hours worked. This indicator trends personnel oxygen are the monthly average blowdown concentrations in performance for SEP #t5,25 and 26.

ppb, iron and copper are monthly time weighted average feedwater concentrations in ppb. The denominator for each of REPEAT FAILURES the five factors is the INPO median value. If the monthly average for a specific pararneter is less than the INPO median The number of Nucioar Plant Reliability Data System (NPRDS) value, the median value is used in the calculation.

components with more than one failure and the number of SIGNIFICANT EVENTS 71

PERFORMANCE INDICATOR DEFINITIONS Significant events are the events identified by NRC staff Tests, Maintenance Procedures, Calibration Procedures, i

through detailed screening and evaluation of operating Special Procedures or Operating Procedures are not experience. The screening process includes the daily review considered as temporary modifications unless the jumper i

and discussion of all reported operating reactor events, as well or block remains in place after the test or procedure is as other operational data such as special tests or construction complete. Jumpers and blocks installed in test or lab activities. An event identified from the screening process as instruments are not considered as temporary a signflicant event candidate is further evaluated to determine modrfications.

if any actual or potential threat to the health and safety of the public was involved. Specific examples of the type of criteria

3) Scaffold is not considered a temporary rnodification.

are summarized as follows:

Jumpers and blocks which are installed and for which MRs have been submitted will be considered as temporary

1) Degradation of important safety equipment; modifiestions until final resolution of the MR and the jumper or blod( is removed or is permanently recorded on

2) Unexpected plant response to a transient; the drawings.

This indicator tracks temporary modrfications for SEP #62 and 71,

3) Degradation of fuel integrity, primary coolant pressure boundary, important associated features; THERMAL PERFORMANCE

4) Scram with complication; The ratio of the design gross heat rate (corrected) to the adjusted actual gross heat rate, expressed as a percentage.

5) Unplanned release of radioactivity; UNIT CAPABILITY FACTOR

6) Operation outside the limits of the Technical Specifications; The ratio of the available energy generation over a given time period to the reference energy generation (the energy that

7) Other.

could be produced if the unit were operated continuously at full power under reference ambient conditions) over the same time INPO significant events reported in this indicator are SERs period, expressed as a percentage.

(Significant Event Reports) which inform utilities of significant events and lessons leamed identified through the SEE-IN UNIT CAPACITY FACTOR screening process.

The net electrical energy generated (MWH) divided by the SPARE PARTS INVENTORY VALUE product of maximum dependable capacity (net MWe) times the gross hours in the reporting period expressed as a percent.

The dollar value of the spare parts inventory for FCS dunng Net electrical energy generated is the gross electrical output the reporting period.

of the unit measured at the output terminals of the turbine generator minus the normal station service loads during the STAFFING LEVEL gross hours of the reporting period, expressed in megawatt hours.

The actual staffing level and the authorized staffing level for the Nuclear Operations Division, The Production Engineering UNPLANNED AUTOMATIC REACTOR SCRAMS PER 7,000 Division, and the Nuclear Services Division. This indicator CRITICAL HOURS tracks performance for SEP #24.

This indicator is defined as the number of unplanned automatic STATION NET GENERATION scrams (RPS logic actuations) that occur per 7,000 hours0 days 0 hours 0 weeks 0 months of critical operation.

The net generation (sum) produced by the FCS during the reporting month.

The value for this indicator is calculated by multiplying the total number of unplanned automatic reactor scrams in a specific TEMPORARY MODIFICATIONS time period by 7,000 hours0 days 0 hours 0 weeks 0 months , then dividing that number by the total number of hours critical in the same time period. The The number of temporary mechanical and electrical indicator is further defined as follows:

configurations to the plant's systems.

1) Unplanned means that the scram was not an anticipated

1) Temporary configurations are defined as electrical part of a planned test.

Jumpers, electrical blocks, mechanical jumpers, or rnechanical blocks which are installed in the plant

2) Scram means the automatic shutdown of the reactor by a operating systems and are not shown on the latest revision rapid insertion of negative reactivity (e g., by control rods, of the P&lD, schematic, connection, winng, or flow liquid injection system, etc.) that is caused by actuation of diagrams.

the reactor protection system. The signal may have resulted from exceeding a set point or spurious.

2) Jumpers and blocks which are installed for Surveillance l

l l

72 i

i 1

4

e PERFORMANCE lNDICATOR DEFINITIONS

3) Automatic means that the initial signal that caused VOLUME OF LOW-LEVEL SOLID RADIOACTIVE WASTE actuation of the reactor protection system logic was provided from one of the sensor's monitoring plant This indicator is defined as the volume of low-level solid parameters and conditions, rather than the manual scram radioactive waste actually shipped for burial. This indicatos swiches or, manual turbine trip swiches (or push-buttons) also shows the volume of low-level radioactive waste which is provided in the main control room.

in temporary storage, the amount of radioactive oil that has been shipped off-site for processing, and the volume of solid

4) Critical means that during the steady-state condition of the dry radioactive waste which has been shipped off-site for reactor prior to the scram, the effective multiplication (k,,

processing. Low-level solid radioactive waste consists of dry

) was essentially equal to one.

active waste, sludges, resins, and evaporator bottoms generated as a result of nuclear power piant operation and UNPLANNED CAPABILITY LOSS FACTOR maintenance. Dry radioactive waste includes contaminated rags, cleaning materials, disposable protectrve clothing, plastic The ratio of the unplanned energy losses during a given period containers. and any other matenal to be disposed of at a low-of time, to the reference energy generation (the energy that level radioactive waste disposal site, except resin, sludge, or could be produced if the unit were operated continuously at full evaporator bottoms. Low-level refers to all radioactive waste power under reference ambient conditions) over the same time that is not spent fuel or a by-product of spent fuel processing.

period, expressed as a perG,xage.

This indicator tradcs radiological work performance for SEP

54.

UNPLANNED SAFETY SYSTEM ACTUATIONS - (INPO

+ DEFINITION)

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

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

2) The number of unplanned emergency AC power system actuations that result from a loss of power to a safeguards bus. An unplanned safety system actuation occurs when an actuation set point for a safety system is reached or when a spurious or inadvertent signal is generated (ECCS only), and major equipment in the system is actuated.

Unplanned rneans that the system actuation was not part of a planned teri or evolution. The ECCS actuations to be counted are actuations of the high pressure injection system, the low pressure injection system, or the safety injection tanks.

UNPLANNED SAFETY SYSTEM ACTIONS -(NRC DEFINITION)

The number of safety system actuations which include (p_n,Q) n the High Pressure Safety injection System, the Low Pressure Safety injection System, the Safety injection Tanks, and the Emergency Diesel Generators. The NRC classification of safety system actuations includes actuations when major equipment is operated 3.nd when the logic systems for the i

above safety systems are challenged.

1 VIOLATION TREND i

This indicator is defined as Fort Calhoun Station Cited Violations and Non-Cited Violations trended over 12 months.

Additionally, Cited Violations for the top quartile Region IV i

plant is trended over 12 months (lagging the Fort Calhoun Station trend by 2-3 months). It is the Fort Calhoun Station j

goal to be at or below the cited violation trend for the top j

quartile Regbn IV plant.

73

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

SEP Reference Number 15 Page

. Increase HPES and IR Accountability through use of Performance Indicators Procedural Noncompliance Incidents (Maintenance) 43 Recordable injury / Illness Cases Frequency Rate

. 16 Clean Controlled Area Contaminations >1,000 Disintegrations / Minute Per Probe Area

. 17 Preventable / Personnel Error LERs 18 SEP Reference Numbers 25. 26. & 27

. Train 5g Program for Managers and Supervisors implemented

. Evaluate and implement Station Standards for Safe Work Practice Requirements

. Implement Superviso y Enforcement of Industrial Safety Standards Disabling injury / Illness Frequency Rate 15 Recordable injury / Illness Cases Frequency Rate 16 SEP Reference Number 31

. Develop Outage and Maintenance Planning Manual and Conduct Project Management Training MWO Planning Status (Cycle 17 Refueling Outage) 59 SSED's Overall Project Status 60 Overall Project Status (Cycle 17 Refueling Outage)

. 61 Progress of Cycle 17 Outage Modification Planning 63 SEP Reference Number 33

. Develop On-Line Maintenance and Modification Schedule 1996 On-line Modification F bnning.

. 62 SEP Reference Number 36

. Reduce Corrective Non-Outage Backlog Maintenance Workload Backlogs (Corrective Non-Outage) 39 SEP Reference Numbers 41 & 44

. Develop and implement a Preventive Maintenance Schedule

. Compliance With and Use cf Procedures Ratio of Preventive to Total Maintenance & Preventive Maintenance items Overdue

. 40 Procedural Noncompliance incidents (Maintenance)

. 43 SEP Reference Number 46

. Design a Procedures Control and Administrative Program Document Review 48 74

SEP Reference Number 52 Engg

. Establish Supervisory Accountability for Workers Radiological Practices Radiological Work Practices Program 47 SEP Reference Number 64

. Complete implementation of Radiological Enhancement Program Clean Controlled Area Disintegrations 11,000 Counts / Minute Per Probe Area 17 Collective Radiation Exposure......

..... 11 Volume of Low-Level Solid Radioactive Waste.....................

12 Contaminated Radiation Controlled Area.......................

. 46 SEP Reference Number 68

. Revise Physical Security Training and Procedure Program Loggable/ Reportable incidents (Security) 4g SEP Reference Numbers 60 & 61

. Improve Controls Over Surveillance Test Program

. Modify Computer Program to Correctly Schedule Surveillance Tests Number of Missed Surveillance Tests resulting in Licensee Event Reports.

23 SEP Reference Number 62

. Establish Interim System Engineers Temporary Modifications....

50 Engineering Assistance Request (EAR) Breakdown...

52 Engineering Change Notice Status 53 Engineering Change Notices Open.....

54 SEP Reference Number 68

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

. 56 License Candidate Exams 57 SEP Reference Number 71

. Improve Controls over Temporary Modifications Temporary Modifications 50 75

e <

REPORT DISTRIBUTION LIST R. L Andrews C. A. Marasco G. C. Bishop T. J. Mcivor C. E. Boughter K. A. Miller C. J. Brunnert P. A. Mruz J. W. Chase R. J. Mueller R. G. Conner R. L. Plott M.R. Core W.J.Ponec T. R. Dukarski D. G. Ried M. L. Ellis M. J. Sandhoefner H. J. Faulhaber F. C. Scofield S. K. Gambhir H. J. Sefick J. K. Gasper R. W. Short W. G. Gates J. L Skiles S. W. Gebers R. D. Spies (2)

D. C. Gorence D. E. Spires R. H. Guy M. A. Tesar A. L. Hale J. J. Tesarek K. R. Henry J. W. Tills J. B. Herman D. R. Trausch R. L. Jaworski L. P. Walling J. W. Johnson G. R. Williams W. C. Jones S. J. Willrett D. D. Kloock M. Edwards (7)

L.T.Kusek B. R. Livingston 76

i e,

j l

kPORT DISTRIBUTION blST R. L. Andrews C. A Marasco G. C. Bishop T. J. Mcivor C. E. Boughter K. A Miller C. J. Brunnert P. A Mruz J. W. Chase R. J. Mueller R. G. Conner R. L. Plott M.R. Core W.J.Ponec T. R. Dukarski D. G. Ried M. L. Ellis M. J. Sandhoefner H. J. Faulhaber F. C. Scofield S. K. Gambhir H. J. Sefick J. K Gasper R. W. Short W. G. Gates J. L. Skiles S. W. Gebers R. D. Spies (2)

D. C. Gorence D. E. Spires M. A Tesar R. H. Guy A. L. Hale J. J. Tesarek J. W. Tills K. R. Henry J. B. Herman D. R. Trausch R. L. Jaworski L. P. Walling J. W. Johnson G. R. Williams W. C. Jones S. J. Willrett D. D. Kloock M. Edwards (7)

L.T.Kusek B. R. Livingston 76

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