Text

Performance Indicators Rept
	ML20136B382
Person / Time
Site:	Fort Calhoun
Issue date:	01/31/1997
From:	; OMAHA PUBLIC POWER DISTRICT
To:	;
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ML20136B373	List: LIC-97-0029, Forwards Fort Calhoun Station Performance Indicators Rept Jan 1997; ML20136B382;
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FORT CALHOUN STATION PERFORMANCE INDICATORS 9

/

JANUARY 1997 SAFE OPERATIONS PERFORMANCE EXCELLENCE COST EFFECTIVENESS

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FORT CALHOUN STATION January 1997 Monthly Operating Report OPERATIONS

SUMMARY

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The Fort Calhoun Station (FCS) was at 30% of rated power on January 1,1997 following the steam leak repairs on the orifice downstream of MOV-CV that occurred on December 31,1996. At 2338 hours0.0271 days 0.649 hours 0.00387 weeks 8.89609e-4 months on January 1,1997, FCS began to increase power after clearing a hold for Steam Generator chemistry. The Station reached 100% of rated power at 2053 hours0.0238 days 0.57 hours 0.00339 weeks 7.811665e-4 months on January 2,1997 and continued to operate at a nominal 100% power level for the remainder of the month.

As a result of the Millstone Unit 2 Licensee Event Report (LER), which reported a problem with the failure to account for steam line pressure drops in the calculation of the Main Steam Safety Valve (MSSV) setpoints, OPPD investigated if similar issues existed at FCS.

Although it was determined on January 22,1997 that MSSV chatter is not an issue at FCS, it was concluded that the number and location of inoperable MSSVs allowed by FCS Technical Specifications could have placed the plant outside of its design basis. OPPD is performing the necessary analyses to update the design basis of the plant and is providing additional guidance to the operating staff to ensure that the revised design basis is maintained. See LER 97-001 for additional details.

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

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Industry Median 90,

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85 83 83 83 30,

82 79 70.

1 60.

f Value for January 1997 31.s7 50.-

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95I1 95/2 95/3 95/4 96/1 96/2 96/3 96/4 Jan Feb 97/1 l

DATES BY QUARTER (HOST RECENT QUARTER BY MONTH / QUARTER)

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

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value will still be tracked, but the value will no longer be used in calculating the Stations Performance Index.

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i UCF UCLF HPSI AFW EACP CRE UAS7 FRl CF1 TPI ISAR This graph shows the difference between the maximum number 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 l

CRE Collective Radiation Exposure FRI Fuel Reliability indicator l

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

l FORT CALHOUN STATION PERFORMANCE INDICATORS REPORT i

January 1997-

SUMMARY

l POSITIVE TREND REPORT POSITIVE TREND REPORT (cont.1 A performance indicator with data representing three Contaminated Radiation Controlled Area consecutive months of improving performance or three (Page 54) consecutive months of performance that is superior to the stated goalis exhibiting a positive trend per Nuclear Temocrary Modifications Operations Division Quality Procedure 37 (NOD 4P-(Page 58) 37).

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

Sa etv Svstem Failures (p 9 19)

ADVERSE TREND REPORT Hiah Pressure Safety Iniection System A performance indicator with data representing three (Page 5) consecutive months of declining performance or three consecutive months of performance that is trending Auxiliary Feedwater System toward declining as determined by the Manager -

(Page 6)

Station Engineering, constitutes an adverse trend per Nuclear Operations Division Quality Procedure 37 Emeroenev AC Power System (NOD-QP-37). A supervisor whose performance (Page 7) indicator exhibits an adverse trend by this definition may specify in written form (to be published in this Secondary Chemistrv report) why the trend is not adverse.

(Page 10)

The following performance indicators exhibited adverse Emeraency Diesel Generator Unit Reliability trends for the reporting month:

(Page 20)

Maintenance Workload Backloa Diesel Generator Reliability (25 Demands)

(Page 47)

(Page 21)

Emeroency Diesel Genentor Unreliability (Page 22)

Missed Survoillance Tests Resultina in Licensee Event Reports (Page 28)

Unolanned Safety System Actuations (INPO Definition)

(Page 34)

Hazardous Waste Produced (Page 53) iv

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INDICATORS NEEDING INCREASED MANAGEMENT ATTENTION REPORT A performance indicator with data for the reporting penod that is inadequate when compared to the OPPD goal is defined as *Needing increased Management Attention" per Nuclear Operations Division Quality Procedure 37 (NOD-QP-37).

Fuel Reliability Indicator (Psge 9)

Eauioment Forced Outaaes (Page 38)

Cents Der Kilowatt Hour (page 44)

WANO INDICATORS (As compared to previous month)

Unit Capability Factor increasing Unplanned Capability Loss Factor No Change l

High Pressure Safety injection No Change Aux. Feedwater System No Change Emergency AC Power No Change Collective Radiation Exposure No Change Unplanned Reactor Scrams No Change Fuel Reliability Decreasing Chemistry Indicator Decreasing Thermal Performance Decreasing industrial Safety Accident Rate No Change j

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Table of Contents / Summary

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. xii l

WANO PERFORMANCE INDICATORS Unit Capability Factor.

2

)

Unplanned Capability Loss Factor 3

Unplanned Automatic Reactor SCRAMS per 7000 Hours Critical 4

High Pressure Safety injection System 5

1 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 Frequency Rate 15 Recordable injury / Illness Frequency Rate 16 Clean Controlled Area Contaminations 11,000 Disintegrations / Minute per Probe Area 17 Preventable / Personnel Error LERs 18 NRC Safety System Failures 19 Emergency Diesel Generator Unit Reliability 20 Reliability (25 Demands) 21 Unreliability 22 l

Control Room Equipment Deficiencies..

23 1

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l On-line and Outage Control Room Equipment Deficiencies

. 24 l

vi l

i 1

l

Table of Contents / Summary Maximum individua! Radation Exposure

........ 25 Violation Trend......

.... 26 Significant Events 27 Number of Missed Surveillance Tests Resulting in LERs..

28 PERFORMANCE Station Net Generation

........... 30 Forced Outage Rate.....................

. 31 Unit Capacity Factor.

........ 32 Equivalent Availability Factor

...... 33 Unplanned Safety System Actuations INPO Definition 34 NRC DefinWon

... 35 Gross Heat Rate

...... 36 Daily Thermal Output

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

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

39 Repeat Failures

. 40 Chemistry Action Levels Exceeded. Event Days...

................... 41 Primary System Lithium % Hours Out of Limit 42 COST Cents Per Kilowatt Hour......

44 Spare Parts Inventory Value 45 vii

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Table of Contents / Summary DMSION AND DEPARTMENT PERFORMANCE INDICATORS Maintenance Workload Backlogs (Corrective Non-Outage)

. 47 Ratio of Preventive to Total Maintenance 48 Percentage of Total MWOs Completed per month identified as Rework 49 Overtime 50 Procedural Noncompliance incidents.....

. 51 in-Line Chemistry Instruments Out-of-Service 52 Hazardous Waste Produced 53 Contaminated Radiation Controlled Area 54 Radiological Work Practices Program 55 Document Review...

. 56 Loggable/ Reportable incidents (Security)..

57 Temporary Modifications 58 Outstanding Modifications

.. 59 Engineering Assistance Request (EAR) Breakdown.

60 Engineering Change Notices Status...............

61 Open..........

.... 62 Licensee Event Report (LED) Root Cause Breakdown 63 Licensed Operator Requalification Training 64 License Candidate Exams 65 Condition Reports...

66 Cycle 17 Refueling Outage MWO Planning Status 67 Overall Project Status.

68 Outage Modification Planning 69 On-Line Modification Planning..

70 Progress of 1996 On-Line Modification Planning 71 viii

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

72 Performance indicator Definitions..........

83 Safety Enhancernent Program index

... 91 Report Distribution List

... 93 i

1 I

4 l

1 8

G IX

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, however, progress and l

success are not. Fort Calhoun must react to these changes while improving capacity, SALP ratings and INPO 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 PQFORMANCE 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 FOCUSISTRATEGIES.

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

MISSION The safe, reliable and cost effective generation of electricity for OPPD 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.

X

l 4

GOALS Goal 1:

SAFE OPERATIONS i

)

Supports: Corporate Strategic Plan Goal 3, Objective: 3 & 4 1

A proactive, self-critical and safety conscious culture is exhibited throughout the i

nuclear organization.

Individuals demonstrate professionalism through self-ownership and personal initiative and open communication.

}.

l 1997 Priorities:

l Achieve an overall SALP Rating of"1"in 1997 Focus on Achieving an.INPO Rating of"1"in 1998 1

Reduce 1997 NRC vblations with no violations more severe than level 4 No unplanned automatic reactor scrams or safety system actuations t

Objectives to support SAFE OPERATIONS.

OBJECTIVE 1-1:

No challenges to a nuclear safety system.

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 concern.

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.

Xi

OPPD NUCLEAR ORGANIZATION GOALS 1997 Priorities Goal 2:

PERFORMANCE Supports:

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 l

Objectives to support PERFORMANCE:

OBJECTIVE 2 I 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 perfo:mance 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 training 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 xii i

(

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 or 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.

j 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

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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)

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, Monthly thit Capability Factor

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

Year 2000 WANo industry Goal (87%)

100%.

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Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan 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 generation over a given period of time to the reference energy generation over the same time period, expressed as a percentage.

The UCF for January 1997 was reported as 100.0%. The year-to-date UCF was also reported as l

100%, the UCF for the last 12 months (Feb.1996 through Jan.1997) was 72.3%, and the 36-month average UCF was reported as (Feb.1994 through Jan.1997) was reported as 83.4%.

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-3B-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.

l 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 January 1997, the FCS Value was 12.0. This compares to the end of the year value of 11.96.

Data Source:

Generation Totals Report & Monthly Operating Report Accountability:

Chase Trend:

None 2

i

, Monthly thplanned Capability 1.oss Factor

+ 12-Month Fbiling Average 1

e-FortCalhounGoal(1.58"4

+ Year 2000MNOlndustry Goal (4.S'S 60%

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Feb Mar Apr May Jun Jtd Aug Sep Oct Nw Dec Jan 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 for the month of January 1997 was reported as 0.00%. The year-to-date UCLF was 0.00%, the UCLF for the last 12 months (Feb.1996 through Jan.1997) was 8.41%, and the 36-month average UCLF (Feb.1994 through Jan.1997) was reported as 6.5% at the i

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 % a maximum value of 1.58%

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The maximum index point value for this indicator is 12. At the end of the January 1997 the FCS Value was 4.77. This compares to the end of the year value of 4.77.

Data Source:

Generation Totals Report & Monthly Operating Report Accountability:

Chase Trend:

Needs increased Management Attention.

l 3

i l

1 12-Month Rolling Average i

+ FCS Roactor Scrams Per 7,000 Hours Critical for last 36 months Fort Calhoun Goal (0.0)

Year 2000 WANO Industry Goal (1) 3.

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Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan FCS Reactor Scrams -1997 l

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95 96 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan UNPLANNED AUTOMATIC REACTOR SCRAMS PER 7000 HOURS CRITICAL The upper graph shows the 12-month rolling average, the 36-month average, the OPPD goal for 1997 and the Year 2000 WANO goal. The lower graph shows the number of unplanned automatic reactor scrams that occurred during the last 12 months. This indicator is defined as the number of unplanned automatic 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 January 1997. The 12-month rolling average (Feb.1996 through Jan.1997) was 0. The 36-month value (Feb.1994 through Jan.1997) was 0.609.

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.

The maximum index point value for this indicator is 8. At the end of the January 1997, the FCS Value was 8.0. This compares to the end of the year value of 8.0.

Data Source:

Monthly Operating Report & Plant Licensee Event Reports (LERs)

Accountability:

Chase Trend:

Positive 4

1 l

m Monthly HPSI system Unavailability Value

- 12 Month Rolling Average e_. Fort Calhoun Goal (0.003)

Year 2000 WANo industry Goal (0.02) 0.02..

0.015.

0.01 0.005 0

e=

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1996 Jan Feb Mar Apr May Jun Jul Aug sep Oct Nov Dec Jan 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 January 1997.

The HPSI System unavailability value for the month of January 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 (Feb.1996 through Jan.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 January 1997 the FCS Value was 10. This compares to the end of the year value of 10.

Data Source:

Phelps/Schaffer(Manager / Source)

Accountability:

Phelps/Schaffer Trend:

Positive 5

i Monthly Auxiliary Feedwater System Unavaliability

.-x-12 Month AFW Unavailability

_ FortCalhoun Goal (0.01)

Year 2000 WANO Industry Goal (0.025) 0.02..

0.018 -_

0.016..

0.014.

0.012 -_

O.01 --

0.008.

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0 2 93 0.00504 0.006 __

0.00356 x

0 1996 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan 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 January 1997.

The AFW System Unavailability Value for January 1997 was 0.00. There were 0.0 hours0 days 0 hours 0 weeks 0 months of planned and 0.0 hours0 days 0 hours 0 weeks 0 months of unplanned unavailability during the month. The 12 month rolling average (Feb.1996 through Jan.1997) was 0.0057, and the year-to-date unavailability value was 0.00 at the end of January 1997.

At the end of December,1996, there were a total of 21.9 hours1.041667e-4 days 0.0025 hours 1.488095e-5 weeks 3.4245e-6 months of planned unavailability and 6.8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months of unplanned unavailability for the AFW system.

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

The Year 2000 WANO industry goal is 0.025.

The maximum index point value for this indicator is 10. At the end of January 1997, the FCS Value was 10. This compares to the year end value of 10.

Data Source:

Phelps/Fritts (Manager / Source)

Accountability:

Phelps/Fritts Trend:

Positive 6

M Monthly Emergency AC Power Unavailability Value

-x-Year-to-Date Emergency AC Power Unavailability value

--o-- Fort Calhoun Goal (0.024) 0.06 -

O.05 -

0.04 -

O.03 -

0.02 -

0.01

-x x---

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Feb Mar Apr May Jun Jul Aug Sep oct Nov Dec Jan 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 month of January 1997.

3 The Emergency AC Power System unavailability value for January 1997 was 0.010. During the month, there was 6.1 hours1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 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 0.010 and the value for the last 12 months (Feb.1996 through Jan.1997) was 0.010.

There has been 14.2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months (11.2 for DG-1 and 3.0 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-end 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 January 1997, the FCS Value was 10.00. This compares to the year end value of 10.00.

Data Source:

Phelps/Ronning (Manager / Source)

Accountability:

Phelps/Ronning 7

Trend:

Positive

i I

l j

m MonthlyThermalPerformance i 12. Month Rolling Average j

+ Fort Calhoun Goal (99.6%)

j

%_. Year 2000 WANO Industry Goal (99.5%)

100%..

5 C

99%_

j 98%

Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan THERMAL PERFORMANCE This indicator shows the monthly Thermal Performance Value, the rolling 12-month average, j

the OPPD goal, and the Year 2000 WANO goal.

The thermal performance value for the month of January 1997 was 99.9%.

The year to date value was reported as 99.9%.

The 12 month rolling average (Feb.1996 through Jan.1997) was reported as 99.7%.

l 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%.

j The maximum index point value for this indicator is 6. At the end of January 1997, the FCS i

Value was 5.13 This compares to the end of the year value of 5.07.

Data Source:

Phelps/Naser(Manager / Source)

Accountability:

Phelps/Gorence 4

Trend:

None I

i 8

m FuelReliability(E-4)

Year 2000 WANO Chal (5 x 10 4 Microcuries/ Gram) 1997 Goal 147E-4 320 299.16 E 2801 257.07 h 240 217.6 200 -

169 159.9 8 160 +

121.9 2 120-1996 y

73.4 78.42 g

h 40 --

4.5 1E1 0

e-- =-- --. n.. age. i Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan FUEL RELIABILITY INDICATOR The FUEL RELIABILITY INDICATOR (FRI) for January 1997 was 16.1E-4 microcuries/ gram. This value is four times larger than the December 1996 FRI of 4.5E-4 microcuries/ gram and indicates an increase in the number or size fo the Cycle 17 fuel failures. Based on the January 1997 chemistry data, and the fuel vendor, Westinghouse, it is estimated that the Cycle 17 core has 4 to 5 failures.

The purpose of the FR1 is to monitorindustry 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 location.

The January 1997 FRI value is based on data from January 6 through January 31. The days selected j

are when the plant chemistry values are at equilibrium for steady-state power operation (above 85%

power for at least 3 days) and the letdown flow is at a constant value. The plant reduced power to approximately 7% on Decemebr 31st to allow the isolation of Main Steam Control valve piping to repair a leak. Power was increased the following day, reaching approximately 100% on January 2nd at about 0900 hours0.0104 days 0.25 hours 0.00149 weeks 3.4245e-4 months .

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 inproved fuel failure resistant grid design in one third of the assemblies in the Cycle 17 core.

The maximum index point value for this indicatoris 8. At the end of the January 1997, the FCS Value was 6.07. This compares to the end fo the year value of 8.0.

Data Source:

Guinn/Guliani Accountability:

Chase /Stafford Trend:

Needs Management Attention 9

I m MontNyChemistryindicator

._,__12-Month Rolling Average j

+ Fort Calhoun Goal (1 A) 2.6 2.51 2.4..

l Y.

j 2.1 2_.

1.9..

1.8 _.

1.7..

1.6 _

j 1.5 i

1A - e c

1.3.

1.2

.E

__._ i i

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

t 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 January 1997 was 1.31. The CPI value for the past 12 months (Feb.1996 through Jan.1997) was 1.32. The OPPD goal for 1997 is a CPI value < 1.4.

l 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-l ber 1996 values. Sodium and copper are still high based on historical data, the dissolved i

oxygen is considered normal. There is currently an Action Plan in place for dissolved oxygen and copper reduction.

4 The maximum index point value for this indicator is 7. At the end of January 1997, the FCS Value was 5.37. This compares to the end of the value of 7.00 10 f

m Monthly Personnel Radiation Exposure

--*- Cumulative Personnel Radiation Exposure

-e-FCS Goal 38 person REM l

40 Tc

=

a 35 -

30 -

25 5

20 -

2 15 l

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.

t The exposure for January 1997 was 1.734 Person-Rem (ALNOR).

The year-to-date exposure through the end of January 1997 was 1.734 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 (Feb.1994 through Jan.1997), the collective radiation exposure was 392.198 person-rem. This gives a Fort Calhoun Station a three year average of 130.732 person-rem per year.

The maximum index point value for this indicator is 8. At the end of January 1997 the FCS Value was 5.73. This compares to the end of the year value of 5.73.

Data Source:

Chase /Cartwright (Manager / Source)

Accountability:

Chase /Gebers Trend:

None SEP54 s

11

Monthly Volume of LLRW (cu.ft.)

[

x._ Year-to-Date Cumulative Radioactive Waste Buried l

Fort Calhoun Goal (1200 cu.ft.)

1 1200 --

1100-_

j 1000..

900..

800._

700.,_

600.

500.

400..

300.

200..

100__

0__0g 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 year-to-date radioactive waste buried, and the Fort Calhoun goal.

Cu.Ft.

Amount of solid radwaste shipped off-site for processing during current month 0.0 Volume of solid radwaste buried during January 1997 0.0 Cumulative volume of solid radioactive waste buried in 1996 0.0 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 metars (1,589 cubic feet) per year. The industry upper ten percentile value is approximately i:7.33 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.

Data Source:

Chase /Breuer(Manager / Source)

Accountability:

Chase /Gebers Trend:

None SEP 54 12

_e Monthlyindustrial Accident Rate e_12 Month Rolling Average

,_. FCS Year-End Goal (<0.50)

+ Year 2000 WANoindustry Goal (<0.40) 1.2,

1.:,.

O.8.

N-DA T

/:

W A

2 2

Y T~

e e

02

=

^

0 Feb Mar Apr May June July Aug Sep oct Nov Dec Jan 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) i Fatalities The purpose of this indicator is to monitor progress in improving industrial safety performance 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:

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

The Fort Calhoun Station industrial safety accident rate for the month of January 1997 was 0.00. The 12 month rolling average (Feb.1996 through Jan.1997) was 0.44. The year to date value was 0.44 at the end of January 1997.

There were no restricted-time and no lost-time accidents in January 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 January 1997, the FCS Value was 4.6 This compares to the end of the year value of 4.6.

Data Source:

Sorensen/Skaggs (Manager / Source)

Chase / Booth (Manager / Source)

Accountability:

Chase / Bishop 13

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

I e

14

1

+ Monthly Disabling injuryAliness Frequency

+ 12 Month Rolling Average

_1997 OPPD Goal 2.

1.8..

1.6.-

1.4..

1.2 L 1__

0.8..

0.6..

I 0.4

'N I

~I 2

I 0.2..

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

DISABLING IN]URY/ ILLNESS FREQUENCY RATE (LOST-TIME ACCIDENT RATE)

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

For the month of January 1997 the disabling injury / illness frequency rate was 0.00. For the 12 month period (Feb.1996 through Jan.1997) the disabling injury / illness rate was 0.44. There were no disabling injury / illness cases reported for January 1997.

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

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..

3.0..

2.5..

2.0 9

1.5

.......e.......e.......e.......e......e.......e.......e.......e.......e.......e.......e 1.0 4

Feb Mar Apr May Jun Jul Aug sep Oct Nov Dec Jan 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 January 1997 was 4.45.

The recordable injury / illness frequency rate for the past 12 months (Feb.1996 through Jan 1997) was 2.35.

During the month of January 1997, there were 2 recordable injuries.

1.

Worrker had a foreign body blown into his/her eye.

2.

Worker burned his/her hand on a hot pipe.

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

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

)

1.5.

Data Source:

Sorensen/Skaggs (Manager / Source)

Accountability:

Bishop Trend:

Needs Management Attention SEP 15,25,26 & 27 16 4

i gigg Contamination Events (Monthly)

_,_. Contamirwilon Events (YTD) 100..

l 90.

80 I

]

70 60..

50..

40 30._

l l

20 _

10._

i De 1

Jan Feb Mar Apr May Jun Jul Aug sep Oct Nov Dec CLEAN CONTROLLED AREA CONTAMINATIONS 21,000 DISINTEGRATIONS / MINUTE PER PROBE AREA This indicator shows the Personnel Contamination Events in the Clean Controlled Area for contaminations 11,000 disintegrations / minute per probe area for January 1997.

1 There were O contamination events in January 1997. There have been zero contamination events in 1997 through the end of January 1997.

4 Data Source:

Chase /Cartwright (Manager / Source)

Accountability:

Chase /Gebers Trend:

Needs Management Attention SEP 15 & 54 17

m PersonnelErrors(EschMonth)

+ Preventable (18-MonthTotals) e Personnel Error (18-Month Totals) 20._

15 _.

10 __

1 5 A

?=N;;

0 E<

,E E;

i Jul Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun Jul Aug sep Oct Nov Dec 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 December 1996, there were two events which were subsequently reported as LERs.

One LER was categorized as Preventable and no LERs were categorized as Personnel Error for the month of December. The total LERs for the year 1996 is sixteen. The total Personnel Error LERs for the year 1996 is seven. The total Preventable LERs for the year 1996 is nine.

The 1996 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)

Accountability:

Chase Trend:

Needs increased Management Attention SEP 15 18

i Startup m Shutdown m Operations

...o...

Industry Average Trend

-if

-.o...

.a......

,,,.a..

,,g......

,,g

,,,y,,,,

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.

4th Quarter 1993: 1) During surveillance testing, both PORVs for the LTOP system failed to open during multiple attempts. The failures were a result of differential expansion caused by a loop seal, excessive venting line back pressure, and cracked valve disks; 2) Calibration errors of the offsite power low signal relays could have prevented offsite power from tripping and the EDGs from starting in the required amount of time during a degraded voltage condition; 3) Both AFW pumps were inoperable when one was removed from service for testing and the control switch for the other pump's steam supply valve was out of the auto position;

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

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

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

There were co safety system failures in the 1st quarter of 1995.

Data Source:

Nuclear Regulatory Commission Accountability:

Chase Trend:

Positive 19

e Failures /20 Demands r-- ; Failures /50 Demands t

e Failures /100 Demands

--m-Trigger values /20 Demands Trigger Values /50 Demands

,_ Trigger Values 100 Demands 8.

7..

6__

5.

4__

3__

m 2 "2

"2

- - " ~ ~ ~ " ~ ~ "

~~ 1 1

1 11 11 1

1 1

1

" 0 0

0 0] 0] 000 0 og 0 CE " E

I '"E

"E Feb Mar Apr May Jun Jul Aug sep Oct Nov Dec Jan EMERGENCY DIESEL GENERATOR LINIT RELIABILITY This bar graph shows three monthly indicators pertaining to the number of failures that were reported during the last 20,50, and 100 emergency diesel generator demands at the Fort Calhoun Station. Also shown are trigger values which correspond to a high level of confidence that a unit's diesel generators have obtained a reliability of greater than or equal to 95% when the failure values are below the corresponding trigger values. The Fort Calhoun 1996 goal is to have fewer failures than these trigger values.

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

]

Data Source:

Phelps/Ronning (Manager / Source)

Accountability:

Phelps/Ronning Trend:

Positive due to performance better than goal.

20

i DG-1 Failures /25 Demands i

e DG-2 Failures /25 Demands 5.

-e-. M Goal 4_

3.

2 s

0 Feb Mar Apr May Jun Jul Aug sep Oct Nov Dec Jan 1996 DIESEL GENERATOR RELIABILITY (25 DEMANDS)

This indicator shows the number of failures experienced by each emergency diesel generator during the last 25 start demands and the last 25 load-run demands. A trigger value of 4 failures within the last 25 demands is also shown. This trigger value of 4 failures within 25 demands is the Fort Calhoun goal for 1997.

It must be emphasized that, in accordance with NUMARC criteria, certain actions will take place in the event that any one emergency diesel generator experiences 4 or more failures within the last 25 demands on the unit. These actions are described in the Definitions Section of this report.

Diesel Generator DG-1 has experienced zero failures during the last year, and zero failures during the last 25 demands on the unit. Diesel Generator DG-2 has experienced zero failures during the last 25 demands on the unit.

Data Source:

Phelps/Ronning (Manager / Source)

Accountability:

Phelps/Ronning Trend:

Positive due to performance better than goal.

21

m DG1 UnreliabilityValue i

DG-2 Unreliability Value

+ Station Unreliability Value 1997 Goal 0.07,.

0.06.

0.05 -- c 0.04.

0.03..

0.02.

0.01 _-

oo oo oo oo oo oo oo oo oo oo oo o

0

0 ;

Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan EMERGENCY DIESEL GENERATOR UNRELIABILITY The purpose of this indicator is to monitor the likelihood that emergency AC power generators will respond to off-normal events or accidents. It also provides an indication of the effectiveness of maintenance, operation, and test practices in controlling generator unreliability. The last event occured on September 1,1995 when the Field Flash Relay on DG-2 failed.

Emergency diesel generator unreliability is calculated as follows:

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

=

number of valid start demands LU = Load-run Unreliability = number of unsuccessfulload-runs number of valid load-run demands Station Value = average of DG-1 and DG-2 values The year-to-date station EDG unreliability at the end of January 1997 was 0.0. The 1997 goal for this indicatoris a maximum value of 0.05.

For DG-1:

There were 2 start demands in January 1997 with 0 failures.

In addition, there were 2 load-run demands without a failure.

For DG-2:

There was 1 start demand in January 1997 with 0 failures.

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

Data Source:

Phelps/Ronning (Manager / Source)

Accountability:

Phelps/Ronning Trend:

Positive due to performance better than goal.

22

l l

1 4

i m ControlRoom Deficiencies Mded r

ControlRoom Deficiencies Cc

'-21

=

e Cc.%11within Target Completion Date l

90 - -

+ Completionm ee

-- 100A%

70 --

--60A% g o

60 --

es.4s f

j i

-- 60A% y 50 -- 4 e.7 g

E j

g40 I

k o

ss.o

-- 40A%

.5 30 27 7

8'

0

-- 20D% Y O

OD%

j Jun Jul Aug Sep Oct Nov Dec Jan J

i i

NUMBER OF CONTROL ROOM EQUIPMENT DEFICIENCIES l

l This indicator measures the timeliness of closing Control Room Equipment D eficiencies (CRD).

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

to close > 90% of all CRDs within the Target Due Date.

i i

There were 34 Control Room Deficiencies completed during January 1997, and 24 were i

completed within the target completion date.

{

A Scheduling Coordinator has been assigned to track performance on a weekly basis and j

identify problem areas. Revisions have been made to the scheduling process to allow for more timely completion of CRDs.

I Due to a new tracking system initiated in July / August, data for August 1996 was not available.

i 1

i Data Source:

Chase /Cronin (Manager / Source)

Accountability:

Short/Faulhaber

)

Trend:

None 23 f

i t

i

_m r

I g Overdue c ai.Lesssu a e

+ Number of On-Une ControlRor.an Deficiencies (CRD)

""d '

30 --

2 25 __

20 __

15..

84 is 1

10 __

5--

Data N/A Data N/A 3

O i

j i

i l

1 Jun Jul Aug Sep Oct Nov Dec Jan i

Number of On-Une CRDs m Overdue c,,,, g,, o,,,,,,

+ Number of Outage Control Room Deficiencies 35..

30..

Note: Overdue iterrs are those older than 18 months 34 25 20 __

se se se 15.

I 10 s

5 Data N/A s

Data N/A l

Od --

Jun Jul Aug sep Oct Nov Dec Jan f

Number of Outage CRDs 4

NUMBER OF ON-LINE AND OUTAGE CONTROL ROOM DEFICIENCIES i

i This indicator shows the total number of On-Line and Outage Control Room Equipment 3

Deficiencies (CRD), and the number of overdue Control Room Deficiencies.

No data was available for the month of November.

No data was available for the month of August.

4 The 1997 Fort Calhoun goal for these indicators are less than 5 overdue outage and no overdue on-line Control Room Deficiencies.

Data for August was not available.

Data Source:

Chase /Cronin (Manager / Source)

Accountability:

Short/Faulhaber/ Herman Trend:

None 1

24

m Highest Monthly bdividual Exposure mR

,Y ear-to-date

+ Fort Calhoun Goal 1000 mR 1000 e

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 I

This indicator shows the highest exposure for an individual during January 1997.

For the month of January 1997, an individual accumulated 123 millirem, which was the highest individual exposure for the month.

For the year to date, an individual has accumulated a total of 123 millirem.

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

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

Data Source:

Chase /Cartwright (Manager / Source)

Accountability:

Chase /Gebers Trend:

None i

25

m FCS Cited Violations (Monthly) l FCS Non-Cited Violations (Monthly) r3 FCS Cited Violations (12-Month Average)

FCS Non-Cited Violations (12 Month Average)

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

{

w 20 15 _

~~

N_

=u

" W E

E E

5 i

o O

E E

O.-

C M

>h a

u 6

x e

x m

a o

e e

i f

M e

o e

8 A

1996 VIOLATION TREND This indicator illustrates a 12-month trend for Fort Calhoun Station Cited Violations, Non-Cited Violations and Cited Violations for the Top Quartile plants in Region IV.

Additionally, the Fort Calhoun Station Cited and Non-Cited Violations for the past 12 months will be illustrated monthly. The 12-month trend for the Region IV top quartile lags 2-3 months behind the Fort Calhoun Station trend. This lag is necessary to compile informa-tion on other Region IV plants.

The following inspections were completed during January 1997:

IER No.

Iine None N/A To date, OPPD has received no violations for inspections conducted in 1997.

Level lil Violations 0

LevelIV Violations 0

Non-Cited Violations

_Q Tok!

0 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 26

m NRC Significant Events Industry Average Trend l GOOD l 1

i 1

V 0.5 0

0 0

r r

y 92 93 94 t%1 95-2 95-3 95-4 96 1 96-2 96-3 96-4 l Year - Quarter INPO Significant Events (SEs)

[ GOOD l 4

3 2

2 1

1 V

25 0

0 1"

0 M

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

Performance Indicators for Operating NuclearPower ReaMors' 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 Quartee t 193:

inoperability of Power Range Nuclear instrumentation Safety Channel D.

2nd Quarte <.893:

Inadequate control of Switchyard activities.

3rd Quarter 1993:

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

l 1st Quarter 1994:

1)

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

i l

2)

Unplanned dilution of Boron concentration in the Reactor Coolant System.

1st Quarter 1996:

During pressunzer 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 frem INPO on the 1996 SEs as of August 1, 1996.

Data Source:

Nuclear Regulatory Commission & INPO Accountability:

Chase Trend:

Positive 27 l

l Missed STs Resulting in LERs i

3_

1 l

2 1._

)

l 1

\\

l 0

0 0

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

l 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 January 1997.

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

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

l l

l Data Source:

Monthly Operating Report & Plant Licensee Event Reports (LERs)

Accountability:

Chase /Phelps Trend :

Positive SEP 60 & 61 28

PERFORMANCE Goal:

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

9 29

i i

d i

l j

Net Generation (10,000 MWh) 40 __

M.55 M.84 M

33.85 34A3 30.08 30 _.

M inl -

2 Outa g e 20.-

9' 16.94 8

15.16 1996 RFO 9.746 0

i i

i 3

i i

i Feb Mar Apr May Jun Jul Aug sep Oct Nov Dec Jan STATION NET GENERATION During the month of January 1997, a net total of 351,391.9 MWh was generated by the Fort Calhoun Station. Cumulative net generation for Cycle 16 was 5,418,326.6 MWh.

Cumulative net generation for Cycle 17 was 705,505.9 MWh at the end of January 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 (2) condenser tube leakage repair.

Energy losses for December were attributed to a steam leak on the turbine control valves (MOV-CV).

Data Source:

Station Generation Report Accountability:

Chase Trend:

None 30

, Monthly Forced Outage Rate e _ Rolling 12 Month Averagn

+ 1997 Fort Calhoun Goal (1.4%)

50%..

45%..

40%..

35%..

30%..

25%.

20%..

l 15%..

10%..

5%..O T

e 4

0 0

0 O

A; 0%

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

FORCED OUTAGE RATE The forced outage rate (FOR) for the month of January 1997 was 0.00. The forced outage rate for the previous 12 months (Feb.1996 through Jan.1997) was 5.38%. The 1997 year-to-date FOR was 0.00% at the end of January 1997.

Energy Losses are explained on Page 30.

t l

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

1 s

9 Date Source:

Monthly Operating Report Accountability:

Chase i

Trend:

None 31 I

m MonthlyUrstCapacityFactor

...s... Year-to-Date Unit Capacity Factor x

UnitCapacityFactorforCycle 17 1997 FCS Goal (81.49%)

110%.-

100 %.

90% -- 85.20%

805.._

60*/. +

Cycle 17 50%.

o 40 %

30%._

)

j 20%__

l 10%.

0%

[

C-16 Feb Mar Apr May Jun Jul Aug Sep oct Nov Dec Jan 4

1 i

i i

UNIT CAPACITY FACTOR This indicator shows the plant monthly Unit Capacity Factor, the Unit Capacity Factor for the j

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 i

Cycle 16 Unit Capacity factor was 85.23%,.

J At the end of January 1997, the Cycle 17 Unit Capacity Factor was 66.85%. The Unit Capacity l

Factor for the last 36 months (Feb.1994 through Jan.1997) was 85.28%. The 1997 Fort Cal-l houn annual goal for this indicator is 82.00%.

The year-to-date value is 76.76%.

Data Source:

Monthly Operating Report 1

Accountability:

Chase Trend:

None 32

.~.

_-.._~

Monthly EAF i

i

_ e_ Year-to-Date Average Monthly EAF

+ 12 Month Rolling Average

+ OPPD Goal 100% _.

'f;0% 'sys 3

~

\\

4 T

k i

~

80% T nfs 60%.-

g,,,

40%__

20%__

1996 RFO

,R; 0%

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

)

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 January 1997 was 98.06%. The 12 month rolling average (Feb 1996 through Jan.1997) was 72.4%. The equivalent availability factor for the past three years (Feb.

1994 through Jan.1997) was 85.01%.

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

Data Source:

DietzNandervort (Manager / Source)

Accountability:

Chase Trend:

None 33

m Safety System Actuations (INPO Definition)

._ __ FCS Goal (0)

+ Industry Upper 10 Percentile (0) 3,.

i 2__

1__

0 0

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

1 I

l m Safety System Actuations (NRC Definition)

FCs Goal (0) i

+ CriticalHours 10 --

1996 RFo

. 800 m

__700 RFO s__

..600 I

s..

500 j

__400 $

_300

{*

..200 2..

__100 0 0 0 0 0

0 1

NDJ FMAM J JA SON D J FMAMJ JASONDJ UNPLANNED SAFETY SYSTEM ACTUATIONS -(NRC DEFINITION) l 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 i

35 i

m Gross Heat Rate

--M-- Year-to-Date Gross Heat Rate

-e-Fort Calhoun Goal 14.75 -

14.25 -

13.75 -

13.25 -

12.75 -

p 12.25 -

11.75 -

j

11.25 -

10.75 -

10.25 -- iom E

l 9.75 9.25 96 Feb Mar Apr May Jun Jul Aug Sep oct Nov Dec Jan l

GROSS HEAT RATE l

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 10,033 BTUlkWh for the month of January 1997. The 1997 year-to-date GHR was 10,033 BTU /kWh at the end of the month.

The GHR varies with fluctuations in river water temperature. In general, the GHR im-proves during the winter months and degrades during the summer. This is because the l

gross heat rate is not normalized to the design river water temperature of 60 degrees l

Fahrenheit.

The 1997 Fort Calhoun year-end goal for this indicator is 10,166 BTulkWh.

l Data Source:

Guinn/Willett (Manager / Source) l Accountability:

Chase /Skiles Trend:

None I

36 l

--+- Thermaloutput

-+- Fort Cahoun 1495 MW Goal

--*- Tech Spec 1500 MW Umit 1600 --

1400 --

1200 -

1000 -

800 -

I 600 -

400 --

200 --

0 l l l l l l l l l l l l l l l l l l l l l

l l l 1

3 5

7 9

11 13 15 17 19 21 23 25 27 29 31 i

1, 4

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

l Data Source:

Guinn/Willett(Manager / Source)

Accountability:

Chase /Short Trend:

None 37

~. _.

+ Monthly Equipment FOR Equipment FOR/1,000 Critical Hrs. (Rolling 12-Month interval)

Fort Calhoun Year-End Goals (0.2) 2.-

1.-

x E

2 0

Feb Mar Apr May Jun

[ul Aug sep oct Nov Dec Jan EQUIPMENT FORCED OUTAGES PER 1,000 CRITICAL HOURS The equipment forced outage rate per 1,000 critical hours for the 12 months from February 1,1996, through January 31,1997, was 0.286. The year-to-date rate per 1,000 criticel hours for the months from January 1,1997 through January 31,1997 was 0.286.

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 38

- - ~

+cmixxwtcmegne.

20

+

M 18 Cdsgmes 16.

~

f1.

V 10.

8.

y f

Nf E'

0 0

N D

J-N F

M A

M

]

A 0

N D

]

l Initial hs allation Testing Action Procedure Error 2%

2%

Maintenance Action l

21 %

Age / Normal use 56%

Other Devices 13%

Manufacturing Defect Engineering / Design 2%

2%

COMPONENT FAILURE ANALYSIS REPORT (CFAR)

SUMMARY

The top chart illustrates the number of component categories, application categories and total categories in which the Fort Calhoun Station has significantly higher (1.645 standard deviations) failure rates than the industry failure rates during the past 18-month Component Failure Analysis Report (CFAR) reporting period (from April 1995 through September 1996). Fort Calhoun Station reported a higher failure rate in 9 of the 83 component categories (valves, pumps, motors, etc.)

during the past 18-month CFAR period. The station reported a higher failure rate in 7 of the 174 application categories (main steam stop valves, auxiliary / emergency feedwater pumps, control element drive motors, etc.) during the past 18-month CFAR period.

The pie chart depicts the breakdown by INPO cause categories (see the " Definitions" section of this report for descriptions of these categories) for the 47 failure reports (failure discovery dates within the 18-month CFAR period) with known failure causes that were submitted to INPO by Fort Calhoun Station. A total of 70 failure reports were submitted to INPO with discovery dates within the 18-month CFAR period.

l l

Data Source:

Phelps/ Frank (Manager / Source) l Accountability:

Phelps/ Dowdy i

Trend:

None 39

m

+ Components with more than One Failure

Components with more than Two Failures 15.-

f 10 10 10 10..

g g

7 6

6 5

3 3

2 2'

1 1

1 I

O I Feb Mar Apr May Jun JtA Aug Sep Oct Nov Dec Jan 1

REPEAT FAILURES The Repeat Failures Indicator (formerly called the " Maintenance Effectiveness Performance Indicator") was l

developed in response to guidelines set forth by the Nuclear Regulatory Commission's Office for Analysis and Evaluation of Operational Data (NRC/AEOD). The NRC requirement for a Maintenance Effectiveness Performance Indicator has been discontinued, but station management considers it useful to continue to track repetitive component failures using the Nuclear Plant Reliability Data System (NPRDS).

This indicator shows the number of NPRDS reportable components with more than one failure during the 18-month Component Failure Analysis Report (CFAR) period (failure discovery dates from April 1995 through September 1996) and the number of NPRDS reportable components with more than two failures during the 18-month CFAR period.

During the last 18-month CFAR period, there were 9 NPRDS components with more than one failure. Three out of these 9 NPRDS reportable components had more than two failures. The description and tag numbers of the NPRDS reportable components with more than one failure are listed below-IA-HCV-2987-BP Air Intensifier for HPSI Pump SI-2C Discharge isolation Valve

=

(> 2 Failures)

RC-10-08 Control Element Drive Mechanism RC-3D-M Reactor Coolant Pump Motor V/P-402C Valve Positioner for Cont. Cooling Coil VA-BA CCW Outlet Valve

+

V/P-403C (> Two Failures)

Valve Positioner for Cont. Cooling Coil VA-8B CCW Outlet Valve

+

FW-56 (> Two Failares) Auxiliary Feedwater Pump FW-56 Diesel Engine

=

HCV-1106-0 Valve Operator for SG RC-2B Feed Regulation Bypass Valve YE-116A QSPDS Heated Junction Thermocouple Probe for Reactor Vessel RC-1 1B3B-4 AC-3A Circuit Breaker Data Source:

Phelps/ Frank (Manager / Source)

Accountability:

Chase Trend:

None 40

CHEMISTRY ACTION LEVELS EXCEEDED Event Days + Average Event Days : oPPD LimR 6.

6.

4.

y3.

E 2-

=

s g

~

0 I

k Y

Y D

I 8

k Y

s s

s 8

s a

s s

s M ONTH 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 1996 Fort Calhoun goal for this indicator is the 12-month average of two event days per month. There is no goal established for the number of event days per individual month.

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

There were no event days in January.

Data Source:

Chase / Spires Accountability:

Spires Trend:

None 41

.-.. - ~ _..

a% Hours out of Umit 12.00 -

+ N MM 10.00.

8.00.

6.00.

2 4m.

2.00.

Om r

n o

e m

6 6

r 3

y a

2 i

E R

8 8

8 4

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 January 1997.

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

l Data Source:

Chase / Spires (Manager / Source)

Accountability:

Spires Trend:

None 42

j i

I I

i

!j.

i COST 1

1 i

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

effectively maintains nuclear generation as an l

economically viable contribution to OPPD's bottom line.

j Cost consciousness is exhibited at all levels of the j

organization.

3*

4 43

--+-- Actual de-Revised Budget e-original Budget Plan 3.75 -

3.50 -

3.25 -

3.00 -

t o 2.75 2.50 2.25 -

2.00

4 y4 4 E'=*=**o ggggg

= a 8EaEE Months CENTS PER KILOWATT HOUR 1996 Year End Data The purpose of this indicator is to quantify the economical operation of Fort Calhoun Station.

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

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

The 12-month rolling average unit price (period of November,1995 through December, 1996) averaged above the budget due to 12-month rolling expenses exceeding the bud-get expectations, and the 12-month rolling generation not meeting the budget expecta-tions. The 12-month rolling average (12/95 through 12/96) 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 2.79 2.84 2.85 2.81 2.82 2.76 2.73 2.75 2.80 2.97 3.12 3.09 Actual Y-T-D 2.91 2.77 2.96 2.94 2.83 2.98 2.91 2.85 2.84 2.98 3.23 3.39 Data Source:

Lounsberry/ Dent (Manager / Source)

Accountability:

Lounsberry Trend:

Needs Management Attention 44

+ Spare Parts inventory Value ($ MiHion) 16.30.

16.10.

15.90.

l 15.70,

e 15.50 --

3 Ej 15.30 -_

i 15.10..

14.90.

14.70..

14.50 i

Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan 1096 SPARE PARTS INVENTORY The spare parts inventory value at the Fort Calhoun Station at the end of January 1997 was reported as $15,211,420.

Data Source:

Steele/Huliska (Manager / Source)

Accountability:

Willrett/McCorrnick Trend:

None 45

}

l l

l i

i l

DIVISION AND DEPARTMENT PERFORMANCE l

INDICATORS i

Goal: Achieve high standards at Fort Calhoun Station resulting in safe, reliable and cost effective power production.

i i

1 1

i f

46 4

l 1..

i e Corrective Maintenance m Preventive Maintenance m Non-Corrective /Plantimprovements Fort Calhoun Goal 1000_.

)

8M 870 780 830 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan 4

Non-Outage Maintenance Work Order Backlog i

Past Completion

)

compieted

.rm m 62 %

i IMOPRORTYER%KDCMN 38 %

400...I NC + -. '

M.

Th;[kN,103%(

j 77{

200.

0..__

" ' ~

~

Not Completed j

R uty Ruty Raty Rorty Ruty 1

2 3

4 5

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

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

Chase / Johnson (Manager / Source)

Accountability:

Chase /Faulhaber Trend:

Adverse SEP 36 47

j Ratio of Preventive to Total Maintenance 90%

i 80%1 70%

60%

50%..

40%

Data N/A 30%..

i 20% -

10%..

0%.

i i

4 --

i I

l j

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

- Fort Calhoun Goal J

3%

2.60 %

2% +

1.28 %

0.75%

1% - 0.60%

0.37% 0.40 %

0.39 % 0.39 %

0%

i i

Feb Mar Apr May Jun Jul Aug Sep Oct Nov 0.1g.

Jan c

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 were 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 48

i i

j m Rework as identified by Craft

_ _ Fort Calhoun Goal (<3%)

l

] 5% _.

4.s%

5 b

I N 4%

3.7%

b 3%

2-2 3

o

+

te%

ts%

l 3 1%.

o.s%

0.s%

0t%

n%

j i

i Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan e No. Wintenance terrs Corrpeted

+ % Identified as Fbpeat 700.

. 8.0%

600.

7.0%

g 500.

. 6.0%

400.

35 288 SM

. 4.0%

~

220 217 214 207

. 3.0%

200 n

, -, n ns Jan Feb Mar Apr May Jun Jul Aug sep Oct Nov Dec PERCENTAGE OF TOTAL MWOs COMPLETED PER MONTH IDENTIFIED AS REWORK / REPEAT 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 49

, Monthly Overtime (On-Une)

+ Y-T-D Monthly Average (On-Une)

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

8%..

7%._

6%..$

5%__

4%..

3%--

2%..

1%

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 6% for the month of January 1997.

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

Data Source:

Chase / Johnson (Manager / Source)

Accountability:

Chase /Faulhaber Trend:

None 50 i

i

. _ _. ~.

Human Performance CRs(Maintenance) l 20,.

I i

18 16._

14._

i g 12 __

i

?

0" 9

9 l

0 l

j 8.

6 6

I 6M i

Jul Aug Sep Oct Nov Dec Jan l

l 1

l l

PROCEDURAL NONCOMPLIANCE INCIDENTS i

(MAINTENANCE) i, 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 i

Trend:

None SEP 15,41 & 44 l

i

$j

,f 51 1

% pas 5OoS

% Non-PASS OoS

%TotalooS Total % OoS Goal 50%.

45%.

40%.

35%.

30%.

25%.

20%.

15%.

10%

^

5%.

^ ' ~ ~ _ ~ ~ ~ ~ ~

~

_m 8

8 8

8 e

k b

h h

b b

h h

b h

h 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 January 1997, the percentage of hours the in-line chemistry system instruments were inoperable was 2.46%. The following instrument was out of service for the entire month of January:

PHE-6775 CPD pH The entire instrument channel is considered inoperative if: 1) the insrumeet is inopera-tive, 2) the chart recorder associated with the instrument is inoperative, or 3) the alarm function associated with the instrument is inoperative. If any of the functions listed above are not operational, then the instrument is not performing its intended function.

~

Data Source:

Chase /Reneaud (Manager / Source)

Accountability:

Chase /Skiles Trend:

Positive - Better than OPPD Goal 52

m Wrto Produced Ea:h Month (Kilogram )

J

+ Fort Calhoun Monthly Average Goal (150 kilograms)

I Federal & state Monthly Limit (Max. of 1,000 kg) 1000 900__

l 800__

l 700..

600 __

E (500..

.e E

400 __

300.-

200

=

100-_

0 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan 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 January 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 53

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

10% --

9%.-

I111111ll Feb Mar Apr May Jun Jul Aug sep Oct Nov Dec Jan CONTAMINATED RADIATION CONTROLLED AREA This indicator shows the percentage of the Radiologically Controlled Area that is contami-nated based on the total square footage. The 1996 monthly non-outage goal is a maxi-mum of 10.0% contaminated RCA.

At the end of January 1997, the percentage of the total square footage of the RCA that was contaminated was 8.4%

Data Source:

Chase / Williams (Manager / Source)

Accountability:

Chase /Gebers Trend:

None SEP 54

1 l

Poor Radiation Worker Practices Fort Calhoun Goal (<125) 16 14.

12.

10.

8.

6.

4.

2.

0 0:

Jan Feb Mar Apr May June July Aug sep Oct Nov Dec RADIOLOGICAL WORK PRACTICES PROGRAM i

The Radiological Work Practices Program Indicator shows the number of Poor Radiologi-cal Work Practices (PRWPs) which were identified during the reporting month.

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

During the month of January 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 55

O Documents Scheduled for Review g Documents Reviewed g Documents Overdue 400..

~

350 __

l l

i

)f 300..

il, i

4 250__

200..

150 100,.

50 _.

0 E+ _

E+. _

E+ _ b

+

l

+

+-

+_

y Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan 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 doctiments reviews are performed in-house and include Special Proce-dures, the Site Security Plan, Maintenance Procedures, Preventive Maintenance Proce-dures, and the Operating Manual.

i During January 1997, there were 358 document reviews scheduled, while 51 reviews i

were completed. At the end of the month, there were 39 document reviews more than 6 months overdue. There were 0 new documents initiated during January 1997.

Data Source:

Chase /Plath Accountability:

Chase /Skiles Trend:

None SEP 46 56

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

_~... _ _.

1 1

g System Failures a Non-System Failures 33 25 --

2s 22 22 j.

2o -..

y f

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

}

l LOGGABLE/ REPORTABLE INCIDENTS (SECURITY) i j

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-l tion, Security Force Error, and Unsecured Doors.

l During the month of January 1997, there were 30 loggable/ reportable incidents identi-i fied. Overall for 1997, there has been 30 loggable/ reportable incidents identified.

)

l System failures in January 1997, accounted for 90% of the loggable/ reportable incidents, j-17 (63%) of which were environmental failures. Non-system failures consisted of three l

lost / unattended security badges.

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

l l

Data Source:

Sefick/Woerner (Manager / Source) i Accountability:

Sefick j

Trend:

None SEP 58 i

I 57 4

4

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

+ Fort Calhoun Goals for >1-cycle and >6 months old 3.5 I 3

3 3--

2.5 __

2_-

1.5 __

1__

o o

oo oo o,o o,o o

oo oo o

A 5

8 5

a 8

e 8

A a

i 2

.l TEMPORARY MODIFICATIONS i

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 i

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 January 1997, there were 3 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 January 1997, there was a total of 16 TMs installed in the Fort Calhoun Station. Six (6) of the 16 installed TMs require an outage for removal and 10 are removable on-line. In 1997, a total of 5 temporary modifications have been installed.

TM 96-018 Equipment Drain Header Soft Rubber Patch TM 96-022 Containment Low Flow Purge

~

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 58

~.

I

, Total Modification Packages Open i

l

_ _ FortCalhounYear-EndGoal(68) 75 74..

l 73.

72..

71 --

H::-

l p

=

66 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 orooosed to be cancelled).

Reporting Cateaorv

'9.3

'94 15

'9fi 2Z E

Month Form FC-1133 Backlog /In Progress 0

0 0

0 4

0 0

Mod. Requests Being Reviewed 0

0 0

Design Engr. Backlog /In Progress 0

0 0

0 4

16 20 Construction Backlog /in Progress 4

1 8

5 1

2 21 Design Engr. Update Backlog /In Progress _1

_1

_A

_21

_Q

_2R Totals 5

2 14 26 9

18 74 (Outage + Onune)

(3+2)

(0+2) (6+8) (17+9) (0+9) (17+1)

(43+31)

At the end of January 1997,4 modification requests have been issued this year and 0 modification requests have been cancelled. The Nuclear Projects Review Committee (NPRC) has conducted 0 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.

I i

Data Source:

Jaworski/ Walling (Manager / Source) i Lounsberry/Belek (Manager / Source)

Accountability:

Scofield/Jaworski Trend:

None 59

)

4 40 --

EARS Requiring Engineering Closeout - Not in Closeout 32 32

)

30 -

20 m SE D DEN l

20 --

~

13 13 12 13 1

1 1

i 10 --3 4

~

4 4

~

,E 0

j Nov Dec Jan Nov Dec Jan Nov Dec tan Nov Dec Jan O.3 Months 3 6 Months 6-12 Months

>12 Monthe l

O Engineering Response E Closecut(SE) 3,..

t 19

{

20 --

8 7

12 4 3 10 -

2 i

0 1

,3 q0 l

0 0 j

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

SIE AR s a game dogAne 40 R equiring Rosetoed ee O ve rdue R oope nse m ed le s e na d os.

Reposees closeest 43.4%

40.4 %

NO ci.se e sie W.2%

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 7

EARS closed during the month 12 Total EARS open at the end of the month 96 Data Source:

Jaworski/Livingston (Manager / Source)

Accountability:

Phelps/Jaworski Trend:

None SEP 62 60

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

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

l f

1 i

l l

78 44 gg CLOS EOUT DEN C

T.

8 l

ECN Status - Overall Backlog 36 9

g Backlogged O Received E Completed

E,*,*

' 5 * "

250.

I 150.. tzs n

u oi o,

f si l Aug Sep Oct Nov Dec Jan l

l Design Engineering i

3-6

250, l

03 Months j

200.

Months 17 %

I 150.

9%

>6 100..,

7.

n rs 74 %

l Aug Sep Oct Nov Dec Jan System Engineering 300 ue o.s u...

3,,,

250 3.. g...

2+ 4 I,

e ::

is is so 4 ::

Jul Aug Sep Oct 2v Dec i

l Procurement / Construction 250.

g

200, Wnths 150 72%

[

0- 3 T

Wnths 100J.8' 77

,M 6.8%

i Aug Sep Oct 2v Dec Jan Drafting / Closeout ENGINEERING CHANGE NOTICE STATUS l

Data Source:

Jaworski/Livingston (Manager / Source) l Accountability:

Jaworski/Phelps j

Trend:

None SEP 62 1

i 61 i

i i

i

344 99 Pd fy 302 305

' "' N" Total Open ECNs = 513 P rl* d*

5 TM @m Eh = m O DEN-Clos eout or Drafdus bt Congdete 19 25 5 Mainsenance/Construcsion/Psocweenent MrkhtCongdece P do rity P rio rity B 5yteen Engineering Response,Connnuedon Not Congdese 5as6 let2 M

N E DEN.EngineedagNotCongdete P ri i

3 Aug-96 Sep 96 No Dec 96 jan-97 7

N 2M 296 2M M

P riority P rio dty 42 38 M

II O

Sag ist!

2E.

r7%

10 %

fn W e

J

.Y" A

Aug 96 Sep.96 Oct-96 Ptw 96 rbc416.brWIT OM P ri ley 3ae4 78 47 yo,

de 60.

e s

f P ri*d'Y P dry 3,j 50.

s M.

y e

e 20.

I

( __

s

=

6 Aug Sep Oct Ptw Dec Jan r rity 5

oxteneruzunge s:mopen

,,j ENGINEERING CHANGE NOTICES OPEN Data Source:

Jaworski/Livingston (Manager Source)

Accountability:

Phelps/Jaworski Trend:

None SEP 62 62

O Administrative Control Problem E Licensed Operator Error E Other Personnel Error g Maintenance Problem O Desigenstructionlinstallation/ Fabrication Problem g Misc.

3..

2..

1..

0 Jan Feb Mar Apr May Jun Jul Aug sep Oct Nov Dec 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 January 1,1996, through December 31,1996. To be consistent with the Preventable / Personnel Error LERs indicator, this indicator is reported by the LER event date, as opposed to the LER report date.

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

There were two events in December 1996 that resulted in LERs.

Data Source:

Tills /Cavanaugh (Manager / Source)

Accountability:

Chase Trend:

None 63

O Total Requalification Training Hours g simulator Training Hours a Non-Requalification Training Hours g Number of Exam Failures 35 ~~

34 34 32 32.5 32 30 _-

25 __

~

22 7

16

.5 4

15 __

14 4

2 12 0__

.5

.5 8

8 8

5 3

5 4

5__

3 1

1 1k 0__

i i

i i_

Cycle Cycle Cycle Cycle Cycle Cycle Cycle Cycle Cycle 95-3 95-4 95-5 95-6 96-1 96 2 96-3 96-5 96 7

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

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

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

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

~

Data Source:

Conner /Guliani(Manager / Source)

Accountability:

Conner /Guliani Trend:

None SEP 68 64

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

4 P

4 d

i 0000 0

Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec LICENSE CANDIDATE EXAMS - 1997 This indicator shows the number of Senior Reactor Operator (SRO) and Reactor Operator I

(RO) quizzes and exams taken and passed each month. These internally administered quizzes and exams are used to plot the SRO and RO candidates' monthly progress.

~

During the month of January 1997, there were O RO and 0 SRO exams given.

I Data Source:

Conner /Guliani(Manager / Source)

Accountability:

Conner /Guliani Trend:

None SEP 68 65 1

m Ready to Close a Oosed

+ Total CRs 2500 2000 1500.

1000.

o e

500.

0 4

}

{

! (

8

?

i s

s 8

8

^

s i

a a

8

.7 a

8 8

8 5

=

~

CONDITION REPORTS BY LEVEL 1

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 Total Open 23 11 96 845 41 21 1047 Closed 10 3

73 651 336 97 1170 293 Condition Report's are classified as READY to CLOSE.

At the end of January 1997, there were 42 "OPEN" incident Reports, of which,14 were Significant.

As of September 21,1995, incident Reports were no longer issued.

Data Source:

Tesar/Burggraf(Manager / Source)

Accountability:

Andrews/Gambhir/Patterson Trend :

None 66

O TotaloutaphMOs MWO HOLDS

, mqm 1200-Ranner System 29%

bgneering 5%

1000.

23 %

800.

r4 REVEW

~

25%

E04s 18%

m.

47s 200.

O j

i 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 67

i 1

NO NEW DATA 1

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

f Data Source:

Phelps/Swearngin (Manager / Source)

Accountability:

Phelps/Boughter j

Trend:

None SEP 31

{

68

1

, ActualFHCDate e Target FNCDate 9 28/97 ar2997 8

m e

e a

e e

a e

e a

e 7/30/97.

6/3097 5/31/97.

5/1/97.

4/1/97.

E97.

1/31/97.

1/1/97 m

e m

e e

n n

n a

o e

n n

a b

b

$ hh8 E

E b

U b

8 8

8 m

a m

o a

a m

m 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.

January 1996 Modifications added: 0 Deleted = 0 Data Source:

Jaworski/ Walling (Manager / Source)

Accountability:

Gambhir/Jaworski Trend:

None SEP 31 69 A

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.

January 1997 Modifications Added: 0 Deleted = 0 Modifications Pre-Approved: 0 Data Source:

Jaworski/ Walling (Manager / Source)

Accountability:

Gambhir/Jaworski Trend:

None SEP 31 f

70

, Actual PRC rhte a Target FRc Date 6/30/97.

5/31/97.

8 5/1/97.

4/1/97.

3/2/97.

1/31/97.

1/1/97 95012 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.

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

Jaworski/ Walling (Manager / Source)

Accountability:

Gambhir/Jaworski Trend:

None SEP 33 71

p.

G ACTION PLANS 6

72

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

in accordance with Revision 3 of NOD-OP-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 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.

e 73 l

Chemistry Department Drte:

Scotember 17.1996 CARBOHYDRAZIDE & ALTERNATE AMINE IMPLEMENTATION ACTION PLAN (IRON & COPPER TRANSPORT REDUCTION) l A.

PROBLEM STATEMENT 1.

Program changes are required to allow trial use of carbohydrazide as a hydrazine replacement.

2.

Iron and copper corrosion increases steam generator corrosion rates and increases plant expenditures.

l B.

GOALS 1.

Provide a detailed plan and documentation of programmatic changes required for carbohydrazide use.

2.

Systematically evaluate attemate amines to reduce iron and copper transport rates and reduce related plant operating costs.

LEAD DUE C.

ACTION (S) REOUIRED TO ACCOMPLISil GOALS RESPONSIBILITY DATE COMMENTS 1.

Perform an evaluation of hydrazine replacements Evaluation, PRC and (carbohydrazide). Present results of evaluation to Complete soIC presentations-p$v'ed PRC and S/G Integrity Committee.

Chemical Services 09-13-96 soIC ror wet lay-up ops only 2.

Perform an environmental (NPDES) Impact evaluation for carbohydrazide. Submit results to Environmental Affairs for transmittal and approval Submitted to Env.

from the State of Nebraska Department of Complete AfTairs and NDEQ-Environmental Quality.

Chemical Services 10-01-96 Awaiting approval 3.

Prepare Material Specifications, Material Purchase Complete see memo Plan, and Chemicai Permit for carbohydrazide.

Chemical Services 07-29-96 FC-C-152-96 R1,01-08-97

Chemistry Department Dat$:

September 17.1996 CARBOHYDRAZIDE & ALTERNATE AMINE IMPLEMENTATION ACTION PLAN (IRON & COPPER TRANSPORT REDUCTION)

LEAD DUE C.

ACTION (S) REOUIRED TO ACCOMPLISII GOALS RESPONSIBILITY DATE COMMENTS 4.

Prepam implementation plan for carbohydrazide trial Complete use.

Chemical Services 10-01-96 5.

Prepare new procedures for sampling and analysis of carbohydrazide.

Chemical Services 03-01-97 l

6.

Prepare procedure changes required to allow utilization ofcarbohydrazide (including CII-AD-0003 Complete wet Lay-up limits).

Chemical Services 10-01-96 applications only 7.

Evaluate carbohydrazide impact on Control Room System Engineering Complete EAR 96-11I has been habitability.

DEN 09-19-96 submitted 8.

Purchase carbohydrazide for trial study.

Chemical Services 06-01-97 9.

Perform iron and copper transport studies prior to implementation ofcarbohydrazide trial. This includes perfonning Mossbauer Spectroscopy.

Chemical Services 10-01-97 i

l 10.

Perform iron and copper transport studies following the implementation of carbohydrazide use. This g

includes perfomling Mossbauer Spectroscopy.

Chemical Services 07-01-98 11.

Evaluate continued use of carbohydrazide for Wet l

Layup and power operation applications.

Chemical Services 09-01-98 R1,01-08-97

Chemistry Department Date:

Seotember 17.1996 CARBOHYDRAZIDE & ALTERNATE AMINE IMPLEMENTATION ACTION PLAN (IRON & COPPER TRANSPORT REDUCTION)

LEAD DUE C.

ACTION (S) REOUIRED TO ACCOMPLISIl GOALS RESPONSIBILITY DATE COMMENTS l

12.

IfItem i 1 is favorable, implement permanent program changes to use carbohydrazide. Othenvise return to hydrazine use and remove carbohydrazide program changes.

Chemical Services Il-01-98 l

13.

Re-evaluate use of carbohydrazide for use in secondary system on-line.

Chemical Services 05-01-97 l

14.

Perform evaluation of carbohydrazide use in primary systems.

Chemical Services 03-01-97 15.

Based on Item 14 results, implement program changes necessary to use carbohydrazide in primary systems.

Chemical Services 05-01-97 16.

Evaluate attemate amines or chemical additives to minimize iron and copper transport (corrosion) to steam generators.

Chemical Services 09-Cl-97 17.

Based on Item 16, implement procedure / program changes to allow injection of attemate amines.

Chemical Services 07-01-98 18.

Evaluate movement of the chemical feed injection point for the condensate system from the steam parking exhauster to the shell side of FW-13A and System Engineering EAR 96-109 has FW-13B.

DEN 03-01-97 been submitted 19.

Based on Item 18, install modifications to move the Sys Eng/ DEN chemical injection point.

Construction Mgmt 07-01-98 RI,01-08-97

~

Chemistry Department kte:

May 13.1996 -

CONDENSATE DISSOLVED OXYGEN (AIR LEAKAGE) ACTION PLAN A.

PROBLEM STATEMENT 1.

Elevated levels of dissolved oxygen have been identified in the condensate pump discharge by both grab sample analysis and installed in-line instrumentation.

2.

The elevated levels of dissolved oxygen in condensate are in excess of the INPO industry median value resulting in a high Chemistry Performance Indicator. Excessive dissolved oxygen in the condensate system has the potential to increase secondary plant corrosion rates and increase the iron transport to the steam generators.

B.

GOALS 1.

Identify all sources of dissolved oxygen (air) ingress and actively pursue corrective actions to eliminate / minimize these sources.

2.

Determine the optimum levels of dissolved oxygen to be maintained to ensure enough oxygen is available to passivate the secondary plant components while minimizing secondary system corrosion and iron transport rates.

LEAD DUE C.

ACTION (S) REOUIRED TO ACCOMPLISH GOALS RESPONSIBILITY DATE COMMENTS 1.

Rotate the condensate pumps to determine the optimum operating configuration to minimize the ingress of dissolved oxygen while the sources are The optimum operating mode is to keep B" being determined. This includes the utilization of Complete condensate pump in helium leak detection equipment.

Chem / Ops 05-18-96 operation.

2.

Perform system walkdown to ensure system is properly lined up for the condensate pump seal water Complete supply.

Ops 05-24-96 complete R8,01-31-97

Chemistry Department Dite:

May 13.1996 CONDENSATE DISSOLVED OXYGEN (AIR LEAKAGE) ACTION PLAN LEAD DUE l

C.

ACTION (S) REOUIRED TO ACCOMPLISH GOALS RESPONSIBILITY DATE COMMENTS Additionalleak testing completed after % RFO; 3.

Perform helium leakage testing per PMO WP002949 Complete Additional testing to be and procedure SE-PM-CD-0300.

Chem /Maint 05-31-96 done on as-needed basis.

4.

Perform required corrective actions to Identified valves; MWR's eliminate / minimize the leaks identified in Item 3 (on-Complete 9602199,9602200,and line maintenance items).

Maint/Sys Eng 07-31-96

%02502 are complete 5.

Perform required corrective actions to eliminate / minimize the leaks identified in item 3 Complete MWR's 960l%5 and (outage maintenance items).

Maint/Sys Eng 11-31-96

%02t98 are complete 6.

Install temporary Electro-Chemical Potential monitors in the condensate and feedwater systems to determine initial meeting w/

l the optimum dissolved oxygen and hydrazine NALCO Chemical Co.-

concentrations in the condensate system. This will COMPLETE. Due to ensure the system is properly passivated and minimize high E

tudy not 9e 9,,

p i

system corrosion and iron transport to the steam Chem /Sys Eng troscopy to be done in generators. (Evaluation complete)

Maint 10-01-97 its place.

7.

Evaluate the replacement of hydrazine with an Initial eval.-Complete alternate oxygen scavenging chemical to reduce Presented to PRC-8/96, condensate dissolved oxygen levels and minimize

[,8

~

iuated l'or personnel exposure to hazardous chemicals.

Chem 05-01-97 on_i;neuse, l

R8,01-31-97

Chemistry Department fhte:

May 13.1996 CONDENSATE DISSOLVED OXYGEN (AIR LEAKAGE) ACTION PLAN LEAD DUE C.

ACTION (S) REOUIRED TO ACCOMPLlSH GOALS RESPONSIBILITY DATE COMMENTS 8.

Based on Item 7 (if conclusions are favorable),

reinstall temporary Electro-Chemical Potential monitors in the condensate and feedwater systems to determine the optimum dissolved oxygen and the Initial meeting wt alternate oxygen scavenger concentrations in the NALCO Chemical Co.-

condensate system. This ) vill ensure the system is C

hi m

properly passivated and mimmtze system corrosion done: Mossbauer spec-and iron transport to the steam generators.

Chem /Sys Eng troscopy to be done in (Evaluation complete)

Maint 07-01-98 its place.

9.

Evaluate alternate seal designs for condensate and feedwater pumps or other modifications to minimize the ingress of dissolved oxygen (air)- into the EAR 96 079 to eval.

condensate system.

Sys Eng 04-15-97 pump seal design 10.

Based on Item 9, install modifications to minimize the ingress of dissolved oxygen (air) into the condensate Sys Eng/ DEN system.

Const Mgmt 09-30-97 11.

Repair condensate evacuation pumps (FW-8 A,8B,8C) to increase condenser efficiency.

Sys Eng/Maint 05-01-97 MWD 970221 (FW-8C)

EAR 96-075 written to evaluate condenser 12.

Evaluate optimum condenser efliciency.

Sys Eng 04-15-97 emciency.

13.

Implement temporary chemical feed injection point change from the Steam Packing Exhauster to the shell Sys Eng/Maint side of FW-13A and FW-13B.

Chem 04-01-97 R8,01-31-97

Chemistry Department Date:

May 13.1996 CONDENSATE DISSOLVED OXYGEN (AIR LEAKAGE) ACTION PLAN LEAD DUE C.

ACTION (S) REOUIRED TO ACCOMPLISH GOALS RESPONSIBILITY DATE COMMENTS 14.

Based on item 13, install permanent modification to Sys Eng/ DEN move the chemical injection point.

Const Mgmt 07-01-98 15.

Evaluated / Implement direct injection ofNitrogen into the condenser hotwell above the water line, possibly Sys Eng/Maint into the make-up water to reduce entrained oxygen.

Chem 05-01-97 16.

Evaluate installation of a Nitrogen sparge rig into the condensate storage tank to reduce entrained oxygen in the make-up water.

Sys Eng 07-01-97 17.

Based on Item 16, install permanent modification to install a Nitrogen sparge rig in the condensate storage Sys Eng/ DEN tank.

Const Mgmt 07-01-98 R8,01-31-97

Chemistry Department Date:

Sentember 17.1996 CONDENSATE COPPER & LEAD REDUCTION ACTION PLAN A.

PROBLEM STATEMENT 1.

Elevated levels of copper and lead contained in Feedwater and Steam Generator Systems can lead to increased corrosion rates.

B.

GOALS 1.

Identify all sources of copper and lead, and actively pursue correction actions to eliminate / minimize these sources.

LEAD DUE C.

ACTION (S) REOUIRED TO ACCOMPLISH GOALS RESPONSIBILITY DATE COMMENTS 1.

Evaluate the feasibility of repiacing copper containing components contained in condensate, feedwater, and System Engineering EAR 96-082 has support systems.

DEN 03-01-97 been submitted 2.

Based on Item 1, install modifications to remove Sys Eng/ DEN copper components from these systems.

Construction Mgmt 07-01-98 3.

Evaluate the compatibility of using brass / bronze System Engineering EAR 96-083 has (copper materials) in systems which contain DEN 03-01-97 been submitted ammonia.

4.

Based on item 3, install modifications to remove brass / bronze materials from systems containing Sys Eng/ DEN ammonia.

Construction Mgmt 07-01-98 5.

Identify components / materials in the condensate, feedwater, and support systems which contain lead.

Evaluate the feasibility of replacing the lead containing components / materials contained in these System Engineering EAR 96-il0 has systems.

DEN 03-01-97 been submitted R0,09-17-%

(

Chemistry Dcpartment Date:

September 17.1996 CONDENSATE COPPER & LEAD REDUCTION ACTION PLAN LEAD DUE C.

ACTION (S) REOUIRED TO ACCOMPLISH GOALS RESPONSIBILITY DATE COMMENTS 6.

Based on Item 5, install modifications to remove lead Sys Eng/ DEN containing components / materials from these systems.

Construction Mgmt 07-01-98 7.

Evaluate altemate amines or chemical additives to minimize iron, copper, and lead transport (corrosion) to the steam generators.

Chemical Services 09-01-97 8.

Based on item 7, implements procedures / program changes to allow injection of alternate amines.

Chemical Services 07-01-98 9.

Evaluate movement of the chemical feed injection point for the condensate system from the steam parking exhauster to the shell side of FW-13A and System Engineering EAR 96-109 has FW-13B.

DEN 03-01-97 been submitted 10.

Based on Item 9, install modifications to move the Sys Eng/ DEN chemical injection point.

Construction Mgmt 07-01-98 R0,09-17-%

t PERFORMANCE INDICATOR DEFINITIONS AUXILIARY FEEDWATER SYSTEM SAFETY SYSTEM CLEAN CONTROLLED AREA CONTAMINATIONS 11,000 PERFORMANCE DISINTEGRATIONS / MINUTE PER PROBE AREA The sum of the known (planned and unplanned) unavailable The personnel contamination events in the clean controlled hours and the estrnated unavailable hours for the auxiliary area. This indicator tracks personnel performance for SEP feedwater system for the reporting period divded by the entical

15 & 54.

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

CONTAMINATED RADIATION CONTROLLED AREA

)

COLLECTIVE RADIATION EXPOSURE The percentage of the Radiation Controlled Area, which incluoes the auxiliary building, the radwaste building, and Collective radiation exposure is the total extemal whole-body areas of the C/RP building, that is contaminated based on the i

dose received by all on-site personnel (including contractors total square footage. This indicator tracks performance for and visitors) during a time penod, as measured by the SEP #54.

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

i This indicator shows the daily core thermal output as COMPONENT FAILURE ANALYSIS REPORT (CFAR) measured from computer point XC105 (in themal megawatts).

SUMMARY

The 1500 MW Tech Spec limit, and the unmet portion of the 1495 MW FCS daily goal for the reporting month are also The summary of INPO categories for Fort Calhoun Station with shown.

significantly higher (1.645 standard deviations) failure rates than the rest of the industry for an eighteerHnonth time period.

DIESEL GENERATOR RELIABILITY (25 Demands)

Failures are reported as component (i.e., pumps, motors. main steam stop valves, control element motors, etc.) categories.

This indicator shows the number of failures occumng for each i

emergency diesel generator during the last 25 start dernands Failure Cause Categories 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-kfe, 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 system.

days eway from work per 200,000 man-hours worked (100 man-years). This does not include contractor personnel. This Engineering / Design - a failure attnbutable to the indicator tracks personnel performance for SEP #25, 26 & 27, inadequate design of the responsible component or system.

DOCUMENT REVIEW (BIENNIAL)

Other Devices - a failure attributable to a failure or 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 l

review, and the number of document reviews that are overdue Maintenance / Action - resulting from improper for the reporting month. A document review is considered maintenance, lack of maintenance, or personnel errors that overdue if the review is not complete within six months of the occur during maintenance activiteson the component.,

assigned due date. This indicator tracks performance for SEP

46.

Testing Action resulting from improper testing or personnel errors that occur dunng testing at,tivities.

EMERGENCY AC POWER SYSTEM SAFETY SYSTEM PERFORMANCE initial installation Error caused by improper initial installation of equipment The sum of the known (planned and unplanned) unavailable 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 period muftiplied by the number of 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 everage for the current year. The basis for the budget curve is the approved yearty This indcator shows the number of failures that were reported dunng the budget. The basis for the actual curve is the Financial and last 20, 50, and 100 emergency diesel generator dernands at the Fort Operating Report.

Calhoun Station. Also shown are tngger values which correlate to a high level of conridence that a unit's diesel generators have obtained a 83

PERFORMANCE lNDICATOR DEFINITIONS rehability of greater than or equal to 95% when the demand failures are Each emergency generator failure that results in the generator less than the ingger 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 j

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.

i whether by automatic or manual initiation. A start-only 1

comand 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, unreliabikty is the ratio of l

emergency generator system that prevents tile 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 start classified as a valid start failure. This includes any unreliabihty and load-run unreliability.

condition identified in the course of maintenance inspedions (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 number of EARS assigned to Design Engineering demand to be counted, the load-run attempt must meet Nuclear and System Engineenng. This indicator tracks one or more of the following criteria:

performance 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 awalting 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 indcator breaks down the number of Engineering 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 Facihty Changes open, ECN emergency generator does not pick up load and run as Substitute Replacement items open, and ECN Document predicted. Failures are counted dunng any valid load-run Changes open. This indicator tracks performance for SEP demands.

62.

1

5) Exceptions: Unsuccessful attempts to start or load-run EQUIPMENT FORCED OUTAGES PER 1,000 CRITICAL should not be counted as vahd demands or failures when HOURS they can be attributed 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 rnean time is equal to the number of hours the reactor is entical 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 termination of a test because of EQUIVALENT AVAILABILITY FACTOR abnormal conditions that would not have resutted in major diesel generator damage or repair.

This indicator is defined as the ratio of gross available l

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 operated 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.

84

PERFORMANCE INDICATOR DEFINITIONS FORCED OUTAGE RATE

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

the accident);

I This indicator is defined as the perantage of time that the unit

2) One or more days away from work (excluding the day of was unavailable due to forced events compared to the time the accident); and planned for electncal generation. Forced events are failures

3) Fatalities.

or other unplanned conditions that require removing the unit from service before the end of the next weekend. Forced Contractor personnel are not included for this indicator.

events include start-up failures and events initiated while the unit is in reserve stutdown (i.e., the unit is available but not in IN-LINE CHEMISTRY INSTRUMENTS OUT OF SERVICE service).

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

This indicator is defined as the steady-state primary coolant l-131 edivity, corrected for the tramp uranium contribution and LICENSE CANDIDATE EXAMS normalized to a common punfication 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 1

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 collect 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 j

state power above 85% should collect data for this indicator at each cycle. Also provided are the simulator training hours i

the highest steady-state power level attained during the month.

(which are a subset of the total training hours), the number of non-REQUALIFICATION training hours and the number of The density correction factor is the ratio of the specific volume exam failures. This indicator tracks training performance for of coolant at the RCS operating temperature (540 degrees F.,

SEP # 68.

Vf = 0.02146) divided by the specific volume of coolant at i

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 electncal energy produced by the generator in activities (i.e., poor planning, breakdown or lack of kilowatt-hours (KWH).

adequate management or supervisory control, incorrect ptocedures, etc).

HAZARDOUS WASTE PRODUCED 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 activities.

The sum of the known (planned and unplanned) unavailable

4) Maintenance Problem The intent of this cause code is hours and the estimated unavailable hours for the high to capture the full range of problems which can be i

pressure safety injection system for the reporting period attributed in any way to programmatic deficiencies in the divided by the critical hours for the reporting period multipled maintenance functional organization. Activities included by the number of trains in the high pressure safety injection in this category are maintenance, testing, surveillance,

system, calibration and radiation protection.

f INDUSTRIAL SAFETY ACCIDENT RATE -lNPO

5) Design /Constructionlinstallation/ Fabrication Problem

- This cause code covers a full range of programmatic j

This indicator is defined as the number of accidents per deficiencies in the areas of design, construction, 200.000 man-hours worked for all utihty personnel permanentty installation, and fabncation (i e., loss of control power due 4

assigned to the station that result in any of the following:

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

4 85

\\

l PERFORMANCE INDICATOR DEFINITIONS

6) Equipment Failures (Electronic Piece-Parts or MAXIMUM INDMDUAL RADIATION EXPOSURE Environmental-Related Failures)-This mde 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 hghtning, ice, high individual person working at FCS on a monthly, quarterty, and winds, etc. Generally, it includes spurious or one-time annual basis.

failures. Electric components included in this category are circuit cards, recbrers, bistables, 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 security 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 field 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 amved) 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 identified 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 Maintenance 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 capabilities from the Control Room, provides components that have failed or are malfunctioning and are automatic actions from or to the Control 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 Attemate 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 control room level indicator 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 significantly degrade station

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

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

3) Special schons are required by an Operator because of equipment design problems. These acbons may be Operations Concern - Equipment deficiencies which hinder desenbed in Operations Memorandums, Operator Notes, station operation.

or may require changes to Operaung 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 stat >on systems and equipment.

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

Plant Improvement - Non-corrective maintenance and plant improvements.

This indicator tracks maintenance performance for SEP #36.

86

PERFORMANCE INDICATOR DEFINITIONS NUMBER OF MISSED SURVEILLANCE TESTS RESULTING This indicator 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 rese't in Licensee PERCENTAGE OF TOTAL MWOs COMPLETED PER Event Reports (LERs) during the 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 identrfied by maintenance planning and craft. Rework is: Any additional work required i

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

,)e months old and the number of open significant irs.

subsequent Post Maintenance Test.

OUTSTANDING MODIFICATIONS PERCENT 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 mainter:ance completion of the drawing update.

activities as compared to the number of scheduled maintenana 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 activities. This indicator tracks Maintenance performance for

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

includes:

PERFORMANCE INDICATOR INDEX A) Modrfication 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 indicator values, which include the Nuclear Projects Review Committee (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).

Reliability, 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 (attnbuted 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 construchon 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 classificahon, a " Personnel Error" LER is defined as follows:

5) Design Engineenng Jp: late Backlog /In Progress.

PED has received the Moutfication Completion Report but An event for which the root cause is inappropriate action 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 modifications do not include inappropriate action must have occurred within modifications which are proposed for cancellation.

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

OVERALL PROJECT STATUS (REFUELING OUTAGE) 87

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

PERFORMANCE lNDICATOR DEFINITIONS Additionally, each event classified as a " Personnel Error" NPRDS components with rnore than two failures for the should also be classified as " Preventable

This indicator eighteerwnonth 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 Birnit are for lithium divided by the prevent the fulNiment of the safety functions of strudures or total number of hours possible for the month, systems, if a system consists of multiple redundant subsystems or trains, failure of all trains conslutes a safety PROCEDURAL NONCOMPLIANCE INCIDENTS system failure. Failure of one of two or mc e trains is not (MAINTENANCE) counted as a safety system failure. The d rhnition for the indicator parallels NRC reporting requiremeats in 10 CFR The number of identsfied incidents concoming maintenance 50.72 and 10 CFR 50.73. The following is a dst of the major procedural problems, the number of closed irs reisted to the salsty systerns, sub systems, and componer is monitored for use of procedures (includes the number of closed irs caused this indicator:

by procedural noncomphance), and the number of closed promdural noncompliance irs.

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

L,,,v.,n,y) Feedwater System, Combustible Gas Control, Component Cooling Water System, Containment and PROGRESS OF CYCLE 18 OUTAGE MODIFICATION Containment isolaten, Containment Coolant Systems, PLANNING Control Room Emergency Ventilation System, Emergency

' Core Cooling Systems, Engineered Safety Features This indicator shows the status of modsfications 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 1996 0N4JNE MODIFICATION PLANNING Ternperature Overpressure Protection, Main Steam Line isolation Valves, Onsite Emergency AC & DC Power This indicator shows the status of modifications approved for w/Distnbuten, Radiation Monitonng instrumentation, w.vn,6 dunng 1995.

Reactor Coolant System, Reactor Core isolation Cooling 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 identrhed poor radiological work practces 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 Cherrustry Performance index (CPI) is a ceiculation based The ratio of preventive maintenance (including surveillance on the concentraten of key impurities 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 rnaintenance and preventive maintenance deterioration of the steam generators. Criteria for calculating completed over the reporting period. The ratio, expressed as the cpl 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 administratively closed by the scheduled date plus a grace period equal to 25% of the

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

scheduled interval.

This indcator tracks preventive maintenance activities for SEP #41.

The CPI is calculated using the following equation:

RECORDABLE INJURY /lLLNESS CASES FREQUENCY CPI = ((sodium /0.79) + (Chloride /1.52) + (Sutfate/1.44) +

RATE (Iron /3.30) + (Copper /0.30)+(Condensate 02/2.90))/6 The number of injuries requinng 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 #15,25 and 26.

ppb, iron and copper are monthly time weighted average feedwater concentratons in ppb. The denominator for each of REPEAT FAILURES the five factors is the INPO median value. If the monthly average for a specific parameter is less than the INPO median The number of Nuclear 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 88

- - ~-

~-

PERFORMANCE INDICATOR DEFINITIONS Significant events are the events identified by NRC staff Tests, Maintenance Procedures Calibration Procedures, 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 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 identifed from the screening process as instruments are not considered as temporary a significant event candidate is further evaluated to determine modifications.

if any actual of 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 modification.

are summarized as follows:

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

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

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

This indicator tracks temporary modifications for SEP #62 and 71.

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

4) Scram with comphcation; The ratio of the design gross heat rate (corrected) to the j

adjusted actual gross heat rate, expressed as a percentage.

j

5) Unplanned release of radioactivity; j

UNIT CAPABILITY FACTOR i

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.

l (Significant Event Reports) which inform utilites of significant events and lessons leamed identried 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 during 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 penod, expressed in megawatt hours.

The actual staffing level and the authorized staffing level for the Nuclear Opera: ions Division, The Production Engineering UNPLANNED AUTOMATlc 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 serams (RPS logic actuations) that occur per 7,000 hours0 days 0 hours 0 weeks 0 months of cntical 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 penod 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 penod. 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 electncal part of a planned test.

Jumpers, electrical blocks, mechanical jumpers, or mechanical 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, wiring, or flow hquid 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 89

PERFORMANCE INDICATOR DEFINITIONS

3) Automatic means that the I,iltial 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 indicator switches or, manual turbine trip switches (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 ateady-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 plant operation and UNPLANNED CAPABILITY LOSS FACTOR maintenance. Dry radioactive waste includes contaminated rags, cleaning materials, disposable protective clothing, plastic The ratio of the unplanned energy losses during a given period containers, and any other material 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 continuousPy at full evaporator bottoms. Low-level refers to all radioactive waste power under reference ambient condtions) over the same time that is not spent fuel or a by-product of spent fuel processing.

period, expressed as a percentage.

This indicator tracks 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 means that the system actuation was not part of a planned test 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 N

DEFINITION)

The number of safety system actuations which include (gn!y) 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 gng when the logic systems for the above safety systems are challenged.

VIOLATION TREND 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 plant is trended over 12 months (lagging the Fort Calhoun Station trend by 2-3 months). It is the Fort Calhoun Station goal to be at or below the cited violation trend for the top quartile Region IV plant.

90

SAFEW 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 Referan..gJumber 15 EASA c

. Increase hPC and IR Accountability through use of Performance Indicators s

Procedural Noncompliance incidents (Maintenance) 50 Recordable injury /lliness Cases Frequency Rate..

4

^

Clean Controlled Area Contaminations >1,000 Disintegrations / Minute Per Probe Area 5

Preventable / Personnel Error LERs 6

SEP Reference Number 24

. Complete Staff Studies Staffing level...

43 SEP Reference Numbers 25. 26. & 27

. Training Program for Managers and Supervisors implemented

. Evaluate and implement Station Standards for Safe Work Practice Requirements

. Implement Supervisory Enforcement of industrial Safety Standards Disabling injury /lliness Frequency Rate..

3 Recordable injury / illness Cases Frequency Rate.

.4 SEP Reference Number 31 Develop Outage and Maintenance Planning Manual and Conduct Project Management Training MWO Planning Status (Cycle 17 Refueling Outage) 67 Overall Project Status (Cycle 17 Refueling Outage) 68 Progress of Cycle 17 Outage Modification Planning 69 SEP Reference Number 33 Develop On-Line Maintenance and Modification Schedule Percent of Completed Scheduled Maintenance Activities (All Maintenance Crafts) 51 SEP Reference Number 36

Reduce Corrective Non-Outage Backlog Maintenance Workload Backlogs (Corrective Non-Outage) 46 SEP Reference Numbers 41 & 44

. Develop and implement a Preventive Maintenance Schedule

. Compliance With and Use of Procedures Ratio of Preventive to Total Maintenance & Preventive Maintenance items Overdue 47 Procedural Noncompliance incidents (Maintenance) 50 SEP Reference Number 46 l

. Design a Procedures Control and Administrative Program i

l 91

SAFEW ENHANCEMENT PROGRAM INDEX Document Review 56 SEP Reference Number 52 Eagt

. Establish Supervisory Accountability for Workers Radiological Practices Radiological Work Practices Program

...... 55 SEP Reference Number 54

. Complete implementation of Radiological Enhancement Program Clean Controlled Area Disintegrations >1,000 Counts / Minute Per Probe Area..

.......... 5 Collective Radiation Exposure 17 Volume of Low-Level Solid Radioactive Waste

......... 38 Contaminated Radiation Controlled Area..........

...... 54 SEP Reference Number 58

. Revise Physical Security Training and Procedure Program Loggable/ Reportable incidents (Security) 57 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..........

..... 21 SEP Reference Number 62

. Establish interim System Engineers Temporary Modifications......

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

.................... 60 Engineering Change Notice Status

..... 61 Engineering Change Notices Open.

.... 62 SEP Reference Number 68

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

. 64 License Candidate Exams...

65 SEP Reference Number 71

. Improve Controls over Temporary Modifications Temporary Modifications 58 92

REPORT DISTRIBUTION llST 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 G. M. Cook W.J.Ponec M.R. Core D. G. Ried T. R. Dukarski M. J. Sandhoefner M. L. Ellis F. C. Scofield H. J. Faulhaber H. J. Sefick S. K Gambhir R. W. Short J. K. Gasper J. L. Skiles W. G. Gates R. D. Spies (2)

S. W. Gebers D. E. Spires D. C. Gorence M. A. Tesar R. H. Guy J. J. Tesarek A. L. Hale J. W. Tills K. R. Henry D. R. Trausch J. B. Herman L. P. Walling R. L. Jaworski G. R. Williams J. W. Johnson S. J. Willrett W. C. Jones D. D. Kloock M. Edwards (7)-Nuclear Licensing L.T.Kusek B. R. Livingston 93

ML20136B382

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