ML20101L717

Performance Indicators

ML20101L717
Person / Time
Site:	Fort Calhoun
Issue date:	02/29/1996
From:	OMAHA PUBLIC POWER DISTRICT
To:
Shared Package
ML20101L712	List: LIC-96-0045, Forwards Fort Calhoun Station Performance Indicators, for Feb 1996 ML20101L717
References
NUDOCS 9604040186
Download: ML20101L717 (104)

Text

__ _ _

Omano PimK Power Outfut FORT CALHOUN STATION PERFORMANCE INDICATORS

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OMAHA PUBLIC POWER DISTRICT i

FORT CALHOUN STATION PERFORMANCE INDICATORS REPORT FEBRUARY 1996 Production Engineering Division System Engineering FEBRUARY 1996

l FORT CALHOUN STATION February 1996 Monthly Operating Report i

OPERATIONS

SUMMARY

During the month of February 1996, the Fort Calhoun Station (FCS) operated at a 1

nominal 100% power. Normal plant maintenance, surveillance, equipment rotation activities and scheduled on-line modifications were performed during the month.

Monitoring of the Control Element Drive Mechanism (CEDM) mechanical seal leak continued. A planned maintenance outage is scheduled to commence on March 15,1996 with a planned duration of 7 days. During this mini-outage, the seal will be repaired and other work will be completed to improve station reliability for the upcoming summer.

On February 1, a supplemental on hour non-emergency notification was made to the NRC pursuant to 10CFR50.72(b)(1)(ii)(B) and (C) to update a reportable event from November 1995 in which FCS was found to be in a condition outside its design basis. Originally, only the motor control center (MCC) 480VAC breakers were considered susceptible to ground induced tripping. Further review concluded that, as a conservative measure, the affected breakers feeding safeguards motors should be included in the group of susceptible breakers. A modification to resolve the 480V breaker issue was finalized in February. Replacement trip devices have been procured with MCC breaker replacement anticipated during the mini-outage..

Eight additional incore nuclear detectors failed in February 1996, rendering five of the twenty-eight detector string inoperable.

These failures occurred in new detectors that were installed during the 1995 refueling outage. These failures are under investigation with assistance from ABB/CE and the incore detector vendor.

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The index tmnd is showing a small decline due to poor performance in the following parameters; Fuel Reliability, and Thermal Performance.

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FORT CALHOUN STATION PERFORMANCE INDICATORS REPORT December 1995 -

SUMMARY

POSITIVE TREND REPORT ADVERSE TREND REPORT A performance indicator with data representing three A performance indicator with data representng three consecutive months of improving performance or three consecutve months of declining performance or three consecutve months of performance that a supenor to the consecutive months of performance that is trending i

stated goal is exhibitng a positive trend per Nuclear toward dedining as determined by the Manager Station Operabons Dusion C'uality Procedure 37 (NOD-OP-37)

Engineenna constitutes an adverse trend per Nuclear Operatons DMsson Quality Procedure 37 (NOD-QP-37)

The followng performance indicators exhibited positive A supervisor whose performance indicator exhibits an trends for the reporting month-adverse trend by the definiton may specify in wntten form (to be pubhshed in the report) why the trend is not Safety System Failures adverse.

(Page 7)

The following performance indicators exhibited adverse Hiah Pressure Safety iniection System Safety System trends for the reportng month.

Performance 1

(Page 8)

Fuel Rehability Index (Page 14)

Emeroenev A C. Power System l

(Page 10)

Thermal Performance 1

(Page 33)

Emeroenev Diesel Generator Unreliebility

)

(Page 11)

Maintenance Workload Backloos Diesel Generator Reliability f25 Demands)

(Page 12)

Emeroenev Diesel Generator Unreliabilftv End of Adverse Trend Report.

l (Page 13) l Sianificant Events INDICATORS NEEDING INCREASED (Page 20)

MANAGEMENT ATTENTION REPORT Missed Surveillance Tests Results in Licensee Event A performance indicator wth data for the reporung period 1

Reports that s inadequate when compared to the OPPD goa! s (Page 21) defined as 'Needing increased Management Attention" per Nuclear Operations Dmsion Quality Procedure 37 j

Uncianned Safety System Actuatons -INPO Definiton (NOD-QP-37)

(Page 30)

Industnal Safety Accident Rate Secondary System Chemistry (Page 2)

(Page 39)

Disablina Iniurv/ Illness Frecuenev Rate Contaminated Radiation Controlled Area (Page 3)

(Page 56)

End of Positive Trend Report.

V

FORT CALHOUN STATION PERFORMANCE INDICATORS REPORT December 1995 -

SUMMARY

INDICATORS NEEDING INCREASED MANAGEMENT ATTENTION REPORT (continued)

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

Forced Outaae Rate (Page 24)

Eautoment Forced Outaae Rate (Page 35)

Cents oer Kilowatt Hour (page 44)

Percentaae of Total MWOs Comoleted oer Month identrfied as Rework (Page 50)

Temocrarv Modifications (Page 60)

PERFORMANCE INDICATOR REPORT IMPROVEMENTS / CHANGES Thra section lists significant changes made to the report and to specific indicators wrthin the report since the previous month.

Two new Chemistry Performance Indicators were added to the November Performance Indicator Book.

See pages 41 and 42.

End of Report Improvements / Changes Report.

vi

Table of Contents / Summary enan GOALS...............................................

......................... x SAFE OPERATIONS Industrial Safety Accident Rate - INPO.............

.................................. 2 Disabling injury / Illness Cases Frequency Rate........................................ 3 Recordable injuryAliness Cases Frequency Rate..................................... 4 Clean ControHed Area Contaminations 11,000 DisintegrationsMinute per Probe Area

................................ 5 Preventable / Personnel Error LERs................................................ 6 Safety System Failures 7

l Safety System Performance:

l High Pressure Safety injection system........................................ 8 l

AuxiNary Feedwater System

.......................... 9 Emergency AC Power System

..........................................10 l

Emergency Diesel Generator Unit ReNabiNty 11 ReNability (25 Demands)

.......................................................12 j

Un re li a bi hty................................................................. 13 Fuel Relia bility Indicator............................................................. 14 Control Room Equipment Deficiencies.................................................. 15 On-Une and Outage Control Room Deficiencies........................................... 16 Collectiv e Radiation Ex posure........................................................ 17 Maximum individual Radiation Exposure

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

...............................19 Significant Events.......................

..................20 Missed Surveillance Tests Resulting in LERs 21 l

PERFORMANCE l

Station Net Generation..........................

..........................23 Forced Outage Rate....................................

......................24 Unit Ca pa city Factor.....................................

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

26 vil

~

Table of Contents / Summary PERFORMANCE (continued)

PAGE U nit Ca pa bility Fa ctor................................................................ 27 Unplanned Capabikty Loss Factor 28 Unplanned Automatic Reactor Scrams per 7,000 Hours c ritical.................................................

. 29 Unplanned Safety System Actuations INPO Definition..................................

30 NRC Definition............................................................. 31 G ross He at R ate................................................................ 32 Thermal Performance

................................ 33 Daily Thermal Output.............................................................. 34 Equipment Forced outages per 1,000 Critical Hours...................................... 35 Component Failure Analysis Report (CFAR) Summary.................................... 36 Repeat Failures

.................................................... 37 Volume of Low-Level SoEd Radioactive Waste

.................. 38 Secondary System Chemistry.................................................... 39 Chemistry Action Levels Exceeded - Event Days.............................

...........40 Primary System Lithium % Hours Out of Limit........................................... 41 l

G.QI.I Cents Per Kilowatt Hour....................

..............43 Staffing Level.....................

44 Spare Parts inventory Value...

... 45 DIVISION AND DEPARTMENT PERFORMANCE INDICATORS Maintenance Workload Backlogs (Corrective Non Outsge) 47 Ratio of Preventive to Total Maintenance & Preventive Maintenance Items Overdue 48 Percentage of Total !W0s Completed per month identified as Rework 49 Overtime 50 Procedural Noncompliance Incidents 51 Daily Schedule Performance Percent of Completed Scheduled Activities 52 viii

Table of Contents / Summary DIVISION AND DEPARTMENT PERFORMANCE INDICATORS Mfaf in-Une Chernistry Instruments Out-of-Service..

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

... 54 Contaminated Radiation Cor trolled Area...........

...........................55 Radiological Work Practices Program

.............................. 56 Document Review

.. 57 Loggable/Reportabie lncidents (Security)................

..........58 Modificationc Te mpora ry......................................

......................59 O utsta nding....................................

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

..... 61 Engineering Change Notices Status

................62 Open

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

.................64 Ucensed Operator Requahfication Training........................................... 65 Ucense C andidate Ex ams...........................................

............ 66 Open Incident Reports........................

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

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

..............................................70 Outage Modification Planning

........................... 71 On-Une Modification Planning.......................................... 72 Progress of 1996 On-Une Modification Planning......

72 ACDON PLANS. DEFINmONS. SEP INDEX & DISTRIBUTION LIST Action Plans..............

........ 73 Performance indicator Definitions......................

80 Safety Enhancement Programindex

..............88 Report Distribution Ust..................

... 90 ix

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i l

i OPPD NUCLEAR ORGANIZATION GOALS 1996 Priorities MISSION The safe, reliable and cost effective generation of electricity for OPPD customers through the professional use of nuclear technology. The Company shall conduct these operations prudently, efficiently and effectively to assure the health, safety and protection of all personnel, the general public and the environment.

1 GOALS Goal 1:

SAFE OPERATIONS Supports: April 1995 Corporate Strategic Plan Goal 3 Obj: 3 & 4 l

A proactive, self critical and safety conscious culture is exhibited throughout the nuclear organization.

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

1996 Priorities:

f Improve SALP ratings.

Improve INPO rating.

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

No unplanned automatic reactor scrams or safety system actuations.

Objectives to support SAFE OPERATIONS.

OBJECTIVE 1-1:

No challenges to a nuclear safety system.

OBJECTIVE 1-2:

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

OBJECTIVE 1-3:

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

OBJECTIVE 14:

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

OBJECTIVE 1-5:

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

X

i l

l OPPD NUCLEAR ORGANIZATION GOALS 1996 Priorities Goal 2:

PERFORMANCE Supports: April 1995 Corporate Strategic Plan Goal 3, Obj: 2; G-4, Obj: 1, 2 & 3; G-6 Obj 3.

Nuclear teamwork achieves high performance at Fort Calhoun Station as exhibited by safe, reliable and cost effective power production.

1996 PRIORITIES:

Improve Quality, Professionalism, Teamwork and Training.

Maintain High Plant Reliability.

Pursue efficient, cost-effective work processes, i

Meet or exceed INPO key parameters and outage performance goals.

Reduce the number of Human Performance errors.

Identify Programmatic performance problems through effective self assessment.

Maintain a high level of readiness in the ERO.

Objectives to support PERFORMANCE:

OBJECTIVE 2-1:

Achieve an annual plant capacity factor of 81.4% and a unit capability factor of 83.5%.

OBJECTIVE 2-2:

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

OBJECTIVE 2-3:

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

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

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

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

j Executive Training Committee:

j 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 J

uniformly emphasized.

OBJECTIVE 2 4:

Achieve all performance-related 1996 performance indicator goals in the Performance Indicator Report. Focus on performing basic skills well while pursuing efficient, cost-effective verk processes. Identify the barriers to excellence and resolve them.

XI

OPPD NUCLEAR ORGANIZATION GOALS 1996 Priorities OBJECTIVE 2-5:

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

OBJECTIVE 2 6:

Through the Utilities Service Alliance (USA) attain operating efficiencies and lower cost through a cooperative effort among several utilities. Initial focus is on sharing of personnel for outage support, combined purchasing and contracting, common dosimetry reading, sharing of equipment, including test equipment, standardization of plant access and general employee training.

l Goal 3:

COSTS Supports: April 1995 Corporate Strategic Plan Goal 2, Obj: 1,2 and 3, and Goal 6, Obj: 1 i

Operate Fort Calhoun in a manner that cost effectively maintains nuclear generation as an economically viable contribution to OPPD's " bottom line". Cost consciousness is exhibited at alllevels of the organization.

1996 Priorities:

Maintain total O&M and Capital Expenditures within budget.

Streamline work process to improve cost effectiveness.

l Implement Opportunity Review recommendations.

Objectives to support COSTS:

OBJECTIVE 3-1:

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

OBJECTIVE 3-2:

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

4 Goals Source:

Lounsberry (Manager) xil

1-l i

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

1

_.,_. Year-to-Date FCS Industrial Safety Accident Rate (INPO Definition)

,_ FCS Average Rate (Last 12 Months)

+ ICS Year-End Goal (<0.50) tile (.24)

Industry Current Best Quar

!0000!

1995 Industrial Safety AccYear 2000 INPO Industry (ident(< Rate ()INPO Defination) bel 0.40 II 2.

1.5 1

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

The INPO industrial safety accident rate value year-to-date was 0.00 at the end of February 1996. The value for the 12 months from March 1,1995, through February 29,1996, was 1.01.

There were no restricted-time and zero lost-time accidents in February 1996.

The values for this indicator are determined as follows:

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

The 1996 Fort Calhoun year-end goalis 50.50. The Year 2000 INPO industry goalis 50.40. The approximate industry upper ten percentile value is 0.12.

Data Source:

Sorensen/Skaggs (Manager / Source)

Chase / Booth (Manager / Source)

Accountability:

Chase Trend:

Needs increased Management Attention 2

l

_e_,

1996 Disabtng injur)dtness Frequency

-x 1995 Disablinginjur)dtness Frequency

+ Average Rate (Last 12 Months) l 0000 l

+ 19M Goal (0.50) 2.

1.8 _

1.6 _

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0.8.

0.6.

l 0.4.

0.2.

O Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb 1996l DISABLING IN]URY/ ILLNESS FREQUENCY RATE (LOST-TIME ACCIDENT RATE)

This indicator shows the 1996 disabling injury / illness frequency rate. The 1995 disabling injury /

illness frequency rate is also shown.

The disabling injury / illness frequency rate year-to-date was 0.00 at the end of February 1996.

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

The disabling injury / illness frequency rate for the 12 months from March 1,1995, through Feb-ruary 29,1996, was 1.1.

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

4 Data Source:

Sorensen/Skaggs (Manager / Source)

Accountability:

Chase Trend:

Need increased Management Attention SEP 25,26 & 27 3

l l

1996 Recordable injuryminess Frequency x

1995 Recordable injuryminess Frequency I 0000 l

_a__._ Average Rate (Last 12 Months)

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...o... Fort Calhoun Goal 2.25 __

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1.75 __

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Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb l1996l RECORDABLE INJURY / ILLNESS FREQUENCY RATE This indicator shows the 1996 recordable injury / illness frequency rate. The 1995 record-able injury / illness cases frequency rate is also shown.

A recordable injury / illness case is reported if personnel from any of the Nuclear Divisions are injured on the job and require corrective medical treatment beyond first aid. The recordable injury / illness cases frequency rate is computed on a year-to-date basis.

There have been 0 recordable injury / illness cases in 1996. The recordable injury / illness cases frequency rate year-to-date was 0.00 at the end of February 1996. There were 0 recordable injury / illness cases reported for the month of February.

The recordable injury / illness cases frequency rate for the 12 months from February 1, 1995, through January 31,1996, was 1.24.

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

Data Source:

Sorensen/Skaggs (Manager / Source)

Accountability:

Chase Trend:

None SEP 15,25,26 & 27 4

m CantansmionEmts(Monthly)

_,_ contamination Events (YTQ 40.

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30.

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O Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 1996 CLEAN CONTROLLED AREA CONTAMINATIONS 21,000 DISINTEGRATIONS / MINUTE PER PROBE AREA This indicator shows the Personnel Contamination Events in the Clean Controlled Area for contaminations 21,000 disintegrations / minute per probe area for the reporting month.

l There were O contamination events in February 1996. There has been a total of 1 contamination event in 1996 through the end of February. This compares to 9 at this time last year.

Data Source:

Chase /Cartwright (Manager / Source)

Accountability:

Chase /Gebers Trend:

None SEP 15 & 54 5

1

4 m

m m PersonnelErrors(EschMonth)

,_. Preventable (18-MonthTotals) e_. PersonnelError(18-MonthTotals) 20..

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E; Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun Jtd Aug Sep Oct Nov Dec Jan 1996 PREVENTABLE / PERSONNEL ERROR LERs This indicator depicts 18-month totals for numbers of " Preventable" and " Personnel Error" LERs.

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

In January 1996, there were no events which were subsequently reported as an LER.

No LERs were categorized as Preventable or as Personnel Error for the month of Janu-ary. The total LERs for the year 1996 (through January 31,1996) is zero. The total Personnel Error LERs for the year 1996 is zero. The total Preventable LERs for the year 4

is zero.

The 1996 goal for this indicator is that the year-end values for the 18-month totals be no more than 12 Preventable and 5 Personnel Error LERs.

Data Source:

Tills /Cavanaugh (Manager / Source)

Accountability:

Chase Trend:

None SEP 15 6

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,,,a 92-2 92 3 92-4 93-1 93-2 93-3 93-4 94 1 94-2 94 3 94-4 95-1 Year-Quarter 4

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 Onerational Data in the biannual" Performance Indica-tors for Operating Commercial Nuclear Power Reactors" report.

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

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

2nd Quarter 1993: A section of the piping configuration forthe borated water source of the safety injection system was not seismically qualified. This could have resulted in a failure of the system to meet design requirements during a seismic event.

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

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

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

There have been no safety system failures as of February 29,1996.

Data Source:

Nuclear Regulatory Commission Accountability:

Chase Trend:

Positive 7

d Monthly High Pressute Safety injection System Unavailability Value

-Year-to Date High Preasure Safety injection system Unavailability Value

_ Fort Calhoun Goal (0.003)

Good l Year 2000 INPO Industry Goal (0.02)

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0 1994 1995 Jan Feb Mar Apr May Jun Jul Aug sep Oct Nov Dec 1996l HIGH PRESSURE SAFETY INJECTION SYSTEM SAFETY SYSTEM PERFORMANCE This indicator shows the High Pressure Safety injection System unavailability value, as defined by INPO in the Safety System Performance Indicator Definitions, for the reporting month.

The High Pressure Safety System unavailability value for the month of February 1996 was 0. There were 0 hours0 days <br />0 hours <br />0 weeks <br />0 months <br /> of planned unavailability, and 0 hours0 days <br />0 hours <br />0 weeks <br />0 months <br /> of unplanned unavail-ability, during the month. The 1996 year-to-date HPSI unavailability value was 0.0 at the end of the month. The unavailability value for the last 12 months was 0.000509.

There was a total of 13.39 hours4.513889e-4 days <br />0.0108 hours <br />6.448413e-5 weeks <br />1.48395e-5 months <br /> of planned unavailability and 0.0 hours0 days <br />0 hours <br />0 weeks <br />0 months <br /> of unplanned unavailability for the high pressure safety injection system in 1995.

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

The 1996 Fort Calhoun year-end goal for this indicator is a maximum value of 0.003. The Year 2000 INPO industry goal is 0.02 and the industry upper ten percentile value (for the three-year period from 1/92 through 12/94) is approximately 0.001.

Data Source:

Skiles/Schaffer (Manager / Source)

Accountability:

Skiles/Schaffer l

l Trend:

Positive l

I 8

. Monthly Auxiliary Feedwater system Unavailability Year-t@te Emergency AC Power Unavailability l GOOD a

...o... Fbrt Calhoun Goal (OD1) c Year 2000 INPO Industry Goal (0.025) y e

industry Upper 10%(0.0021) 0D2 a

a a

a z

a z

a OD18 __

0D16 0.014 __

0.012._

DD1 o..... o..... o..... o...... e..... o..... o..... o..... o..... o..... o..... o ODO8 __

0.006._

.co4:.co4s 0D04.4.eene 0.002 __

g c

c c

c c

c c

c c

a 0

l 1994 1995 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec l1996 AUXILIARY FEEDWATER SYSTEM SAFETY SYSTEM PERFORMANCE This indicator shows the Auxiliary Feedwater System Unavailability value, as defined by INPO in the Safety System Performance Indicator Definitions, for the reporting month.

The Auxiliary Feedwater System Unavailability Value for February 1996 was 0.00. There were 0.0 hours0 days <br />0 hours <br />0 weeks <br />0 months <br /> of planned and 0.0 hours0 days <br />0 hours <br />0 weeks <br />0 months <br /> of unplanned unavailability during the month.

The year-to-date unavailability value was 0.00457 and the value for the last 12 months was 0.00493 at the end of the month.

There has been a total of 0.0 hours0 days <br />0 hours <br />0 weeks <br />0 months <br /> of planned unavailability and 6.8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> of unplanned unavailability for the auxiliary feedwater system in 1996. The unplanned unavailability on FW-10 was due to a failed relay on HCV-1045B.

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

The Year 2000 INPO industry goal is 0.025 and the industry upper ten percentile value is approximately 0.002.

Data Source:

Skiles/Fritts (Manager / Source)

Accountability:

Skiles/Fritts Trend:

None 9

O e Monthly Ernergency Ac Power UnavailabilityValue

--x Year-to-Date Emergency Ac Power Unavailability Value 1996 Fort Calhoun Goal (0.024) l GOOD l o_ Year 2000INPoIndustryGoal(0.025) 9 y

c Industry Upper 10%(0.0035) 0.14._

l 0.12 _

l 1

0.1 _

0.08 __

0.06 _

0.04 _

0.02 __

0 m,_

,-eP, X

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

The Emergency AC Power System unavailability value for February 1996 was 0.005.

During the month, there were 7.0 hours0 days <br />0 hours <br />0 weeks <br />0 months <br /> of planned unavailability, and 0.0 hours0 days <br />0 hours <br />0 weeks <br />0 months <br /> of un-planned unavailability for testing and repairs. The Emergency AC Power System un-availability value year-to-date was 0.007 and the value for the last 12 months was 0.011 at the end of the month.

There has been a total of 20.7 hours8.101852e-5 days <br />0.00194 hours <br />1.157407e-5 weeks <br />2.6635e-6 months <br /> of planned unavailability and 0.0 hours0 days <br />0 hours <br />0 weeks <br />0 months <br /> of unplanned unavailability for the emergency AC power system in 1996.

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

The Year 2000 INPO inaustry goal is 0.025 and the industry upper ten percentile value is approximately 0.0035.

Data Source:

Skiles/Ronning (Manager / Source)

Accountability:

Skiles/Ronning Trend:

Positive due to performance better than goal.

10

1 ranuresf20 Demands m

a Failures /S0 Demands e Failures /100 Demands lG000l Trigger Valuest20 Demands

+ Trigger ValuesISO Demands II Trigger Values.100 Demands 8..

7..

6 5

4 s

2

- 33

,y yq y,

,y y,

y o

y Mar Apr May Jun Jul Aug sep oct Nov Dec Jan Feb l1996l EMERGENCY DIESEL GENERATOR UNIT RELIABILITY This bar graph shows three monthly indicators pertaining to the number of failures that were reported during the last 20,50, and 100 emergency diesel generator demands at the Fort Calhoun Station. Also shown are trigger values which correspond to a high level of confidence that a unit's diesel generators have obtained a reliability of greater than or equal to 95% when the failure values are below the corresponding trigger values. The Fort Calhoun 1996 goal is to have fewer failures than these trigger values.

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

Data Source:

Skiles/Ronning (Manager / Source)

Accountability:

Skiles/Ronning Trend:

Positive due to performance better than goal.

11

DG-1 FsHures/25~ Demands g DG2 Failures /25 Demands lG000l 5.

y 4.

e 3

3.

2 1

1 1

1 1

1 1

1 1

g i

1-j q

q 0

0 0

0 0

0 0 0

0 0

0 0

0 0

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

This indicator shows the number of failures experienced by each emergency diesel gen-erator during the last 25 start demands and the last 25 load-run demands. A trigger value of 4 failures within the last 25 demands is also shown. This trigger value of 4 failures within 25 demands is the Fort Calhoun goal for 1996.

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

place in the event that any one emergency diesel generator experiences 4 or more fail-ures within the last 25 demands on the unit. These actions are described in the Defini-tions Section of this report. A System Engineering Instruction has been approved for the Fort Calhoun Station to institutionalize and formally approve / adopt the required NUMARC actions.

Diesel Generator DG-1 has experienced one failure during the last year, and zero fail-

]

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

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

Data Source:

Skiles/Ronning (Manager / Source)

Accountability:

Skiles/Ronning Trend:

Positive due to performance better than goal.

12

DG-1 Unreliability Value DG 2 Unreliability Value Station UnreliabilityValue 1996 Goal lGOODI I

l s

Industry Upper 10%(0.002 for a 3-Year Average) 0.06.

045__

c 2

0.04 --

'8" 0.03.

ey s 0.02 __

0.01._

eo eo ee ee e

o e

e e

e e

ee 9'

0 9

9 9

9 9

Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb l1996l EMERGENCY DIESEL GENERATOR UNRELIABILITY j

The purpose of this indicator is to monitor the likelihood that emergency AC power generators will respond to off-normal events or accidents. It also provides an indication of the effectiveness of maintenance, opera-tion and test practices in controlling generator unreliability. The last event occured on September 1,1995 when the Field Flash Relay on DG-2 failed.

The year-to-date station EDG unreliability at the end of February 1996 was 0.0. The 1996 goal for this indicator is a maximum value of 0.05.

For DG-1:

There was 1 start demand for the reporting month with 0 failures.

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

For DG-2:

There was 1 start demand for the reporting month with 0 failures.

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

Emergency diesel generator unreliability is calculated as follows:

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

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

Skiles/Ronning (Manager / Source)

Accountability:

Skiles/Ronning Trend:

Positive due to performance better than goal.

13

FueiMlabiHty GOOD l

+ Year 2000 INPO Industry Fuel Defect Reference (5 x 10-4 Microcuries/Grarn)

_o_

1996 Goal (9/1/96 tbrough 12/31/96) 96 _

80 _

! 70_

60 _

j 50 40 _

c res. is n

R ef ueling 3 30 -

outase

} 20.

" 10 _

n i _ i i

i i

i Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb l1996l FUEL RELIABILITY INDICATOR The FUEL RELIABILITY INDICATOR (FRI) for February 1996 was 73.40 X 10d microcuries/ gram. The purpose of the FRI is to monitor industry progress in achieving and maintaining a high level of fuel integrity.

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

The February FRI value is based on data from February 1" through 29*, The days selected are when the plant chemistry values were at equilibrium for steady-state full power operation.

Cycle 16 plant operation started on April 13* and attained 100% on April 23'*,1995. Durirg the months of

)

June and July the plant operated at 100% power. The plant tripped at the end of August but has operated at 100% during the months of September through February.

The February FRl value of 73.40 X 10d microcuries/ gram indicated a decrease from the January FRI value of 75.52 X 10d microcuries/ gram. No new fuelfailures wo etermined to have occurred during the month based on changes in the equilibrium Xenon and lodine de This is consistent with the normalincrease of fission products during a cycle and the increased power pr.. tion of the peripheral assemblies due to shim bumout and the subsequent power distribution changes with power shifting from the center of the core to the periphery. Recent analysis through February 29,1996, performed by nuclear engineering, indicated five to ten failed rods at core average power. The Ceslum isotopic analysb indicated failures in several different bumup levels. OPPD personnel estimate that 15 to 25 rods are failed baseu on the results from the Cycle 15 and 16 RCS chemistry data and the end of Cycle 15 fuelinspection project.

The INPO "WANO Performance Indicator Program Utility Data Coordinator Reference Notebook" (INPO No.94-009, Rev.1) states the Industry Goal for fuel reliability is: " units should strive to operate with zero fuel defects". The 1996 Fort Caihoun Station FRI Performance Indicator goalis to maintain a monthly FRl below 5.0 x 10d micrr" ies/ gram. A value larger than 5.0 x 10d microcuries/ gram indicates a high probability of reactor core operation with one or more fuel defects. The 1996 year end goal can be met after the 1996 RFO. See page lii.

Data Source:

Bostelman/Riva Accountability:

Chase /Stafford Trend:

Adverse 14

l m ControlRoom Deflciencies Added

, Control Room Deficiencios Completed e Completed within Target Completion Date 50..

_ _100.0%

Goal.Conpiese80%of CR Defcanness byTargW ConplarenDate 40 80.0%

1 ai

....,Qh

.m j30 60.0% a y

k os.o, g

h

" ai si

]

o 20._ ' '

i

7

.. 40.0% %

is is is is io

• 10

. 20.0% at 0

0.0%

Jul Aug Sep Oct Nov Dec Jan-96 Fe b-96 Control Room Deficiencles NUMBER OF CONTROL ROOM EQUIPMENT DEFICIENCIES This indicator measures the timeliness of closing Control Room Deficiencies.

Target Completion Dates are established by the Emergent Work Committee. The goal is to close at least 80% of all CRDs within the Target Due Date. In February, the goal was achieved with 82.3% closed within the target date.

There were 17 Control Room Deficiencies completed during February 1996, and 14 were completed within the target completion date.

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

Data Source:

Chase /Kermoade (Manager / Source)

Accountability:

Chase /Faulhaber Trend:

None 15

O m overdue

+ Number of On-Une Control Room Deficiencias 30.

2, 25 2

20.

$3 15._

l Jul Aug sep Oct Nov Dec Jan06 Feb-96 l Number of On-Line CRDs j m Overdue

+ Number of Outage ControlRoom Deficiencies 2

3 15 1 tbte: Overdue tems are those older ttun 18 morthe

'o

. ~......

5._

0 Jul Aug sep oct Nov Dec Jan-96 Feb.96 l Number of Outage CRDsl NUMBER OF ON-LINE AND OUTAGE CONTROL ROOM DEFICIENCIES This indicator shows the total number of On-Line and Outage Control Room Deficiencies, and the rumber of overdue Control Room Deficiencies.

There were 9 on-line (8 were overdue) and 29 outage (2 were overdue) Control Room Deficiencies at the end of February 1996.

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

Data Source:

Chase /Kermoade (Manager / Source)

Accountability:

Chase /Faulhaber/ Herman Trend:

iusds increased Management Attention - Number of On-Line CRDs

<8 Overdue exceeds goal 16

4 g Monthly Personnel Radistion Exposure Cumulative Personnel Radiation Exposure

[Tgy607

_o_. FcS Goal 138 person-REM I

I E

1 130 120 110 100 90 l 80 70 60 50 40 30 20 __

{

10 0a Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 1996 COLLECTIVE RADIATION EXPOSURE The 1996 Fort Calhoun goal for collective radiation exposure for the year is set a 138.0 person-REM.

The exposure for February 1996 was 2.058 person-Rem (ALNOR).

The year-to-date exposure through the end of February was 3.493 person-Rem (TLD).

The Year 2000 INPO industry goal for collective radiation exposure is 120 person-rem per year. The current industry best quartile is 145 person-rem per year. The yearly average for Fort Calhoun Station for the three years from 3/93 through 2/96 was 106.39 person-rem per year.

Data Source:

Chase /Cartwright (Manager / Source)

Accountability:

Chase /Gebers Trend:

None SEP54 17

Hghest Muttfy h9wW Spcare(1996)

+ Rrt QinnLht 1000.

900.

800.

700.

800.

500.

co.

300.

200.

100.

0 dri Rb Mr Apr Nby an JJ Aug Sep Oct Nw De 1996 MAXIMUM INDIVIDUAL RADIATION EXPOSURE During February 1996, an individual accumulated 173 mrem, which was the highest individual exposure for the month.

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

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

Data Source:

Chase /Cartwright (Manager / Source)

Accountability:

Chase /Gebers Trend:

None 18 j

l l

l m FCS Cited Violations (Monthly) l

-c-g FCS Non-Cited Violations (Monthly)

FCS Cited Violations (12-Month Average) l l

l

._e FCS Non-Cited Violations (12-Month Averege) g Reglon IV Cited Violations (12-Month Average for Region IV top quartile) l I 14 -

N:

l 8_

~

~

~

~

~

~

0 C

0 1

o 2_.

- y 0

m

m

e

0;E;m

m

E a

a r

t r

e g

a j

,s t

j E

z m

z 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-montn trend for the Region IV top quartile lags 2-3 months behind the Fort Calhoun Station trend. This lag is necessary to compile information on other Region IV plants.

The following inspections were completed during February 1996:

IER No.

T!tle N/A N/A To date, OPPD has received two violations for inspections conducted in 1996.

Levellli Violations O

LevelIV Violations 2

Level V Violations 0

Non-Cited Violations

_0 i

Total 2

The 1996 Fort Calhoun Station Goal for this performance indicator is to be at or below the cited violation trend for the top quartile plant in Region IV.

Data Source:

Tills /Cavanaugh (Manager / Source)

Accountabi!!ty:

Tills Trend:

None l

19

NRC 51gnmcant Events I

,_ industry Average Trend l

l GOOD l i

1 1

V m

0.5._

0

=

e

=

e e

=___q_.

_+__s q 92-2 92-3 92-4 93-1 93-2 93-3 93 4 94-1 94-2 94 3 94-4 95-1 l Year -Quarter l INPO Significant Ewnts (SERs)

OOODl 2 __

g y

y y

y 37 1_.

0 i

i i

i 92-2 92 3 92 4 93-1 L42 93-3 93-4 94-1 94-2 94-3 94-4 95-1 l Year-Quarter l SIGNIFICANT EVENTS This indicator illustrates the number of NRC and INPO Significant Events for Fod Calhoun Station as re-

)

ported by the Nuclear Regulatory Commission's Office for Analysis and Evaluation of Operational Data in the biannual" Performance Indicators for Operating Commercial Nuclear Power Reactors" report and INPO's Nuclear Network.

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

3rd Quarter 1992: The failure of a Pressurizer Code safety valve to reseat initiated a LOCA with the potential to degrade the reactor coolant pressure boundary.

4th Quarter 1994: A potential accident scenario invoMng a large break loss of coolant accident or a main steam line break inside containment could result in the inoperability of both control room A.C. units.

The following INPO significant events, as reported in Significant Event Reports (SERs), occurred between the 2nd quader of i992 and the 1st Quader of i995:

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

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

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

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

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

Data Source:

Nuclear Regulatory Commission & INPO Accountability:

Chase Trend:

Positive 20

i i

MssedSTsInstitinginLIRs 3__

G"CET l

Y 2__

1 1

o 0

0 0

0 93 94 95 Jan Feb Whr Apr Mry Jiri Jti Aug m%p Oct Ftw 1996 NUMBER OF MISSED SURVEILLANCE TEST RESULTING IN LICENSEE EVENT REPORTS This indicator shows the number of missed Surveillance Tests (STs) that result in Lic-ensee Event Reports (LERs) during the reporting month. The graph on the left shows the yearly totals for the indicated years.

There were no missed surveillance tests resulting in LERs during February 1996.

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

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

Data Source:

Monthly Operating Report & Plant Licensee Event Reports (LERs)

Accountability:

Chase /Skiles Trend :

Positive SEP 60 & 61 21

l i

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

l i

i 22

Net Generation (10,000 MWh) l 40.

34.75 35.08 M.12 30.46 30 I

E 22.82 g 20.

15.29 g

i i

~

n[f.i[.s outes.

0

+

0 l

I I

I I

I I

I I

I l

l Mar Apr May Jun Jul Aug Sep oct Nov Dec Jan Feb P9 STATION NET GENERATION i

During the month of February 1996, a net total of 338525.5 MWh was generated by the Fort Calhoun Station. Cumulative net generation for Cycle 16 was 3346541.2 MWh at the end of the month.

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

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

Data Source:

Station Generation Report Accountability:

Chase Trend:

None 23

-._~

, Forced Outage Rate (Monthly)

+ Forced Outage Rate (12 Months) l GOOD l

+ 1996 Fort Calhoun Goal (1.4%)

40%..

3 f 35% -

30 %

25%.

20%.

l 15% __

10%.

5%-

,,m 0%

i 93 94 95 Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb 1996 FORCED OUTAGE RATE The forced outage rate (FOR) was reported as 3.59% for the twelve months from March 1,1995, through February 29,1996. The 1996 year-to-date FOR was 0.0% at the end of the month.

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

Energy losses for May 1995 were attributable to two separate shutdowns to repair com-ponent cooling water leaks in the lube oil system of RC-3D reactor coolant pump motor oil.

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

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

Date Source:

Monthly Operating Report Accountability:

Chase Trend:

Needs increased Management Attention 24

I E

i

...s...

Year-to Dete Unit Capacity Factor g

Unit Capacity Factor for Cycles 15 & 16

_6_

36 Wlonth Average thit Capacity Factor GOOD l 110%..

1996 FCS Goal (81.49*4 100 %..

p

- -.. -a.

90%..

/

o 80%.. S E

E E

T s-g

.u -

g,

/

70%..

y

.s.

.0%..

p a.

gn.3 __

.s.....-

40%.

30e/,._

Refuellfig Cycle 15 20%..

oui 10%..

0%

i i

i i

i i

i i

i i

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

1996 UNIT CAPACITY FACTOR This indicator shows the plant rnonthly Unit Capacity Factor, the Unit Capacity Factor for the current fuel cycle, year-to-date and the 36-month average Unit Capacity Factor.

At the end of the month, the Cycle 16 Unit Capacity factor was 90.87%, and the Unit Capacity Factor for the last 36 months was 81.83%. The 1996 Fort Calhoun annual goal for this indicator is 82.00%.

The year-to-date value is 101.81%

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

The Unit Capacity Factor is computed as follows:

Net Electrical Enerov Generated (MWH)

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

Monthly Operating Report Accountability:

Chase Trend:

None 25

.._r

,s l

mmly N i

l Year-to_Date Average Monthly EAF

(

+ 12-Month Average EAF

1. industry Median Value (76.7%for a 3-Year Average) 100%..

s 7.as p

a-e s.s s 4

L h~

a k

d

/

8' 80%..

,,,, g r

x x

x x

x

= -

60% [O i

40%.

c yci. is l

n.v nne i

Outage l

20%.

l i

i 0%

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

l 1996 EQUIVALENT AVAILABILITY FACTOR l

This indicator shows the plant monthly Equivalent Availability Factor (EAF), the year-to-date average monthly EAF, and the year-end average monthly EAF for the previous three years.

The EAF for February 1996 was reported as 98.85%. The year-to-date monthly average EAF was 98.9% at the end of the month.

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

The Fort Calhoun average monthly EAF for the three years prior to this report was 88.4%.

1 The industry three year median value is 76.7%.

i Data Source:

Dietz/Kulisek (Manager / Source) i Accountability:

Chase Trend:

None 26 i

1 MontNyUnit CapatMty Factor i

i l

...s... Year to Date lhlt Capability Factor Ik 36440 nth thit CapabilityFactor 1996 Fort Calham Chels GOOD

1. FOlndustryGoals Year 2000 100% - _

l 2

--~'"

80%_

- f - - - -s- - - - 5 5

~

j

,E

.y

,g.....

.n.

60%__

.....g.......a 40%.

Cycle 16 Refueling 20%_

l 0%

l Mar Apr May Jm Jtd Aug Sep Oct Nov Dec Jan Feb 1996 UNIT CAPABILITY FACTOR This indicator shows the plant monthly Unit Capability Factor (UCF) value, the year-to-l date UCFs, the 36-month average UCFs, and the UCF goals. UCF is defined as the ratio of the available energy generation over a given period of time to the reference energy generation (the energy that could be produced if the unit were operated continuously at full power under reference ambient conditions) over the same time period, expressed as l

a percentage (refueling periods excluded).

The UCF for February 1996 was reported as 100.0%. The year-to-date UCF was 100%,

the UCF for the last 12 months was 83.5%, and the 36-month average UCF was reported i

as 85.4% at the end of the month.

l l

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

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

l Data Source:

Generation Totals Report & Monthly Operating Report Accountability:

Chase Trend:

None 27

Montity LMplanned Qipability Less Fector j0000l i

i

._ _ Year-To-Dete thplanned Capabilityi. css Factor

+ 12-Morth Amrage thplanned CapabilityLoss Factor y

_x FortCahounChal(3.00W

._e_

Year 2000 N80 industryGoal(4.5%

_e._ industryCummt Best QLartile 10%..

0% !

=

=

l l

l i

Jan Feb Mar Apr May Jm Jtd Aug Sep Oct Nw Dec 1996l UNPLANNED CAPABILITY LOSS FACTOR This indicator shows the plant monthly Unplanned Capability Loss Factor (UCLF), the year-to-date UCLF and the goal. UCLF is defined as the ratio of the unplanned energy losses during a given period of time, to the reference energy generation (the energy that could be produced if the unit were operated continuously at full power under reference ambient conditions), expressed as a percentage.

The UCLF for the month of February 1996 was reported as 0.00%. Unplanned energy loss is defined as the energy that was not produced during the period of unscheduled shutdowns, outage extensions, or load reductions due to causes under plant manage-ment control. Energy losses are considered to be unplanned if they are not scheduled at least four weeks in advance. The year-to-date UCLF was 0.00%, the UCLF for the last 12 months was 6.29%, and the 36-month average UCLF was reported as 4.5% at the end of the month.

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

l Data Source:

Generation Totals Report & Monthly Operating Report Accountability:

Chase Trend:

Needs increased Management Attention.

28

_e FG5 Reactor Scrams Per 7,000 Hours Grltical Year-to-Date

+ Fcs Reactor scrams Per 7,000 Hours Critical for last 36 months

+ Fort Calhoun Goal (0.0)

%._. Year 2000 INPO Industry Goal (1) l

--e-Industry Upper 10%(1 per 7,000 hours0 days <br />0 hours <br />0 weeks <br />0 months <br /> critical) 3._

N A.

I p A

A A

d

/4 4

A L

4

}

l 0

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

1996 FCs Reactor scrams -199S 4.

3 3.

2 2..

1 1

1.

0 0

0 i

i 92 93 94 95 Jan Feb Mar Apr May Jun Jul Aug sep Oct Nov Dec UNPLANNED AUTOMATIC REACTOR SCRAMS PER 7000 HOURS CRITICAL The upper graph shows the number of unplanned automatic reactor scrams per 7,000 hours0 days <br />0 hours <br />0 weeks <br />0 months <br /> critical (as defined in INPO's 12/93 publication " Detailed Descriptions of Interna-tional Nuclear Power Plant Performance Indicators and Other Indicators") for Fort Calhoun Station. The lower graph shows the number of unplanned automatic reactor scrams that occurred during each month for the last twelve months.

The year-to-date station value was 0.0 at the end of February 1996. The value for the 12 months from March 1,1995, through February 29,1996 was 1.0. The value for the last 36 months was 1.21.

The 1996 Fort Calhoun goal for this indicator is 0. The Year 2000 lNPO industry goal is a maximum of one unplanned automatic reactor scram per 7,000 houis critical. The indus-try upper ten percentile value is approximately 0.48 scrams per 7,000 hours0 days <br />0 hours <br />0 weeks <br />0 months <br /> critical.

Data Source:

Monthly Operating Report & Plant Licensee Event Reports (LERs)

Accountability:

Chase Trend:

Needs increased Management Attention (Above FCS Goal) 29

m SafetySystem Actuations (INPO Defrntion)

+ FCS Goal (0)

+ IndustryUpper10 Percentile (0) 3..

2__

1 1

1 1_.

0 0

0 0

0 0

0 0

0 0

0 0

0 i

92 93 94 Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb 95 96 UNPLANNED SAFETY SYSTEM ACTUATIONS -(INPO DEFINITION)

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

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

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

The 1996 Fort Calhoun goal for this indicator is 0.

Data Source:

Monthly Operating Report & Plant Licensee Event Reports Accountability:

Skiles/Fo!ey/Ronning Trend:

Positive 30

m safety System Actus.tions (Inc Derrution)

, FCS Goal (0)

CnticalHours 12-Month RunningTotalSSAs(MtcDefinition) 10

__300

[5

.700 g

Odage

_600 8a 6._

__500 4

E

__400 :E u

4 W

N 4.

3

..300 g

__200 2.

_ = = = = : -

1

.100 lI:,I:::

0 l l : : : : : ;

l_:_;-

0 i -

92 93 94 95 JFMAMJJASONDJFMAMJJASONDJF 1994l 1995l T9 UNPLANNED SAFETY SYSTEM ACTUATIONS -(NRC DEFINITION)

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

An unplanned safety system actuation occurred in December 1993 when the main turbine and reactor tripped during Electro-Hydraulic Control pump start testing. Also, there was an unplanned SSA during the month of February 1994 when supentisory relay 86B/CPHSS failed, which resulted in a concurrent turbine and reactor trip.

There have been no unplanned safety system actuations in the last 12 months. The 1996 Fort Calhoun goal for this indicator is 0.

Data Source:

Monthly Operating Report & Plant Licensee Event Reports (LERs)

Accountability:

Skiles/Foley/Ronning Trend:

None 31

m Gross Heat Rate Year-to-Date Gross Heat Rate l Good l Fort Calhoun Goal 10.75 p

10.5 10.25 _

m223

,2,

.g m ve o-

---

e o

o 10.

cyci. ts

)

4 n vu.ung I

9.75 _

oui.e.

9.5 9.25 92 93 94 95 Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb j

1996 GROSS HEAT RATE This indicator shows the Gross Heat Rate (GHR) for the reporting month, the year-to-date GHR, the goals and the year-end GHR for the previous three years.

The gross heat rate for Fort Calhoun Station was 10,037 for the month of February 1996.

The 1996 year-to-date GHR was 10,031 at the end of the month.

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

The 1996 Fort Calhoun year-end goal for this indicator is 10,166.

Data Source:

Bostelman/Willett (Manager / Source)

Accountability:

Chase /Skiles Trend:

None 32

l l.

Monthly Thermal Performance g

,12. Month Average

+ Year-toDate Average MonthlyThermalPerformance

+ FortCalhounGoal(99.6%)

i

+ Year 2000 lhPO Industry Goal (99.5%)

lg o_. Industry Upper 10%(99.7%)

1 1

l 100 %.

I c

=

c

=

c c

=

c

=

c a

e o

e e

e a

e u

43 o

o o

C 0

0 0

0 0

0 0

0 0

0 j

l 99%.

j l

98%

Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec l '"S i l

THERMAL PERFORMANCE l

This indicator shows the Thermal Performance Value for the reporting month, the year-to-date average monthly thermal performance value, the Fort Calhoun goals, the 1996 INPO industry goal and the approximate upper ten percentile value.

l l

The thermal performance value for February 1996 was 99.04. The year-to-date average monthly thermal pe:1ormance value was 99.10, at the end of the month. The average monthly value for the 12 months from March 1,1995, through February 29,1996, was 99.35%.

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

and the industry upper 10 percentile value is approximately 99.9%.

Data Source:

Skiles/Naser(Manager / Source)

Accountability:

Skiles/Gorence Trend:

Adverse i

33 l

'l

-+ ThermdQ418

_a_ Fat Odhau11485MWGud Te6!)ec1500MWUmt 1900.

140 148.

1497.

j b

lE 1485::==,,=========================

14M.

1483.

1412 1 2 3 4 5 6 7 8 9101112131415161718192)2122232425 2 272 29 DAILY THERMAL OUTPUT The thermal output graph displays the daily operating power level during February 1996, the 1500 thermal megawatt average technical specification limit, and the 1495 thermal megawatt Fort Calhoun goal.

Bostelmari Willett (Manager / Source)

/

Data Source:

Accountability:

Chase /Short Trend:

None 34

__, _ Number of Equipment Forced Outages (Monthly)

GOOO

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

+ FortCahounYear-EndGoals(0.2) y 2_.

1 c

=

c o

0 93 94 95 Jan Feb Mar Apr May Jun Jul Aug Sep oct Nov Dec EQUIPMENT FORCED OUTAGES PER 1,000 CRITICAL HOURS The equipment forced outage rate per 1,000 critical hours for the 12 months from March 1,1995, through February 29,1996, was 0.266. The year-to-date rate per 1,000 critical hours for the months from March 1995 through February 1996 was 0.0.

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

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

The 1996 Fort Calhoun year-end goal for this indicator is a maximum value of 0.20.

Data Source:

Monthly Operating Report & Plant Licensee Event Reports (LERs)

Accontability:

Chase /Skiles Trend:

Needs increased Management Attention 35 l

____m m _... _. _ _ _.. _. _ _ _ _... _. _ _ _. _ _..........

o e

~t--

' W'M A

+

18.

16.

14.

f 12.

I 10 l d

~

8.

?.

?.

2.

)

0 0

N D

J.95 F

M A

M J

J A

5 O

N D

J.96 F

A gelN e rm al Use initial In s tallette n 2.6 %

60%

f a c tu rin g Defect M alatenance Cther D evices E n gin ee rin gID e sig n

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 May 1994 through October 1995). Fort Calhoun Station reported a higher failure rate in 5 of the 87 component categories (valves, pumps, motors, etc.)

during the past 18-month CFAR period. The station reported a higher failure rate in 5 of the 173 application categories (main steam stop valves, auxiliary / emergency feedwater pumps, control element drive motors, etc.) during the past 18-month CFAR period.

The pie chart depicts the breakdown by INPO cause categories (see the " Definitions" section of this report for descriptions of these categories) for the 40 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 69 failure reports were submitted to INPO with discovery dates within the 18-month CFAR period.

Data Source:

Skiles/ Frank (Manager / Source)

Accountability:

Skiles/ Dowdy Trend:

None 36

l Components with more than One Fellure

1. Components with more than Two Failures l

15 _

3 7 l

10.

7 6

6 5

4 4

3 3

3 3

3 1

1 1

?

0-Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb REPEAT FAILURES The Repeat Failures Indicator (formerly called the " Maintenance Effectiveness Performance Indicator) was I

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).

l 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 May 1994 through October 1995) and the number of NPRDS repostable components with more than two failures during the 18-month CFAR period.

During the last 18 month CFAR period, there were 5 NPRDS components with more than one failure. One of these 5 NPRDS reportable components had more than two failures. Recommendations and actions to l

correct these repeat failures are listed in the Biannual CFAR. The description and tag numbers of the l

NPRDS reportable components with more than one failure are listed below:

l Raw Water Pump AC-10A l

(

Reactor Protection System Channel'A' Axial Power Distribution Trip Calculator Multiplier / Divider j

Module Al-31 A-AW15-B4,5 Reactor Coolant Pump Motor RC-3D-M Containment Cooling Coil VA-88, CCW Outlet Valve V/P-403C (> 2 failures)

Control Element Drive Mechanism, RC-10-08

(

l Data Source:

Skiles/ Frank (Manager / Source)

Accountability:

Chase Trend:

None 1

37

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

+ Year-to-Date Cumulative Radioactive Waste Buried l GOOD l

_o__ Fort Calhoun Goal (600 cu.ft.)

i V

600D0

- c o

500.00 __

400.00 __

N I 300.00 __

iu 200.00 __

100.00 040 Jan Feb Mar Apr May Jun Jul Aug Sep oct Nov Dec 1996 VOLUME OF LOW-LEVEL RADIOACTIVE WASTE This indicator shows the volume of the monthly radioactive waste buried, the cumula-tive year-to-date radioactive waste buried, the Fort Calhoun and INPO goals, and the approximate industry upper 10%.

Cu.Ft.

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

Volume of solid radwaste buried during current month 0

l Cumulative volume of solid radioactive waste buried in 1996 0

1 Amount of solid radwaste in temporary storage 184.1 l

The 1996 Fort Calhoun goal for the volume of solid radioactive waste (buried) is 600 cubic feet. The Year 2000 INPO industry goal is 45 cubic meters (1,589 cubic feet) per year.

The industry upper ten percentile value is approximately 27.33 cubic meters (965.3 cubic feet) per year.

Data Source:

Chase /Breuer (Manager / Source)

Accountability:

Chase /Gebers 1

Trend:

None SEP54 38

m SecondarySystem CPI

+ 12-Month Average j 0000 l

+ Fort Calhoun Goal (1 A) 1.6..

l f 1.5..

1A 1.3

-c y

ll 1.2 V

l l

l I

l l

1 l

l l

l Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb 1996 SECONDARY SYSTEM CHEMISTRY Criteria for calculating the Secondary System Chemistry Performance Index (CPI) are:

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

per day.

The CPI for February 1996 was 1.23. The 12-month average CPI value was 1.28 at the end of the month.

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

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

Data Source:

Spires /Reneaud (Manager / Source)

Accountability:

Spires Trend.

Positive due to performance better than goal 39

CHEMISTRY ACTloN LEVELS EXCEEDED l

Event Days + Average Event Days Lunt j 4

3.5 3

2.5 2

8 8

8 8

8 8

8 3

3 8

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 levelis exceeded. The parameter action levels are delineated in Chem-istry procedure CH-AD-0003, Plant System Chemical Limits and Corrective Actions.

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

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

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

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

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

Two events occured in which hydrazine was low out of specification in the feedwater sys-tem due to problems with the chemical injectitr system.

Data Source:

Chase / Spires Accountability:

Spires Trend:

None 40

l l

Goal 5.00 4.00 3.00 g

1 8z i

3t 2.00 1.00 l

l l

0.00 l

Apr May Jun JJ Aug Sep oct Nov Dec Jan Feb l

1996 l

l l

PRIMARY SYSTEM LITHlUM % HOURS OUT OF LIMIT The Primary System Lithium Percent Hours Out of Limit indicator tracks the hours per l

month that the primary system lithium is out of specification.

l The Primary System Lithium Percent Hours Out of Limit was 0.0% for the month of Febru-ary 1996.

The 1996 Fort Calhoun monthly goal for this indicator is a maximum of 5% hours out of l

limit t

l l

t l

l i

Data Source:

Chase / Spires (Manager / Source)

Accountability:

Spires Trend:

None 43

i l

i l

i l

l l

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

42

+ Actual

_e_. Revised Budget i

Original Budget

+ Plan 2_

4.

3.75._

3.5.

z 3.25 _

i e

g 50 2.75 __

g 2.5 __

225.

1 2

001 D92 D03 004 D95 J96 F M A M J J

A S O N D D96 D97 008 D99 Months i

CENTS PER KILOWATT HOUR The purpose of this indicator is to quantify the economical operation of Fort Calhoun Station.

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

The December 31 amounts are also shown for the prior years 1991 through 1995. In l

addition, the report shows the plan amounts for the years 1996 through 1999 for refar-ence. The basis for the dollars are the Nuclear Long Range Financial Plan and the 19M Corporate Planning and Budget Review. The basis for the generation is provided by Nuclear Fuels.

l The 12-month average unit price (3.16 cents per kilowatt hour for January 1996) aver-l aged above the revised budget due to 12-month generation not meeting the budget ex-pectations.

l l

Data Source:

Lounsberry/Jamieson (Manager / Source) l Accountability:

Lounsberry Trend:

Needs Management Attention i

I 43

g NuclearServicesDMslon O Prmiuction Wneering DMsion g NuclearOperationsDMalon j

g Totair&rlear 4

i 800__

rs4 7,,

727 727 721 7U 700__

ser l

600..

500__

ds7 4n 4s2 a

m n

m 400_

i 300__

)

I 200 _

ne ne ni l

tu 1

tw tu m

m u

,a,

100__

O I

I I

I I

I i=-

1 I

f Jan-93 Jan-94 Jan-95 Mar-95 Jun-95 Sep 95 Dec-95 Feb.96 Jun-96 ActualStdfing Level l l

STAFFING LEVEL l

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

L 1

The acutal staffing levels 1995 and 1996 are given below. The figures are current as of j

March 15,1996.:

l l

Authorized Staffing l

i 1995 1996 l

439 413 Nuclear Operations Division l

185 151 Production Engineering Division l

115 104 Nuclear Services Division l

739 667 Total i

1 1

l

)

Data Source:

Ponec \\Balis (Manager) j Accountability:

Ponec j

Trend:

None SEP 24 44 l

i

Spare Park wentoryValue ($ MHilon) 16.3..

16.2..

\\

16.1 __

$ 16..

8 5

Eo 5 15.9 __

2 a

15.8 _.

15.7..

15.6 Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb 1996 SPARE PARTS INVENTORY The spare parts inventory value at the Fort Calhoun Station at the end of February 1996 was reported as $15,685,682.

Data Source:

Steele/Huliska (Manager / Source)

Accountability:

Willrett/McCormick Trend:

None*

45

J 4

)

l I

l i

8 i

4 1

DIVISION AND l

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

46

i b

1' e corrective Maintenance e Preventive Maintenance Non-Corrective /Pla nt im prove ments + Fort Calhoun Goal 1000 777 834 752 789 771 800

. 687 668 671 726 i

Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb l1995 l Non-Outage Maintenance Work Order Backlog l l1996l

}

l 1

l g TWEl To'ai Mwos g

43%

if 3

4D 2D

.2=

,2H e,3 y

muni

.,M MWos 0._

Y t

DD DDD com eti 1

2 3

4 5

on omte 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 ano priority. The 1996 goal for this indicator is 400 non-outage corrective maintenance MWOs. The current backlog of corrective MWOs is 428. To ensure that the MWO backlog is worked in a timely manner, non-outage maintenance completion goals have been established as follows:

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

Chase /Schmitz (Manager / Source)

Accountability:

Chase /Faulhaber Tiend:

Adverse SEP 36 47

i Ratio of Preventive to Total Maintenance l

100% -_

]

90%.

j 80%._

70%_

60%

50% __

n%

i i

i i

i i

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

m Preventive Maintenance items Overdue Fort Calhoun Goal 2%.

V 1%._

0*4 l

l t

-- l -

i i

1-l 1

I l

l Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb l1996l 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 56.64% for the month of February 1996.

The lower graph shows the percentage of scheduled preventive maintenance items that are overdue. During February 1996, 504 PM items were completed.

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

Data Source:

Chase /Schmitz/ Montgomery (Manager / Sources)

Accountability:

Chase /Faulhaber Trend:

None SEP 41 & 44 48

4 I

l m Rework as identifed by Craft o__ Fort Calhoun Goal (<3%)

l j

6%.

i 8

s.s s i

}

5%.

1 i

I j

3 4%_

.e s i

8 l

lE

s. s s.e s

$ 3% __

24%

2 s

?

(

2.s s e

1 g

l j 2%.

i ll l;;lii

{

n*4 i

l l

i Mar Apr May Jun Jul Aug sep Oct Nov Dec Jan Feb l1996l PERCENTAGE OF TOTAL MWOs COMPLETED PER MONTH IDENTIFIED AS REWORK This graph indicates the percentage of total MWOs completed per month identified as rework. Rework activities are identified by maintenance planning and craft.

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

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

Data Source:

Faulhaber/Schmitz (Manager / Source)

Accountability:

Chase /Faulhaber Trend:

Improving 4g

m Maintenance overtime

+ 12-Month Amrage Maintenance Overtime IGoooI o_. Fort Calhoun "On-Line"(bal(10%)

I I

45%..

1 P 40 %

35%

30%._

25%-

20%._

15%._

l[

11

'l 1;

n' 10%._

e e

e e

e e

5%._

0%

i i

i

_4_ - i i

Mar Apr May Jun Jul Aug Sep oct Nov Dac Jan Feb l1996l MAINTENANCE OVERTIME The Maintenance Overtime Indicator monitors the ability to perform tne desired mainte-nance activities with the allotted resources.

i The percent of overtime hours with respect to normal hours was repoded as 6.00% for the month of February 1996. The 12-month average percentage of overtime hours with respect to normal hours was reported as 14.0 % at the end of the month.

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

Data Source:

Chase /Schmitz (Manager / Source)

Accountability:

Chase /Faulhaber Trend:

None 50

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

I Human Performance CRs(Maintenance) 18 __

1 16 __

14..

13 3 12 __

E 10 __

s i

j 8_

6__

No information Available for the 4

, Months of Sept. and Oct.

2 O

i j

j i

i i

Sep Oct Nov Dec Jan Feb PROCEDURAL NONCOMPLIANCE INCIDENTS (MAINTENANCE)

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

Data Source:

Faulhaber Accountability:

Chase /Faulhaber Trend:

None SEP 15,41 & 44 l

51

_. ~.

. - - - - ~.

i A

I g% Scheduled Activities Compieted O% Emergent Activities 100.0% _-

90.0 %

86.5 %

85.1 %

83.2%

$0.1%

80.0% _

70.0% -

60.0% _

50.0% -

40.0% _

30.0% _

4-1.9%

3.4%

20.0% __

10.0% -

0.0% _

i i

i-i w

Oct Nov Dec-96 Jan-96 Fe b-96 DAILY SCHEDULE PERFORMANCE PERCENT OF SCHEDULED ACTIVITIES COMPLETED This indicator shows the percent of Integrated Plant Schedule activities completed on schedule. All work groups and activities are included.

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

The 1996 Fort Calhoun monthly goal for completed scheduled maintenance activities is 85%.

Data Source:

Chase /Schmitz (Manager / Source)

Accountability:

Chase /Faulhaber Trend:

None SEP 33 1

52

I e %cfitxastheinUneOmntstryhetnmutsareInoperatie GOOD o._1996 RrtOdun(bal(10%)

l Y

l 2st.

2f4__

1 22 5.

20 5_

18E.

16 %_

if4..

12 5.

j 10 1.

85.

61_

Uk__

\\

2E_

E "I

I I

I I

I I

I I

I I

I er Apr Wy Jm Jd Aug Sep Oct Nw Dec Jan Feb 1996 IN-LINE CHEMISTRY INSTRUMENTS l

OUT-OF-SERVICE This indicator shows the percentage of hours the in-line chemistry system instruments are inoperable for the reporting month. The chemistry systems involved in this indicator include the Secondary System and the Post Accident Sampling System (PASS).

At the end of February 1996, the percentage of hours the in-line chemistry system instru-ments were inoperable was 7.01%. The following instruments were out of service during the month:

CE-1547A - Primary Water Storage Tank Specific Conductivity: awaiting ECN for replacement.

CE-1592 - Vendor Supplied Water Conductivity; waiting ECN to replace sensor.

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

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

Data Source:

Chase /Reneaud (Manager / Source)

Accountability:

Chase /Skiles Trend:

None 53

i l

l Waste ProducedTach Month (Kllograms)

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

_ Fort Calhoun Monthly Average Gaal(150 kilograms)

1. Federal & State Monthly Limit (Max. of 1,000 kg) 1000:

x x

x x

x x

x x

x x

x 800.

l

, 600__

E 5

E 400_

200.

o o

51.5 0

e 9

9 9

e n

0 0

0 0

0 l

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

During the month of February 1996,0.0 kilograms of non-halogenated,0.0 kilograms of halogenated and 0.0 kilograms of other hazardous waste was produced. The total haz-ardous waste produced during the last 12 months is 470.6 kilograms.

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

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

4 Data Source:

Chase /Shubert (Manager / Source)

Accountability:

Chase / Spires Trend:

Positive 54

i i

m Contaminated Radiation Controlled Arsa l GOOD l j

_e__ Fort Calhoun Goal (10%)

j l f 10% -- c

=

=

=

=

=

=

=

=

=

=

=

i

l l

9%-_

]

fe d i

i M

I I

l l

l l

1 1

I l

l l

l Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb l1996[

i l

i 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 February 1996, the percentage of the total square footage of the RCA that was contaminated was 9.4%.

Data Source:

Chase /Gundal(Manager / Source)

Accountability:

Chase /Gebers Trend:

Positive SEP54 i

l 55 j

9 Identified PRWPs (Yeat to Date)

Good l e

Fort Calhoun Goal (<20) 20 18._

16 __

14.-

E 12.

1 10 b

8__

g 6__

A 4..

2 0

0 0

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

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

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

During the month of February 1996, there were O PRWPs identified.

There have been 0 PRWPs in 1996.

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

Data Source:

Chase /Cartwright (Manager / Source)

Accountability:

Chase /Gebers Trend:

None SEP 52 56

....~

[ j Documents Scheduled for Review g Documents Reviewed g Documents Overdue 300_.

250.

200.

~~

150.

~

100_

i 50.

O__

i i_

q Mar Apr May Jun Jul Aug sep Oct Nov Dec Jan Feb 1996 DOCUMENT REVIEW This indicator shows the number of completed, scheduled, and overdue (greater than 6 months past the scheduled due date) biennial reviews for the reporting month. These document reviews are performed in-house and include Special Procedures, the Site Se-curity Plan, Maintenance Procedures, Preventive Maintenance Procedures, and the Op-erating Manual.

During February 1996, there were 292 document reviews scheduled, while 27 reviews were completed. At the end of the month, there were 10 document reviews more than 6 months overdue. There were 7 new documents initiated during February 1996. Begin-ning in September 1995, these figures include PED and NOD procedures.

Data Source:

Chase /Plath Accountability:

Chase /Skiles Trend:

None SEP 46 57

. ~. -

g System Failures a Non-System Failures sr 35..

30.

25 __

31 31

)

20.

e e

s 3

3 Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan Fe b LOGGABLEIREPORTABLE INCIDENTS (SECURITY)

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

During the month of February 1996, there were 19 loggable/ reportable incidents identi-fied. System failures accounted for 84% of the loggable/ reportable incidents. The micro-wave system failures during this reporting period have been discussed with the respon-sible craft and the security system engineer. MWRs have been initiated to address these problems. Non-system failures consisted of one (1) lost / unattended security badge, one (1) visitor control incident, and one (1) vital area door incident, which was due to exces-sive air pressure.

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

i Data Source:

Sefick/Woerner (Manager / Source)

Accountability:

Sefick Trend:

None SEP 58 58

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

+ Fort calhoun Goals for >1-cycle and >6 months old 7..

Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb 1996 TEMPORARY MODIFICATIONS This indicator provides information on the number of temporary modifications greater than one fuel cycle old requiring a refueling outage (RFO) for removal and the number of temporary modi-fications removable on-line that are greater than six months old. The 1996 Fort Calhoun monthly goals for this indicator are zero. However, one temporary modification (BAST level indication) has been approved by management to exceed these goals due to cost effectiveness consider-ations (reference PED-STE-94-042).

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

There are currently no temporary modifications that are greater than one-fuel cycle old requiring a refueling outage to remove. In addition, at the end of February 1996, there were 4 temporary modifications installed that were greater than six months old that can be removed on-line. These j

were: 1) Localindication for BAST CH-11A and CH-11B, in which Licensing sent FLC 94-001 to the NRC 6/27/95 for approval; 2) HE-3 Crane safety line, which is awaiting completion of ECN 95-054, scheduled for completion 2/96. 3 ) "A" Channel RPS VHPT capacitor, which is awaiting installation of MR-FC-95-010, (1996 on-line mod); 4) RC-3D cover gasket pressure indicator which is awaiting installation of ECN 96-058, scheduled for completion 7/96.

At the end of February 1996, there was a total of 23 TMs installed in the Fort Calhoun Station.

9 of the 23 installed TMs require an outage for removal and 14 are removable on-line. In 1996, a total of 5 temporary modifications have been installed.

Data Source:

Skiles/ Turner (Manager / Source)

Accountability:

Skiles/Gorence Trend:

Continued Management Attention is Needed SEP 62 & 71 59

m Total Modification Packages Open

+ Fort Calhoun Year-End Goal 100_.

90 -

80.

j O'~

^

~

o 60 _

50 _

40.

30 _

20.

10.

)

0 l

1 93 94 95 Jan Feb Mar Apr May Jun Jul Aug sep oct Nov Dec 96 OUTSTANDING MODIFICATIONS This indicator shows the total number of outstanding modifications (excludino outstandino modifications which are proposed to be cancelled).

Reporting Cateaorv

'93

'94

'95

'96

'97

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

0 0

1 0

0 1

Mod. Requests Being Reviewed 0

0 0

3 0

0 3

Design Engr. Backlog /In Progress 0

0 0

21 1

11 33 Construction Backlog /In Progress 5

0 11 10 0

0 26 Design Engr. Update Backlog /in Progress 0

3 5

0 0

0 8

Totals S

3 16 34 1

11 70 (Outage + OnLine)

(3+2)

(0+3) (7+9) (21+13) (0+1) (11+0)

(42+28)

At the end of February 1996,2 modification requests have been issued this year and 1 modification request has been cancelled. The Nuclear Projects Review Committee (NPRC) 1 has conducted 13 outstanding modification request reviews this year. The Nuclear Projects Committee (NPC) has completed 4 outstanding modification request reviews this year.

\\

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

Data Source:

Jaworski/ Walling (Manager / Source)

Scofield/Lounsberry (Manager / Source)

Accountability:

Scofield/Skiles Trend:

None 60

80..

j EARS Requiring Engineering Closeout - Not in Closeout j

60 -

g sE O DEN 40.

20 -

,O,O, M,M,,E, 0

,O

, I- -)

r' q

}

Dec Jan Feb Dec Jan Feb Dec Jan Feb Dec Jan Feb 0 3 Months 34 Months 612 Months

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

l 20 _

-t Prlority 0 Prlority1 Priority 2 Priority 3 Prlority 4 Priority 5 Priority 6

}

l,

, Priority 1 & 2 Priority 3

...o... Total Open EARS l 3

}

200__

G..-...g.......g.....-G......g, l

100_.

""**U"**"U"*".a.~..-o"'C "U"*"*

t Mar Apr May Jun Jul Aug sep oct Nov Dec Jan Feb 1995 1996

{

30 EARS 39 EARS l

Requiring Resolved 26 Omdue j

Res po ns e and in 63 EARe en Repenses 4

68.9%

Clo s ec ut Schedule e s j

z e.a s

)

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

4 Total EAR breakdown is as follows:

l l

EARS opened during the month 14 j

EARS closed during the month 7

{

Total EARS open at the end of the month 119 I

4 j

Data Source:

Jaworski/Livingston (Manager / Source) l Accountability:

Skiles/Jaworski l

Trend:

None SEP 62 61 l

i

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

e e

10 9 tti gg 0-. M onths C LO SEO UT DEN

. *4 2

ECN Status -Overall Backlog 72

'l 250.

~ LLLLLL

• • "*[ Sep Oct Nov Dec Jan Feb Design Engineering 250.

)

Me hs b

.4 N-9%

M onths E-

>0 M onths

• B I,. L. L I,_ I,. -

Sep Oct Nov Dec Jan Feb System Engineering 250.

200_

12 2 g

22 o

R 88

• [

Sep Oct Nov Dec Jan Feb Procurement / Construction 250.

,,,f,,,,

e.s /n.,

200 kLLL LL 6 e'eS "

Sep Oct iby Dec Jan Feb Drafting / Closeout ENGINEERING CHANGE NOTICE STATUS Data Source:

Jaworski/Livingston (Manager / Source)

Accountability:

Jaworski/Skiles Trend:

None SEP 62 62

l FCT PE DC TYPE P rio rity 10 0 Pr it TM Open Ms = M Total Open ECNs = 544 3a sa%

O DEN. Clo secut or Draftirg Not Cornplete 2s 24 5 Msintenance/ Construction /Procuremert mrk Not Complete P rio rity P rio rity 888 E System Engineering Response, Confirmation Not Cornplete E DEN Engineering Not Complete sep oct g6 aress Fet>st 71%

a u.

27.

=a 2a 3#

250.

so P rio rit y

,,,,, y Sep Od Itv Dec46 Jan46 Fet>06 P,"'Y Substitute Replacement item EENs Open us 100-s 80.

77 7s 7:

32 PyY Sep oct Nov Dec.95 Jan 96 Fets96 p,,,

Document Change ECNs Open 44 %

848 ENGINEERING CHANGE NOTICES OPEN Data Source:

Jaworski/Livingston (Manager Source)

Accountability:

Skiles/Jaworski Trend:

None SEP 62 63

O Administrative Control Problem

'g Licensed Operator Error g Other Personnel Error g Maintenance Problem O Design /constructionlinstallation/ Fabrication Problem g Equipment Failures 2..

1.

0 1

Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec J9n pT!F) l1996l LICENSEE EVENT REPORT (LER) ROOT CAUSE BREAKDOWN This indicator shows the LERs by event date broken down by Root Cause Code for each of the past twelve months from February 1,1995, through January 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 was One event in December 1995 that resulted in an LER.

Data Source:

Tills /Cavanaugh (Manager / Source)

Accountability:

Chase Trend:

None 64

-. -. ~.

i O Total Requalification Training Hours g simulator Training Hours 4

E Non-Requalification Training Hours g Number of Exam Failures 1

i 40 __37

)

34.5 35 i

34 35 32 32

+

30 __

=*

25 1

1 20 __

y 16 4

4 15 "

1.5 12 12 10 J

8 8

)

5

.5 5

l 4

5 3

2.5 3

3 O

O O

O O__

i l

l l

i i

i Cycle Cycle Cycle Cycle Cycle

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

• • Note: Includes 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> 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 APO/EOP verification & validation, INPO commitments, GET, Fire Brigade, Safety Meetings, and Division Manager lunches.

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

Data Source:

Conner /Guliani(Manager / Source)

Accountability:

Conner /Guliani Trend:

None SEP 68 65

a e

g SROExams Administered O SRO Exams Passed O RO Exams Administered g RO Exams Passed 10.

=.

5.

O Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb l1995l l1996l LICENSE CANDIDATE EXAMS This indicator shows the number of Senior Reactor Operator (SRO) and Reactor Opera-j tor (RO) quizzes and exams taken and passed each month. These intemally adminis-tered quizzes and exams are used to plot the SRO and RO candidates' monthly progress.

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

Data Source:

Conner /Guliani(Manager / Source)

Accountability:

Conner /Guliani Trend:

None SEP 68 66

s g Open irs >6 Months Gd

, OpenSignificantIRs j

+ TotalOpenIRs 600.

500.

400..

3 300_

284 gy, 249 228 29 200_

ss y,

Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan Fieb 1995l 1996l OPEN INCIDENT REPORTS This indicator shows the total number of Open irs, irs greater than 6 months old, and the number of open significant irs.

Also, at the end of February 1996, there were 340 open irs. 311 of these irs were greater than 6 months old. There were 99 Open Significant irs at the end of the month.

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

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

Data Source:

Conner /Plott (Manager / Source)

Accountability:

Andrews/Gambhir/Patterson Trend :

None 67

l o MWM s NWNk 1

m.

m 749 700.

ED pMogns 800.

38s S/*m ass BW=U Rrnr e/.

Ruts i

500-1 2r/.

1e%

/.

~

NRMEW 41 %

g, 0

i i

i i

itw Dec

.hn06 Ri>G6 MWO PLANNING STATUS (CYCLE 17 REFUELING OUTAGE)

)

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

- Parts Holds - Planning Complete, Awaiting Parts

- System Engineering Holds - Awaiting System Engineering input to Planning

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

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

Data Source:

Chase /Schmitz (Manager / Source)

Accountability:

Chase /Faulhaber Trend:

None SEP 31 68

i j

1996 Outage Projects Status Report

~

g LastMonth a Ms Month 10o O MN i

so _.

i so..

]

• ~

~

i 60..

sr

'8 st so..

i i

at 4o _

as as

~

n" u

o_

4 i

i 4

3 I

l 3

I I

E lii

!8 l

I 51 5

1 3

5 3

11 si be g

u y

g g

g Es o

i

=

j

! A 1

1 3

6

=g

}

M i

w i

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

This performance indicator shows the status of projects which are in the scope of the j

Cycle 17 Refueling Outage. SSED's goalis to have all projects completed by August 23, 1996,30 days prior to the Refueling Outage start date.

I i

Data Source:

Skiles/Swearngin (Manager / Source)

{

Accountability:

Jaworski/Boughter Trend:

None SEP 31 j

69 j

i;

-.. ~._

o e

I Basehne Schedule fo r PRC A pproval

-S-Projected /ActualSchedule forPRC Approval

- -F mal Design Pkg issued (2 F D DCP issued Pno r to 05/0795)

I To tal M o difcation Packages (23) {t2 Added After 05/0195) l 9

F 8.

I S

57.

12 h'

g.]5.

c: :

h $ 4-e{3.

lg

/...../ __ _

-_--__m i,,

__/

tr.

0 y06.5 5

5 E

5 s

PROGRESS OF CYCLE 17 OUTAGE (1996 MODIFICATION PLANNING)

(FROZEN SCOPE OF 9 OUTAGE MODIFICATIONS) i l

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

The goal for this indicator is to have all modification packages which were identified prior to May 1,1995, PRC approved by March 22,1996. 12 Modifications added after May 1, 1995, not included.

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

l Data Source:

Jaworski/ Walling (Manager / Source)

Accountability:

Gambhir/Jaworski Trend:

None SEP 31 70

i

+ Baseline Schedule for PRC Approval Projected / Actual schedule for PRC Approal 10 _ _

d

.I 5e 2

5 i

3. o.

1. }s__

ir t.

1#

t Se o o.

7__

A.

zg a:

g e__

l o.

s 1855 2/1045 3/1745 4/2155 5/26S 5 6/3055 8/455 9/855 10/1355 PROGRESS OF 1995 ON-LINE MODIFICATION PLANNING (FROZEN SCOPE OF 9 MODIFICATIONS)

This indicator shows the status of modifications approved for on-line installation during 1995. The data is represented with respect to the baseline schedule (established 1/13/

95) and the current schedule. This information is taken from the Modification Variation Report produced by the Design Engineering Nuclear group.

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

This goal was met 09/21/95.

February 1996 Modifications Added: 0 Deletec = 0 Data Source:

Jaworski/ Walling (Manager / Source)

Accountability:

Gambhir/Jaworski Trend:

None SEP 31 71

1 i

+ Baseline Schedule for PRC Approval

_,_ Protected / Actual Schedule for PRC Approval FinafDesian Package issue Total Moalfication Packages (10)(3 Added After 05/0155) 6

. x x x xug., x x x x x x x x_g_x_x_x *_x_w_3_.x._x_x_,_w_x_g.x,_xm_gy xxx xxx I

5._

E

\\

e__

l

{

j3 o.

5 2__

i 1--

0 i, ;;. ;;;;i.ii;;

i;,i ;;;i; ;;

;; i; i

i i 6d6S5 7G1S5 8G545 94935 11445 12445 1/1256 2M646 3G2S6 l

PROGRESS OF 1996 ON-LINE MODIFICATION PLANNING (FROZEN SCOPE OF 6 MODIFICATIONS)

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

The goal for this indicator is to have all modification packages which were identified prior to May 1,1995, PRC approved by March 25,1996.1 Modification added after May 1, t

1995, not included.

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

Data Source:

Jaworski/ Walling (Manager / Source)

Accountability:

Gambhir/Jaworski Trend:

None SEP 31 72

'W s

d:.

1 4

1 9

i ACTION PLANS i

4 i

I I

4 I

I 73

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

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

l

. Fuel Reliability Index (page 14) f

. Thermal Performance (page 33)

. Maintenance Workload Backlogs (page 47) l l

THERMAL PERFORMANCE IMPROVEMENT ACTION PLAN A.

PROBLEM STATEMENT-Plant Heat Rate as measured by the INPO Performance Indicator has shown a decreasing performance trend. This is based on decreases seen in total station electrical output, turbine first stage pressure, condenser inlet / outlet differential temperature, and condenser vacuum compared to previous operating cycles.

Another loss is suspected as a result of non-optimum operation of the condensate cooler which controls cooling water to the generator hydrogen coolers, generator i

stator coolers, and generator field rectifier banks. Operation of this cooler with temperatures below optimum values rejects excessive amounts of thermal energy i

to the river and decreases overall plant efficiency.

]

B.

GOALS

1. Improve Plant Heat Rate as measured by the INPO Performance Indicator above l

the OPPD goal of 99.6%.

l

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

l

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

74

f A

3 C.

Action (s) Reauired to Accomolish Goals Reso.

Date Comments i

1.

Review the calculations utilized to justify the power l

increase from 1420 MWT to 1500 MWT as it relates to S.E.

10/30/95 In Progress

~

secondary plant performance and the condenser evaluation completed during the 93/94 Power Upgrade j

Study.

{

2.

Evaluate the temperature correction factor utilized to l

correct actual plant heat rate data to design conditions for S.E.

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

I 3.

Review current operations procedures for condensate cooler operations. Implement changes required to

[

ensure a minimum amount of heat is rejected to the river implement changes to while providing sufficient protection for operating S.E.

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

approved 10/11/95.

i 4.

Continue to evaluate operating plant systems to t

L determine components operating at less than optimum Currently, S.E.

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

Ongoing reviewing all plant l

station efficiency parameters on a daily

}

basis.

I i

75

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

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

Ongoing Currently, working performance, development of better computer models to toward another program predict and quantify equipment performance impacts on that will provide station efficiency.

computer analysis and troubleshooting assistance.

6.

Complete EAR 95-077, Evalaation of Best Method of Measuring Circulating Water Flow DEN /SYE Complete EAR response received 10/30/95 7.

Implement corrective actions as outlined in EAR 95-077 l

using the ECN process DEN /SYE Later Date to be determined by NPRC l

I i

76 i

1 1

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

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

g.

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

SHORT TERM (CYCLE 16 OPERATIONS)

IIE!d ACTION BESE DATE DUE STATUS 1.

Evaluate replacement of two-mecron fHter in CVCS with one-Holthaus Cornpleted Complete.1/4/96. Filter replacement will micron fHter.

result in irnproved particulate removal 01/04/96 and consequently lower dose rates.

1 a.

Install one-micron Alters in CVCS 01/31/96 Completed 03/13/96 2.

Evaluate benetts ofincreasing letdown flow.

Holthaus/Spilker Completed Previously evaluated in Radiological 01/13/96 Analysis95-005, which supports increased letdo'im flow.

3.

Evaluate need for and e5ectiveness of more frequent of Holthaus Completed Complete. 01/04/96. Rosin bed effeceve purificaton and caton ion beds.

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

77

l f

t I

f IIEM ACTION RESP.

Date Due STATUS 3a.

Replace resin beds during Spring 1996 outage.

Spires 03/22/96 Canceled 4.

Prepare and issuc Nuclear Network request for industry Completed Complete. 01/12/96. Transmitted experience in reducing FRI.

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

}

5.

Evaluate installation of silver morderute iltration system Holthaus/ Spires Completed Received general (unclassited)

'7 for increased iodine removal.

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

6.

Identiff number of old design assemblies to be placed Completed Previously identfied eight assembles to la peripheral locations for second cycle and consider Holthaus/Guinn 01/12/96 be placed on core periphery for second I

replacement with new design assembly.

cycle.

7.

Evaluate whether these assemblies could be used for Holthaus/Guinn Completed i

more than one cycle to reduce cost.

01/19/96 j

8.

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

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

9.

Evaluate Cycle 18 preEminary pattem same as 5 & 6 Holthaus/Guinn Completed Cycle 18 preEminary pattem indicates 01/17/96 four additional assemblies would be i

required. Cost $1.0M j

10.

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

{

11.

Analyze additi,aal assembles to be procured Holthaus/ Hanger Completed Total costis $5.0M for 20 additional 01/17/96 assembles.

{

12.

Evaluated cost /benett with assumption of Holthaus/ Hanger Completed f

$10,000/ person exposure.

01/25/96 l

78 f

The action plan for Maintenance Workload Backlog (page 47) is as follows:

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

Planning Scheduled Maintenance Bulk Work f

79

--,.- - - - ~.

- ~.-

. ~ -.

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

PERFORMANCE lNDICATOR DEFINITIONS AUXE.lARY FEEDWATER SYSTEM SAFETY SYSTEM CLEAN CONTROLLED AREA CONTARENATIONS 2,1,000 PERFORMANCE DISINTEGRATIONS /94NUTE PER PROBE AREA The sum of the known (pionned and unplanned) unavailable The personnel cordaminshon everts in the clean controRed area.

hours and the estimated uneveamble hours for the auxibery This indicator tracks personnel performance for SEP #15 & 54.

had-ear system W the reporbng period divided by the critical hours for the reporting period multipiled by the number of trains CONTARANATED RADIATION CONTROLLED AREA in the auxdiary feedwater system.

The percenlege of the Redishon Controued Area, which includes COLLECTIVE RADIATION EXPOSURE the auxihery bulkhng, the redweste buildmg, and areas of the C/RP bueding, that is contaminated based on the total square CoHoctive radiation exposure is the total extemel whole-body footage. This indicator tracks perfonnance h SEP #54.

does receased by el onets personnel (includmg contractors and viellors) during a tone period, as measured by the DAILY THERMAL OUTPUT thermoluminescent dosimeter (TLD). Cosective radiation exposure is reported in units of person-rom. This indicator ThisincBeelor shows the deny core themel output as measured tracks radiologleal work performance for SEP #54.

Oorn computer point XCt 05 (in thermal megewetts). The 1500 MW Tech Spec limit, and the unmet portkm of the 1495 MW COMPONENT FAILURE ANALYS48 REPORT (CFAR)

FCS daily goal for the reportmg month are eleo shown.

SUMMARY

DIESEL GENERATOR RELIABILITY (28 Demands)

The summary of INPO categories for Fort Calhoun Station with signdcangy higher (1.645 elenderd deviations) feaure rates then This indicator shows the number of feMuros occurring for each the rest of the industry for en eighteen-month time period.

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

steem stop valves, control element motors, etc.) categones DISABLING INJURY /lLLNESS FREQUENCY RATE Failure Cause Categories are:

(LOSS TIGE ACCIDENT RATE)

AgetNormel Use -thought to be the consequence of This hecator is defined as the number of accidents for el utdity expected wear, aging, end-of4fe, or normal use.

personnel permanently assigned to the station, involving days away tom work per 200,000 men-hours worked (100 men-

+

Manufacturing Defect - a failure attributobie to inadequate years). This does not include contractor personnel. This assembly or initial quality of the responsible component or indicator tracks personnel performance for SEP #25,26 S 27, DOCURENT REVEW (BIENNIAL)

EngineeringfDesign a failure attributobie to the inadequate design of the responalble component or system.

The Document Review indicator shows the number of documents reviewed, the number of documents scheduled for Other Devices - a failure attrtbutable to a fedure or review, and the number of document reviews that are overdue misoperation of another component or system, including for the reporting month. A document review is considered associated devices, overdue if the review is not complete within six months of the assigned due date. This indicator tracks performance for SEP MaintenancelAction resuting from improper maintenance,

1. 46.

I lack of maintenance, or personnel errors that occur during maintenance activities on the component EMERGENCY AC POWER SYSTEM SAFETY SYSTEM t

PERFORMANCE Teseng Action resusing from knproper testing or personnel errors that occur during testeg activities.

The sum of tie known (planned and unplanned) unevelleble and the eshmeted unevadeble hours for the emergency AC power initial in=8=e=8aani Error. caused by knproper initial system for the reporting period devided by the number of hours installation of equipment in the reportmg period multipted by the number of trains in the emergency AC power system.

CENTS PER KILOWATT HOUR ERERGENCY DESEL GENERATOR UNii RELIABILITY The purpose of tNs indicator is to quantify the economical operobon of Fort Cohoun Station. The cents per kilowatt 1hs haeolor shoes the nurveier of smauros that were reponed durin0 the hour Indicator represents the budget and actual cerits per last 20,50. and 100 ernergency diesel generstar dernands et the Fort Ceem Simeon. Mao shoosi are Wiggw valm veich correiste to e high kAcouR hour on a twelve-month average for the current year.

d **"'**"'* ee a unirs del generators hm chried a The been for the budget curve is the approved yearty tmeget

'""""#""d*'"*"d""

The beeis k the actuel curve is the Financial and Operating n,,,

R.,ori.

80

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

- ~

. -.. ~ - _ -..

t 4

PERFORMANCE lNDICATOR DEFINITIONS and the successful test that fodows repair to verify operstWNty

1) Nieviber of Start Demands: AI valid and inadvertent start should not be counted as demands or fatures when the EDG demands, includmg al etert only demands and aN etert has not been declared operstdo again.

demands that are folkmed by load-run demands, whether by automshe or menuelinitiation. A start 4nly demand is EWRGENCY DIESEL OENERATOR UNREUABlWTY a demand M which gie emergency generator is started, but no attempt is made to load the generator.

This indlcetor measures the total unrelistduty of emergency diesel generators. In general, unrebabdity is the ratio of

2) Number of Start Failures Any feNure wthin the unsucceosful operations (starts or lood-runs) to the number of emergency generator system that prevents the generator valid demands. Total unrollabdity is a comtnnetion of start I

tom edesving apard=d toquency and vollege is classiGod unrebabiuty and lood run unreliebikty.

i as a valid stort fouure. This includes any condition identilled in the course of maintenance inspections (with ENGINEERING ASSISTANCE REQUEST (EAR) i the emergency generator in etendby mode) that deAndlely BREAMDOWN would have resuhed in a start indure if a demand had i

occurred This indicator shows a breakdown, by age and priortly of the EAR, of the number of EARS essegned to Design Engineering

3) Number of Load Run Demands: For e valid loodrun Nuclear and System Engmeeting. This indicator tracks demand to be counted, the lood-run ettempt must meet performance for SEP 862.

one or more of the fonowmg critorie:

[

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

The number of ECNs that were opened, ECNs that were completed, and open becklog ECNs awaiting cornpietion by B) A loadam test to setiety the pinnre load and duration DEN for the reporting month. This indicator tracks performance es stated in each teet's specincetions.

for SEP 862.

C) Ouier special toets h which the emergency generator ENGINEERWO CHANGE NOTICES OPEN is expeded to bc operated for et least one Nw while loaded with at heet 50% of Rs design loed.

This indicator brooks down the number of Engineering Change Nohces (ECNs) that are assagned to Design Engineering

4) Nievdser c4 LeadJtun Failures: A lood-run feture should Nuclear (DEN), System Engineering, and Maintenance. The be counted for any reason in which the emergency graphs provide date on ECN Facluty Changes open. EON i

generator does not pick up load and run as predicted Subeutute R -F-...; Items open, and ECN Document Failures are counted during any valid lood-run demands.

Changes open. This indicator tracks performance for SEP 862.

5) Exceptions. Unsuccessful allempts to etert or lood-run EQUIPRENT FORCED OUTAGES PER 1,000 CRITICAL should not be counted as vend demands or failures when HOURS they can be attributed to any of the fotowng Equipmert forced outages per 1,000 critical hours is the inverse l

A) Spuntous trips that would be bypeseed in the event of of the mean tkne between forced outages couesd by equipment an emergency failures. The mean time is equel to the number of hours the reactor is craicalin a perted (1,000 hours0 days <br />0 hours <br />0 weeks <br />0 months <br />) divided by the number B) Metfunchon of equipment that is not required during of forced outages caused by equipment fonures in that period, an emergency EQUNALENT AVAILABluTY FACTOR C) Irterdloneltermination of a test because of abnormel conditions that would not have resulted in major This indicator is defined as the ratio of groes avoumbie disesi generator demoge or repelr.

generation to groes maximum generation, expressed as a percentage. Aveliable generation is the energy that can be l

D) MeNunctkms or operating errors which would not produced if the unit is operated at the maximum power level have prevented the emergency generator from being permitted by equipment and reguistory hmitations Maximum restorted and brought to load within a few minutes.

generation is the energy that con be produced by a unit in a given period if operated conhnuously at maximurn capocay E) A failure to stort because a portion of the starting

[

system was diestned for test purpose, if fotowed by FORCED OUTAGE RATE i

a successful start wth the sterling system in its normal abgnment.

This indicator is denned as the percentage of time that the unit was unevagebio due to forced events compared to the tems Each emergency generator foBure that results in the generator planned for electrical generation. Forced events are inNures or being deciered inoperetne should be counted as one demand other unplanned conditions that require removing the unit from and one Indure. Exploratory tests during orrective maintenance service before the end of the next weekend. Forced events i

81 i

-._m mm.-

_m.. _ _ _ _ _ - _ _ _ _ _ _ _ _. _ _ _ _. _. _ _ _ _ _. _. _. _ _ _ _ _

a i

PERFORMANCE INDICATOR DEFINITIONS include start-up failures and events initiated while the unit is in Contractor personnel are not included for this indicator.

reserve shutdown (i.e., the unit is available but not in service).

IN4.INE CHEMSTRY INSTRUhENTS OUT OF SERVICE FUEL RELIABOUTYINDICATOR Total number of in-line chemistry instruments that are out-of.

This indicator is defined as the steady-state primary coolant I-service in the Secondary System and the Post Accident 131 activity, corrected for the trump uraruum contribution and Sampilng System (PASS).

normatted to a common purtAcation rete. Tramp uranium is fuel which has been depoelled on reactor core intemels from LICENSE CANDIDATE EXAMS previous defectwo fuel or is present on the surface of fuel

)

elements from the menudseturing process Steady state is This kutcolor shows the number of SRO and/or RO quizzes and defined as conhnuous opersbon for at least three days at a exams that are adminsstered and poseed each month. TNs power level that does not very more then + or -5%. Plants in&cetor tracks training performance for SEP #68.

should conect data br sus indicator et a power level above 85%,

i when poseblo. Plants tot dd not operate at steadestate power LICENSED OPERATOR REQUALIFICATION TRAINWG above 85% should cousct data for this indlcator et the highest steady-etste power level attained durin0 the month.

The totel number of hours of training given to each crew during each cycle. Also provided are the simulator training hours The donelly correction factor is the ratio of the specec volume (which are a subset of the total traeung hours), the number of of cocient at me RCS operahn0 temperature (540 degrees F., Vf non.REQUALIFICATION training hours and the number of exam

= 0.02146) divided by the specdc volume of cooient at normel failures. This indicator tracks training performance for letdown ternperature (120* F at oumet of the lendown coohng heet SEP f66.

exeenger, VI = 0.016204), which results in a density correction factor for FCS equelto 1.32.

LICENSEE EVENT REPORT (LER) ROOT CAUSE BREAKDOWN GROSS HEAT RATE ThiJ indicator shows the number and root cause code for Genes host rate is donned as the ratio of total thermal energy in Uconese Event Reports. The root cause codes are as follows:

Brulah Thermal Units (BTU) produced by the reactor to the total groes electrical energy produced by the generator in kBowatt.

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

oupervisory donciencies that affect plant programs or activities (i.e., poor pionning, breakdown or lock of HAZARDOUS WASTE PRODUCED adequate management or supervisory control, incorrect procedures, etc).

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

2) Licensed Operator Error This cause code captures waste produced by FCS each month, errors of omission /convrussion by teensed reactor operators during plant activities.

HIGH PRESSURE SAFETY INJECTION SYSTEM SAFETY SYSTEM PERFORMANCE

3) Other Personnel Error Errors of omsskm/commiseen committed by non-ilconced personnel Irwolved in plant The sum of the known (pionned and unplanted) unevailable activities.

hotss and the estmetod unavailable hours for the high pressure safety injection system for the reporting period dwided by the

4) Maintenance Problem The hient of this cause code is to atical hours * *w reportmg period mump 8ed by the number of capture the ful range of problems which can be attributed trains in the he pressure safety injection system.

In any way to programmatic deHelencies in the menenance Asumonalorganization. Activibesincludedin BfDUSTRIAL SAFETY ACCIDENT RATE INPO this cologory are maintenance, tesen0. surveNience, calibration and radiobon protechon.

This hecator is desned as the number of accidents per 200,000 merWours worked br ad utitty personnel permanently assigned 5) abrication Problem -

to the station that result in any of the foRowing This cause code covers a ful range of programmatic donciences in the areas of design, construction,

1) One or more days of restricted work (excluding the day of hetanaton, and fabrication (i.e., loss of control power due the accident);

to underroted fuse, equipment not qusNAed for the erwironment, etc.).

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

6) Equipment Failures (Electronic Piece Parts or Environmental 4telated Failures) This code is used for

3) Fatsut6es.

spurlous failures of electronic piece-parts and fatures due to meteorological conditions such as Bghtning, ice, high 82

s PERFORMANCE INDICATOR DEFINITIONS winds, etc. Generally, it includes spurious or one-time MAXIMUM INDIVIDUAL RADIATION EXPOSURE insures. Eiedric components included in tNs category are cinxd cards, reditors, bestables, fuses, capacitors, diodes, The total maximum amount of radiation received by an indMdual resistors, etc.

person working at FCS on a monthly, quarterfy, and annual besas.

LOGGA8LE/ REPORTABLE INCIDENTS (SECURITY)

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

The total number of Maintenance Work Orders that have been approved lor indueen in the Cycle 17 Refueling Outage and the MANTENANCE OVERTlWE nurrbor that are ready to work (parts staged, pienning complete, and al other paperwork ready for field use). Also included is the The percent of overtime hours compared to normal hours for number of MWOs that have been engineering holds (ECNs, meentenance. This includes CPPD personnel as wed as procedures and other miscellaneous engineering holds), parts contract personnel.

hold, (parts staged, not yet inspected, parts not yet arrived) and pionning hold Gob scope not yet completed). Maintenance Work MANTENANCE WORKLOAD BACKLOGS Requests (MWRs) are also shown that have been identrAed for the Cyde 17 Reibeing Outage and have not yet been converted This indicator shows the backlog of non outage Maintenance to MWOs VWrk Orders remaining open at the end of the reporting month.

Maintenance classincations are dellned as foBows:

NUMER OF CONTROL ROOM EQUFhENT DEFICENCES Corrective - Repelr and restoraten of equipment or A control room equiprnent deficiency (CRD) is deflned as any componards that have iniled or are malfunctioning and are not component which is operated or controRed from the Control performing their intended functen.

Room, provides indicaten or alarm to the Control Room, provides testing capabilities from the Control Room, provides Preventive - Actions taken to maintain a piece of equipment automatic actions from or to the Control Room, or provides a wtNn design operating condshons, prevent equipment faGure, pesolve Onction for the Control Room and has been identified as and extend its his and are performed prior to equipment deGcaert,le., does not perform under al conddhons as designed.

failure.

This degntion aino applies to the Aternate Shutdown Panels Al-179, Al-185, and Al-212.

Non Corrective / Plant improvements Maintenance acerties performed to implement station improvements or to A plant componert which is deficient or inoperable is considered repeir non-plant equipment.

an" Operator Work Around (OWA) Item"if some other action is required by an operator to compensate for the condRion of the Maintenance Work Priorities are defined as:

componert. Some examples of OWAs are:

Emergency - Conditions which significantly degrade station

1) The control room level indicator does not work but a local safety or availability, sight glass can be read by an Operator out in the plant; immediate Action Equipmert deficiencies which

2) A dolciert pump cannot be repeired because repiscement signincantly degrade station reliability. Potential for unit parts require a long lead time for purchase /dehvery, thus shutdown or power reduction, requring the redundant pump to be operated continuously, Operations Concern - Equipment deficiencies which hinder

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

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

4) Dolcsont plart equipmert that is required to be used during Non Essential Routsne corrective maintenance on non.

Ernergency Operating Procedures or Abnormal Operating essential staten systems and equipment.

Procedures; Plant improvement Norworrective maintenance and plant

5) System indication that provides craical informat6on during improvements.

normal or abnormal opershons.

This indicator tracks maintenance performance for SEP #36.

83 i

1

a e

PERFORMANCE INDICATOR DEFINITIONS NURSEROF ASSSED SURVEILLANCE TESTS RESULTING TNs indicator shows the status of the projects which are in the IN LICENSEE EVENT REPORTS scope of the Refueling Outage.

The number of Survemance Tests (STs) that result in Licensee PERCENTAGE OF TOTAL MWOs COWLETED PER Event Reporte (LERs) during the reporting month. This indicator MONTH IDENTIFIED AS REWORK tracks missed STs for SEP #60 & 61.

The percentage of total MWOs completed per month identMed OPEN INCIDENT REPORTS as rework. Rework activities are identmed by maintenance pionning and craft. Rework is: Any additional work required to This indcator depisys tie total number of open incident Reports corred dolceances cincovered during a failed Post Maintenance (irs),gie number ofIRs tiet are greater than six months old and Testto ensure the component / system passes subsequent Post the number of open significant irs.

Maintenance Test.

OUTSTANDBdG MDDurICATIONS PERCENT OF COWLETED SCHEDULED MAINTENANCE ACTIVITIES The number of Modecation Requests (MRs) in any state between the issuance of a Modscotion Number and the The percent of the number of G.,

2 maintenance actwines completion of the ftrowing update.

as cargared to the nurnber of scheduled maintenance activmes each month. This percentage is shown for au maintenance

1) Form FC-1133 Backlog 4n Progress. This number crafts. Aino shown are the number of emergent MWOs.

represents modillcohon requests that have not been plant Maintenance activities include MWRs, MWOs, STs, PMOs, approved during the reporting month.

caubrations, and other miscotoneous actrvlties. This indicolor tracks Maintenance periormance for SEP #33.

2) ea se m Requests Being Reviewed. This category includes PERFORMANCE INDICATOR INDEX A) Modl6 cation Requests that are not yet reviewed.

TNs indicator index is calculated kom a weighted comtunshon of ten over performance indicator values, which include Unit B) un,ser=amn Recpseats being reviewed by the Nuclear Capehmty Factor, Unit Capabibly Loss Factor, HPSI, AFW, Projects Review Committee (NPRC).

Ernergency AC Power System, Unplanned Automatic Screms, Collochve Radinhon Exposure, Fuel Reliebaty Thermal C) un,es,= san Requests being reviewed tr/ the Nuclear Performance, Secondary System Chemistry, Radiation Weste, Projects Committee (NPC).

and industrial Safety Accident Rate.

These Modecation Requests rney be reviewed several times PREVENTABLE / PERSONNEL ERROR LERs before they are approved for accomphehment or canceled Some of these un,mer.emn Requests are retumed to This indicator is a breakdown of LERs. For purposes of LER EnWnsering for rnare informsbon, some approved for evaluation, event closemcation, a " Preventable LER* is defined as:

some approved for study, and some approved for planning.

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

defined, these Modllication Requests may be approved for inappropriate action by one or more individuais). Inodoquele accomphahmert with a year assigned for construchon or they administrative controls, a design construchon, inste8stion, may be conceled. AI of these diflerent phases require review.

heleIslion, fabrication problem (involving work completed by or superveed by OPPD personnel) or a maintenance problem

3) Design Engineering Backlog 4n Progress Nuclear (attributed to inadequate or improper upkeep / repair of plant Planning has seeigned a year in which construction we be ogJipmert). Also,Rio cause of the event must have occurred completed and design work may be in progrees.

weiin approximately two years of the " Event Dete" specMed in sie LER (e.g., en event for which the cause is attributed to

4) Construction Backlogan Progress. The Construebon a problem with the original design of the plant would not be Package has been leeued or construchon has begun but considered preventable),

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

For purposes of LER event closemcation, a Torsonnel Error" LER is deflned as follows:

5) Design Engineering Update Bacidogan Progress PED has received the Modecahon Complebon Report but the An event for which the root cause is inappropriate action on drawings have not been updated.

the part of one or more individuals (as opposed to being attributed to a departmord or a general group), Also, the The above menhoned outetending mod $ cations do not include happropriate acten must have occurred within approximately modMcations which are proposed for cancellation.

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

OVERALL PROJECT STATUS (REFUELING OUTAGE) 84 l

l

____________________----------------_______________----------------_a

PERFORMANCE lNDICATOR DEFINITIONS Addhonofy, each event closamed as a " Personnel Error" should SAFETY SYSTEM FAILURES also be classmed as " Preventable." This indicator trends personnel performance for SEP ltem #15.

Safety system fouures are any events or conditions that could prevent the fulflilment of the safety functione of structures or PRIMARY SYSTEM LITHIUM % OF HOURS OUT OF LIMIT systems. If a system consists of multiple redundant subsystems or trains, feture of a8 trains constitutes a safety system feNure.

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

system failure. The deAnition for the indicator peranels NRC reportry requrementsin 10 CFR 50.72 and 10 CFR 50.73. The PROCEDURAL NONCOMPLIANCE INCIDENTS lbiowing is a list of the mejor safety systems, sub-systems, and (MAINTENANCE) components monitored for thrs indicator:

The number of identlRed incidents ww,.L,i, maintenance Accident Monitoring instrumentation. Auxiliary (and procedural problems, the number of closed irs reisted to the Emergency) Feedwater System, Combustible Gas Control, use of procedwes (includes the number of closed irs caused by Component Cooling Water System, Containment and procedural noncompliance), and the number of closed Conteenmort leoletion, Contomment Coolant Systems, Control promdural noncompisence irs. This indcator trends personnel Room Emergency VentHabon System, Emergency Core performance for SEP #15,41 and 44.

Cooling

Systems, Engineered Safety Features Instrumentalk n.

Essential Cornpressed Air Systems, PROGRESS OF CYCLE 17 OUTAGE MODIFICATION Essential or Emergency Service Water, Fire Detection or PLANNING Suppression Systems, Isolation Condenser, Low Temperature Overpressure Protechon, Main Steam Line This indcator shows the status of modiAcations approved for Isolation Valves, Onsite Emergency AC & DC Power complebon during the Refueling Outage w/Dubtiuhon, Radiation Monitoring instrumentation, Reactor Coolant System, Reactor Core Isolabon Coohng System, PROGRESS OF 1996 ON4.INE MODIFICATION PLANNING Reedor Trip System and instrumentation, Recirculation Pump Trip Actuation instrumentation, Residual Heat Removal This indicator shows the status of modiHcations approved for Systems, Satsty Velves, Spent Fuel Systems, Standby Liquid completion during 1995.

Control System and Ultimate Heat Sink.

RADIOLOGICAL WORK PRACTICES PROGRAM SECONDARY SYSTEM CHEMSTRY PERFORMANCE INDEX 1he number of identified poor radiologeal work practces (PRWPs) for the reporting month. This indicator tracks The Chemistry Performance index (CPI) is a calculation based radiological work performance for SEP #52.

on the concentration of key impunties in the secondary side of the plant. These key importtaes are the most likely cause of RADIO OF PREVENTIVE TO TOTAL MAINTENANCE &

detortoreton of the steem generators. Criteria for calculating the PREVENTIVE MAINTENANCE ITEMS OVERDUE CPIare:

The ratio of preventive mantenance (including surveNience

1) The plant is at greater than 30 percent power; and testing and caHbration procedures) to the sum of non-outage correceve maintenance and preventive maintenance completed

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

over tie reporting period. The ratio, expressed as a percentage, is calculated based on menhours. Also displayed are the The CPI is calculated using the fogowing equation:

permet of provertive maintenance items in the month that were not completed or administratively closed by the scheduled date CPI = ((sodium /0.79) + (Chloride /1.52) + (Sulfate /1.44) +

plus a pace penod squel to 25% of the scMduled interval. This (Iron /3.30) + (Copper /0.30)+(Condensate 02/2.90))/6 hdiator tracks preventive maintenance activities for SEP #41.

Where: Sodium, sulfste, chloride and condensate dissolved RECORDASLE INJURY /K.LNESS CASES FREQUENCY oxygen are the montNy everage blowdown concentrations in RATE ppb, iron and copper are monthly time weighted average feedwater concentrations in ppb. The denominator for each of The number of injuries requiring more than normal first aid per the five factors is the INPO median value. If the monthly 200,000 men-hours worked. This indicator trends personnel average for a spec 4He pers.neter is less than the INPO median performance for SEP #15,25 and 26.

value, the median value is used in the calculation.

REPEAT FAlLURES SIGNIFlcANT EVENTS The rnenber of Nuclear Plert ReliebHity Data System (NPRDS) components with more than one fadure and the number of Signdcart events are the events identded by NRC staff through NPRDS components with more than two failures for the deleted screening and ovaluaten of operstmg experience. The eighteerwnonth CFAR period, screening process includes the daly review and discussion of 85

f PERFORMANCE INDICATOR DEFINITIONS all reported operating reactor events, as wel as other instrumords are not considered as temporary modrlications.

operatonal data such as special tests or construction activities.

An event identHied kom the screening process as a signHlcard

3) Scaffold is not considered a temporary modWicetion.

event conddele is Ibrher evaluated to determine if any actual or Jumpers and blocks which are installed and for which MRs potential threat to the health and safety of the public was have been submitted wel be considered as temporary involved. SpeciSc examples of the type of criterie are modications until final resolution of the MR and the jumper summettred as follows or block le removed o' is permanently recorded on the drawings. This indicator tacks temporary modifications for

1) Degradation ofimportant safety equipment, SEP #62 and 71.

2) Unexpected plant response to a transient; THERMAL PERFORMANCE

3) Degradstion of fuel integrtty, primary cooient pressure The rate of the design gross heat rate (corrected) to the boundary, important associated features; aquated actual gross hast rate, expressed as a percentage.

4) Scram with complication, UNIT CAPABluTY FACTOR i

5) Unplanned release of radioactMty; The ratio of the asadable energy generation over a given time ported to the reference energy generation (the energy that could

6) Opershon outside the limits of the Techrucal SpeclHcations, be pnnhced if the unit were operated corf.muously at fut power under reference ambient conditions) over the same time period,

7) Other.

expressed as a percentage.

INPO signNlcent events reported in this indicator are SERs UNIT CAPACITY FACTOR (SignWicant Event Reports) which inform utulties of signMicant events and lessons learned identNied through the SEE IN The not electrical energy generated (MWH) divided by the screening process.

product of maximum dependeble capacity (not MWe) times the groes hours inthe reporting period expressed as a percent. Not SPARE PARTS INVENTORY VALUE electrical energy generated is the gross electrical output of the unit measured at the output terminals of the tuttine generator i

The doter value of the spare parts inventory for FCS during the mhus the normal staton service loads during the gross hours of reportmg period, the reporting period, expressed in megawatt hours.

STAFFING LEVEL UNPLANNED AUTOMATIC REACTOR SCRAME PER 7,000 CRITICAL HOURS The eduel stafInng level and the authorized stafHng level for the Nuclear Operations Division, The Production Engmeenng Thisindcator is defined as the number of unplanned automatic Division, and the Nuclear Services Division. This indicator scrams (reactor protechon system logic actuatens) that occur tracks performance for SEP #24.

per 7,000 hours0 days <br />0 hours <br />0 weeks <br />0 months <br /> of critical opershon.

STATION NET GENERATION The value for this indicator is calculated by multiplying the total nundier of unplanned autometc reactor scrams in a specific time The not generation (sum) produced by the FCS during the period by 7,000 hours0 days <br />0 hours <br />0 weeks <br />0 months <br />, then dividng that number by the total reporting month, number of hours criticalin the same time period. The indicator is further defined as follows:

TEWORARY MODIFICATIONS

1) Unplanned means that the scram was not an anticipated The number of temporary mechanical and electncal part of a pionned test.

configurations to the pient's systems.

2) Scram means the automatic shutdwn of the reacwr by a

1) Tergorary conAgurations are denned as electricaljumpers, rapid inserbon of nogetive reactivity go.g., by control rods, elodrical blocks, mechanical jumpers, or mechanical blocks liquid injection system, etc.) that is caused by actuation of which are instated in the pierd operating systems and are the reactor protection system. The scram signal may have not shown on the latest revision of the PatD, schematic, resulted from exceeding a set point or may have been wrr La, wiring, or flow diagrams.

spurtous.

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

3) Autometc means that the initial signal that caused actuation Special Procedures or Operating Procedures are not of the reador protecton system logic was provided from one conendered as temporary modifications unless the jumper or of the sensor's monitoring plant parameters and conditions, block remains in place after the test or procedure is rather than the manuel scram switches or, manuel turbine complete. Jumpers and blocks installed in test or lab inp switches (or push-buttons) provided in the main control 86

1 4

~

PERFORMANCE lNDICATOR DEFINITIONS room.

shipped off-elle for processing, and the volume of notid dry j

rodeoectke weste which has been sNpped off-site for

4) Crtical means that during the steady-state condition of the processing Low-level solid radmactNe waste consists of dry reactor pnor to the scram, the effectNe mulhplication (k,,)

actve weste, alu%es, foeins, and evaporator bottoms generated was essentiety equel to one.

as a resut of nuclear power plant operation and maintenance.

j Dry radioectke waste includes contaminated rage, cleaning UNPLANNED CAPABILITY LOSS FACTOR motseteis,<e=f-=N= protective clothing, piestic containers, and any other meternal to be disposed of at a low-level radioactNe The rot.o of the unplanned energy losses during a given period weste <Seposal site, except resen, sludge, or evaporator bottoms.

of time, to the reference energy generation (the energy that Low 4evel refers to su radioactke weste that is not spent fuel or could be produced if the unit were operated conhnuously at fut a by product of spcit fuel processing TNs indicator tracks power under reference ambient conditions) over the some time radiological work performance for SEP #54.

portod, expressed as a percentage.

J UNPLANNED SAFETY SYSTcM ACTUATioh0 - (INPO

+ DEFINITION) j This indicator is deAnod as the sum of the fogowing safety system actuations 4

1) The number of tmplanned Emergency Core Cochng System (ECCS) actuations that resuR from reaching en ECCS d

actuohon set point or lhwn a spuriouelinadvertent ECCS

{

eignet

2) The number of unplanned emergency AC power system actuatone that resuR from a loss of power to a safeguards bus. An unplanned soloty system actuation occurs when an acet eten est point for a safety system is reached or when a spurtous 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 pionned test or evolution. The ECCS actuatons to be counted are actuations of the high pressure injection system, the low pressure injechon system, or the safety kjection tanks.

UNPLANNED SAFETY SYSTEM ACTIONS. (NRC DEFINITION)

The rasnber of selety system aduations which !nclude (gggg) the i

High Pressure Soesty Irgecton System, the Low Pressure Safety Irtscelon Syalam,to Soloty trysdion Tanks, and the Emergency Diesel Generators. The NRC r4===iaration of safety system actuations includes actuations when mejor equ6pment is operated 3Dd when the logic systems for the above safety systems are chatenged VIOLATION TREND This indlostor ls deined as Fort Calhoun Station Cited Vioistens and NorWand Vloistions trended over 12 mcnths. AdditioneNy, Caed Violations for the top quartte Region IV plant is trended over 12 months (legging the Fort Calhoun Station trend by 2-3 mordhs). R is he Fort Camoun Station goal to be at or below the cGod violation trona for the top quartNe Region IV plant.

VOLUTE OF LOW LEVEL SOLD RADIDACTIVE WASTE This indicator is denned as the volume of low-level solid r=rea=enne weste actueNy, shipped for burial This indicator sino shows the volume of low-level radioactNe weste which is in temporary storage, the amount of redloactke o8 that has been 87

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

SEP Reference Number 15 Eagg.

• Increase HPES and IR Accountability through use of Performance Indicators Procedural Noncompliance lncidents (Maintenance)................

.. 51 Recordable injury / Illness Cases Frequency Rate...................................... 4 Clean Controlled Area Contaminations 31,000 Disintagrations/ Minute Per Probe Area

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

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

. Complete Staff Studies StafHng Level

..............................................,.........,,, 44 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 / Illness Frequency Rate

........... 3 Recordable tnjuryllliness 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)

...................................70 Overall Project Status (Cycle 17 Refueling Outage)..................................... 71 Progress of Cycle 17 Outage Modification Planning................................... 72 SEP Reference Number 33

. Develop On-Line Maintenance and Modification Schedule Percent of Completed Scheduled Maintenance Activities (All Maintenance Crafts)............. 52 SEP Reference Number 36

• Reduce Corrective Non-Outage Backlog Maintenance Workload Backlogs (Corrective Nor>-Outage)

..........47 SEP Reference Numbers 41 & 44

. Develop and implement a Preventive Maintenance Schedule

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

48 Procedural Noncompliance incidents (Maintenance)..................

................ 51 88

SAFETY ENHANCEMENT PROGRAM lNDEX SEP Reference Number 46

. Design a Procedures Controland Administrative Program i

Document Review............................................................ 57

)

]

SEP Reference Number 52 Eagg

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

......... 56 SEP Reference Number 54

. Complete implementation of Radiological Enhancement Program 1

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

Collective Radiation Ex posure..................................

17 Volume of low-Level Soud Radioactive Waste....................

38 Contaminated Radiation Controlled Area.......................................... 55

)

SEP Reference Number 58 Revise Physical Security Training and Procedure Program Loggable/ Reportable incidents (Security)

.... 58 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 Ucensee Event Reports................... 21 SEP Reference Number 62

. Establish interim System Engineers Temporary Modifications

......... 59 Engineering Assistance Request (EAR) Breakdown................................... 61 Engineering Change Notice Status...............................................

62 Engineering Change Notices Open............................................... 63 SEP Reference Number 68 Assess Root Cause of Poor Operator Training and establish means to monitor Operator Training License Operator Requahication Training........................................... 65 Ucense Candidate Exams.................

.......... 66 SEP Reference Number 71

. Improve Controls over Temporary Modifications Temporary Modifications

......59 89

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& Industry Affairs (8)

I T. L. Patterson I

90

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

CUMULATIVE (MWH)

Cycle 1 09/26/73 - 02/08/75 3,299,639 3,299,639 1st Refueling 02/08/75 - 05/11/75 Cycle 2 05/11/75 10/01/76 3,853,322 7,152,961 2nd Refueling 10/01/76 - 12/13/76 Cycle 3 12/13/76 - 09/30/77 2,805,927 9,958,888 3rd Refueling 09/30/77 - 12/09/77 Cycle 4 12/09/77 - 10/13/78 3,026,832 12,985,720 4th Refueling 10/13/78 -12/24/78 Cycle 5 12/24/78 - 01/18/80 3,882,734 16,868,454 5th Refueling 01/18/80 - 06/11/80 Cycle 6 06/11/80 - 09/18/81 3,899,714 20,768,168 6th Refueling 09/18/81 - 12/21/81 Cycle 7 12/21/81 - 12/03/82 3,561,866 24,330,034 7th Refueling 12/03/82 - 04/06/83 Cycle 8 04/06/83 - 03/03/84 3,406,371 27,736,405 8th Refueling 03/03/84 - 07/12/84 Cycle 9 07/12/84- 09/28/85 4,741,488 32,477,893 9th Refueling 09/28/85 - 01/18/86 Cycle 10 01/16/845- 03/07/87 4,356,753 36,834,646 10th Refualing 03/07/87 - 06/08/87 Cycle 11 06/08/87 - 09/27/88 4,936,859 41,771,505 11th Refueling 09/27/88 - 01/31/89 Cycle 12 01/31/89 - 02/17/90 3,817,954 45,589,459 12th Refueling 02/17/90 - 05/29/90 Cycle 13 05/29/90 - 02/01/92 5,451,069 51,040,528 13th Refueling 02/01/92 - 05/03/92 Cycle 14 05/03/92- 09/25/93 4,981,485 56,022,013 14th Refueling 09/25/93 - 11/26/93 Cycle 15 11/26/93- 02/20/95 5,043,887 61,065,900 15th Refueling 02/20/95 - 04/14/95 Cycle 16 04/14/95 - 09/21/96 16th Refueling 09/21/96 - 11/02/96 (Planned Dates)

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

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

September 26,1973 Achieved Full ower (100%)

May 4,1974 Longest Run (477 Days)

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

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

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

Feb. 20,1995-Ap' : 9,1995

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