Text

FCS Performance Indicators,Nov 1993
	ML20059F138
Person / Time
Site:	Fort Calhoun
Issue date:	11/30/1993
From:	; OMAHA PUBLIC POWER DISTRICT
To:	;
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FORT CALHOUN STATION PERFORMANCE INDICATORS F-llli'nEriLEEMlliritimir%

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NOVEMBER 1993 SAFE OPERATIONS PERFORMANCE EXCELLENCE COST EFFECTIVENESS 9401130164 931228 PDR ADOCK 05000285 R

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t OMAHA PUBLIC POWER DISTRICT FORT CALHOUN STATION PERFORMANCE INDICATORS REPORT l

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Prepared By:

Production Engineering Division System Engineering Test and Performance Group NOVEMBER 1993

FORT CALHOUN STATION NOVEMBER 1993 MONTHLY OPERATING REPORT OPERATIONS

SUMMARY

The Fon Calhoun Station completed the 1993 refueling and maintenance outage during Novem-ber. On November 1, the reactor head was set in place. The head stud tensioning was completed on November 3. Control rods were coupled on November 4 and 5. On November 9, at 0229, while in preparation for the Integrated Leak Rate Test (ILRT), two of the four wide range nuclear instrumentation channels indicated a prompt increase in power from 1 X 104 to 1 X 104 percent. The power indication increase was determined to be electronic noise-induced. The two wide range channels were declared inoperable and corrective actions completed. Further details on this event were reponed in LER 93-015. After restoring both channels to an operable status, containment pressurization commenced for the ILRT on November 9. The ILRT was success-fully completed on November 11.

On November 13, during performance of a surveillance test on the Secondary Control Element Assembly Position Indication System (SCEAPIS) of the rod block circuitry, an inadvertent i

withdrawal of control rod assembly #31 was experienced. Because of the potential significance during other operational modes, extensive testing and troubleshooting were performed and a modification to install a ground detection system was completed prior to authorizing a reactor stan-up from refueling. The event was determined to be the result of multiple grounds in the ungrounded rod drive system. An NRC Augmented Inspection Team (AIT) performed an inspection to fully understand the event and review cortective actions. The AIT held a public exit meeting on November 22. Funher details of this event will be reponed in LER 93-016.

On November 14, the " cold hydro" (leak check) was completed. A pressurizer spray line check valve (RC-374) body-to-bonnet leak was identified and repaired.

On November 16, with the plant in refueling shutdown (Mode 5), a System Engineer reviewing completed Offsite Power Low Signal (OPLS) calibration procedures discovered that the as-found time delays for OPLS actuation relays were outside the time delay range specified in Technical Specification Table 2-1. The root cause of this event was determined to inadequate technical review of the calibration procedures for the OPLS circuitry. Corrective actions include re-checking the OPLS actuation relay setpoints, revising OPLS calibration procedures, and review-ing other calibration procedures that involve calibration of this same type of time delay relay.

Funber details of this event will be reported in LER 93-017.

At 1400 on November 17, reactor heatup commenced and the plant transitioned from Mode 4 (RCS less than 210* F). As RCS temperature was increased, "C" reactor coolant pump seal bleedoff temperature also increased and would not lower. On November 18, following RCS cooldown to less than 130aF, flow orifices, which were installed during the outage on the com-ponent cooling water lines to the reactor coolant pumps, were removed. RCS heatup recom-menced with reactor coolant pump seal bleedoff temperatures well within nonnal bands. The RCS hot hydrostatic test was successfully completed on November 20. Final stan-up activities were completed and the reactor was taken critical on November 24. Low power physics testing i

FORT CALHOUN STATION NOVEMBER 1993 MONTHLY OPERATING REPORT OPERATIONS

SUMMARY

(continued) l and turbine testing were also satisfactorily completed, with power escalation through the remain.

der of the month. Breakers were closed at 0615 on November 26. As of the end of November, the station was at approximately 85 percent power.

The following NRC inspections were completed during this reporting period:

IER No.

Descriotion 93-22 Steam Generator Tube Integrity Review (STIR) and ISI Program 93-24 Monthly Residents' Inspection 93-25 Augmented Inspection Team (AIT) on the CEA Events of November 13 and 18,1993 The following LER was submitted during this reporting period:

LER No.

Description 93-014 Failure of PORV to Open Properly During Test Source: Nuclear Licensing & Industry Affairs ii

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l 12 Month Value Performance i

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i Unplanned L-yfinidi Upper 10% and better Peff' 'rd1hhce than 1993 OPPD goal Unit jj Unplanned (Automatic:

o Capability ll Capability JShiams/7,000i Factor jj Loss Factor

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August September October i *! !

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INPO PERFORMANCE INDICATORS (Performance for the twelve months from December 1,1992 through November 30,1993.)

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Performance Not Meeting 1993 OPPD Goal or Peer Average Trend Safety Forced System Outage l

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November 1993 12 Month Value Equipment Collective Performance Forced Radiation Outages /1,000 Crit. Hrs.

Exposure l

NRC PERFORMANCE INDICATORS (Safety System Failures and Significant Events ratings are averages for April 1991 through March 1993. All other indicator values are for the twelve months from December 1,1992 through November 30,1993.)

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FORT CALHOUN STATION PERFORMANCE INDICATORS REPORT NOVEMBER 1993 -

SUMMARY

POSITIVE TREND REPORT ADVERSE TREND REPORT A performance indicator with data representing three A Performance Indicator with data representing three (3) consecutive months of improving performance or three consecutive months of declining performance; or four or consecutive months of periormance that is superior to more consecutive months performance that is trending the stated goalis exhibiting a positive trend per Nuclear towards declining as determined by the Manager - Sta-Operations Division Quahty Procedure 37 (NOD OP-37).

tion Engineering, constitutes an adverse trend per NOD-OP-37. A supervisor whose performance indicator ex-The following indicators are exhibiting positive trends for hibits an adverse trend by this definition may specify in the reporting month:

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

Recordab!e Iniurv/11! ness Cases Frecuency Rate (Page 3)

There were no performance indicators exhibiting adverse HPSI Safety Svstom Performance trends for the reporting month.

(Page 7)

AFW Safety System Performance (Page 8)

End of Adverse Trend Report.

Emercency AC Power System Saferv System Perfor-mance (Page 9)

INDICATORS NEEDING INCREASED Emera Diesef Generator Unit Reliabmtv MANAGEMENT ATTENTION REPORT A performance indicator with data for the reporting period Diesel Generator Reliabihtv (25 Demands) that is inadequate when compared to the OPPD goalis defined as 'Needing increased Management Attention *

(Page 12) per NOD-OP-37.

Emeraency Diesel Generator Unreliabihtv (Page 13)

The following performance indicators need increased Number of Missed Survemance Tests Resu! tina in Lic.

management attention for the reporting month:

ensee Event Reoorts Disablina iniurv/I!! ness Frecuency Rate (Page 19)

(Page 2)

Forced Outace Rate The disabling injury / illness rate for the months from January thru November 1993 (the value is 0.54) exceeds (Page 22) the 1993 goal of a maximum value of 0.50.

Uno!anned Safety System Actuations - flNPO Definaion)

Number of Personnel Errors Reoorted in LERs (Page 27)

(Page 5)

Ecuioment Forced Outaces oer 1.000 Critical Houm The percentage of total LERs submitted year-to4 ate that have been attributed to personnel errors for the reporting (Page 32) month (33.3%) exceeds the 1993 Fort Calhoun goal of a maximum of 121 Check Va!ve Failure Rate

9 Number of Control Room Ecuioment Deficiencies Percentaae of Total MWOs Comoleted oer Month kfenti.

(Page 14)

The total number of control room equipment deficiencies fied as Rework at the end of the reporting month (57) exceeds the 1993 (Page 46)

Fort Calhoun monthly goal of a maximum of 45.

Fazardous Waste Produced Viola 4cns Per 1.000 Insoection Hours (Page 51)

(Page 17)

Decontaminated Radia4cn Contro!!ed Area The number of violations per 1,000 inspection hours for (Page 52) the 12 months from 11/1/92 through 10/31/93is 2.41, which exceeds the 1993 and 1992 Fort Calhoun goals of a maximum of 1.5.

Outstandina Modifications (Page 58)

Enaineerina Assistance Recuest Breakdown (Page 59) v End of Positive Trend Report

INDICATORS NEEDING INCREASED PERFORMANCE INDICATOR REPORT MANAGEMENT ATTENTION REPORT IMPROVEMENTS / CHANGES (continued)

This section lists signifcant changes made to the report Uno!anned Au'omatic Reactor Scrams oer 7.000 Hours and to specific indicators within the report since the pre.

Critical vious month.

(Page 26)

The number of unplanned automatic reactor scrams per Disablina iniurv/1!! ness Frecuenev Rate & Recordable l

7,000 hours0 days 0 hours 0 weeks 0 months critical year-to-date (1.1) exceeds the 1993 iniurv/tilness Cases Freauency Rate goalof 0.

(Pages 2 & 3)

The graphs for these indicators have been changed to Unclanned Safety System Actuations (NRC Definition) reflect revisions in the 1992 frequency rates.

(Page 28)

The number of NRC unplanned safety system actuations Contaminations 22.000 Counts Per Probe Area year-to date (2) exceeds the 1993 Fort Calhoun goal of (Page 4)

O.

The line representing the goal for this indicator has been removed from the graph. The goals are stated in the text In-Line Chemistry instruments Outof-Service to clarify that these are year-end, rather than daily or (Page 50) monthly goals.

The number of in-line chemistry instruments out-of-ser-vice for the reporting month (10) is above the 1993 Number of Hot Scots monthly goal of a maximum of S.

(Page 54)

The graph for the reporting month has been revised to Document Review reflect a lower number of hot spots based on criteria es-(Page 55) tablished in RP-306

Hot Spot & Point Source identifica-The number of biennial reviews greater than 6 months tion and Tracking Procedure",

I overdue for the reporting month (4) exceeds the 1993 Fort Calhoun monthly goal of 0.

Encineerina Chance Notice Status (Page 60) l Tomoorary Modrfications The graph for this indicator has been changed to reflect l

(Page 57) revisions in the number of ECNs backlogged in DEN, The number of temporary modtfications >6 months old ECNs received during the month and ECNs completed that are removable on-line for the reporting month (7) during the month for the months from December 1992 exceeds the 1993 monthly goal of 0.

through October 1993.

Auxi!iary System (CCW) Chemistry Percent of Hours Outside Station Limits This indicator has been deleted from the report because End of Management Attention Report.

the out of specifications conditions are too infrequent to provide useful trending. This was originally trended as an INPO indicator, however, INPO is no longer maintain-ing this indicator.

Qaity Thermal Outout This indicator has again been included in the report due to the end of the Cycle 15 Refueling Outage.

End of Performance Indicator Report improvements /

Changes Report M

I Table of Contents / Summary PAGE

..Xi GRALS..

SAFE OPERATONS EAgf DISABLING INJURY /lLLNESS FREQUENCY RATE.

2 RECORDABLE INJURY /lLLNESS CASES FREQUENCY RATE 3

CONTAMINATONS 22,000 COUNTS / MINUTE PER PROBE AREA.

.4 NUMBER OF PERSONNEL ERRORS REPORTED IN LERs

.5 SAFETY SYSTEM FAILURES

.6 SAFETY SYSTEM PERFORMANCE HIGH PRESSURE SAFETY:

.7 INJECTION SYSTEM ;

AUXILIARY FEEDWATER SYSTEM..

.8 EMERGENCY AC POWER SYSTEM...

.9 FUEL RELIABILITY INDICATOR 10 EMERGENCY DIESEL GENERATOR

.11 UNIT RELIABILITY.

EMERGENCY DIESEL GENERATOR

.12 RELIABILITY (25 DEMANDS).

EMERGENCY DIESEL GENERATOR

. 13 UNRELIABILRY.

NUMBER OF CONTROL ROOM EQUIPMENT DEFICIENCIES..

.14 COLLECTIVE RADIATION EXPOSURE tomamem).

15 MAXIMUM INDIVIDUAL RADIATON EXPOSURE (mrem)..

.16 I

VIOLATIONS PER 1,000 INSPECTION HOURS.

.17

... 18 SIGNIFICANT EVENTS.....-..

NUMBER OF MISSED SURVEILLANCE TESTS RESULTING IN LERS.......

.19 PERFORMANCE PAGE

. 21 STATON NET GENERATION (10.000 Mwh)...

. 22 FORCED OUTAGE RATE.

vii i

PERFORMANCE (continued)

PAGE

. 23 EQUIVALENT AVAILABILITY FACTOR...

. 24 UNIT CAPABILITY FACTOR.......

UNPLANNED CAPABILITY LOSS FACTOR.

. 25 UNPLANNED AUTOMATIC REACTOR SCRAMS PER 7,000 HOURS CRITICAL..

. 26 UNPLANNED SAFETY SYSTEM ACTUATONS - (INPO DEFINITON).

. 27 UNPLANNED SAFETY SYSTEM ACTUATONS - (NRC DEFINITON)..

. 28 GROSS HEAT RATE..

. 29 THERMAL PERFORMANCE..

.. 30 DAILY THERMAL OUTPUT..

. 31 EQUIPMENT FORCED OUTAGES PER 1,000 CRITICAL HOURS

. 32 COMPONENT FAILURE ANALYSIS REPORT (CFAR)

SUMMARY

. 33 REPEAT FAILURES.

. 34 CHECK VALVE FAILURE RATE...

. 35 VOLUME OF LOW LEVEL SOLID RADIOACTIVE WASTE (cut =c to.

... 36 PRIMARY SYSTEM CHEMISTRY PERCENT OF HOURS OUT OF LIMIT.

. 37 CHEMISTRY INDEX/ SECONDARY SYSTEM CHEMISTRY.

. 38 COST fMGE CENTS PER KILOWATT HOUR.

.. 40 STAFFING LEVEL..

. 41 SPARE PARTS INVENTORY VALUE..

. 42

)

DIVISON AND DEPARTMENT PERFORMANCE INDICATORS PAGE MAINTENANCE WORKLOAD BACKLOGS (CORRECTIVE NON-OUTAGE)..

. 44 viii

= _ -. _

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DIVISON AND DEPARTMENT PERFORMANCE INDICATORS (continued)

PAGE RATO OF PREVENTIVE TO TOTAL MAINTENANCE

.. 45

& PREVENTIVE MAINTENANCE ITEMS OVERDUE.

PERCENTAGE OF TOTAL MWOs COMPLETED PER MONTH IDENTIFIED AS REWORK.....

... 46 MAINTENANCE OVERTIME..

.47 PROCEDURAL NONCOMPLIANCE INCIDENTS (MAINTENANCE)..-

. 48 PERCENT OF COMPLETED SCHEDULED MAINTENANCE ACTIVITIES

.49 (ALL MAINTENANCE CRAFTS)..

IN.LINE CHEMISTRY INSTRUMENTS OUT.OF-SERVICE.

. 50 HAZARDOUS WASTE PRODUCED (Kg)..

. 51 DECONTAMINATED RADIATION CONTROLLED AREA...

. 52 RADIOLOGICAL WORK PRACTICES PROGRAM..

. 53

. 54 NUMBER OF HOT SPOTS..

. 55 DOCUMENT REVIEW...

LOGGABLE/ REPORTABLE

.56 INCIDENTS (SECURITY).

TEMPORARY MODIFICATIONS...

.. 57

. 58 OUTSTANDING MODIFICATONS.

ENGINEERING ASSISTANCE REQUEST (EAR) BREAKDOWN.

59 ENGINEERING CHANGE NOTICE STATUS..

. 60 ENGINEERING EHANGE NOTICE BREAKDOWN.....

. 61

. 62 LER ROOT CAUSE BREAKDOWN.

LICENSED OPERATOR

.. 63 REQUALIFICATON TRAINING i

. 64 LICENSE CANDIDATE EXAMS...

OPEN CORRECTIVE ACTON REPORTS AND INCIDENT REPORTS.

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ACTION PLANS. DEFINITIONS. SEP INDEX & DISTRIBUTION LIST PAGE

....... 66 ACTON PLANS FOR ADVERSE TRENDS.

..68 PERFORMANCE INDICATOR DEFINITONS.

SAFETY ENHANCEMENT PROGRAM INDEX..

75 i

77 REPORT DISTRIBUTON LIST..

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OPPD NUCLEAR ORGANIZATION GOALS Vice President - 1993 Priorities MISSION The safe and reliable 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 pmtection of all personnel, the general public and the environment.

GOALS Goal 1: SAFE OPERATIONS To ensure the continuation of a " safety culture" in the OPPD Nuclear Program and to provide a professional working environment, in the control room and thmughout the OPPD nuclear organi-zation, that assures safe operation.

1993 Priorities:

Improve SALP ratings.

Improve INPO rating.

Reduce 1993 NRC violations with no violt tions more severe than level 4.

No unplanned automatic reactor scrams or safety system actuations.

Goal 2: PERFORMANCE To strive for Excellence in Operations utilizing the highest standards of performance at Fort Calhoun Station that result in safe reliable plant operation in power production.

i 1993 Priorities:

Improve Quality, Professionalism, and Teamwork.

Improve Plant Reliability.

l Meet or exceed INPO key parameters and outage performance goals.

Reduce the number of human performance errors.

Goal 3: COSTS Operate Fort Calhoun Station in a manner that cost effectively maintains nuclear generation as a viable source of electricity.

1993 Priorities:

Maintain total O & M and Capital expenditures within budget.

Streamline work processes.

i Goals Source: Scofield (Manager)

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i SAFE OPERATIONS Goal: To ensure the continuation of a " safety culture" in the OPPD Nuclear Program and to provide a professional work-ing environment in the control room and throughout the OPPD Nuclear Organization that assures safe operation.

1

1993 Disabling injurynliness Frequency Rate l GOOD l X

1992 Disabling injuryMllness Frequency Rate V

--O-Fort Calhoun Goal ( 0.50) 1.2 -

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0.6 -

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i Jan93 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec93 DISABLING INJURY /lLLNESS FREQUENCY RATE (LOST TIME ACCIDENT RATE)

This indicator shows the 1993 disabling injury / illness frequency rate. The 1992 dis-abling injury / illness frequency rate is also shown.

The disabling injury / illness frequency rate for January through November 1993 was 0.54. There was one lost time accident, a muscle strain, reported for the month of November. The total number of lost time accidents that have been reported during 1993 is 4.

The disabling injury / illness frequency rate for the past twelve months is 0.50.

The 1993 Fort Calhoun goal for this indicator is a maximum value of 0.50.

Data Source: Sorenson/Skaggs (Manager / Source)

Accountability: Chase / Richard Adverse Trend: None SEP 25, 26 & 27 2

= -.

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5-1993 Recordable injury / Illness Frequency Rate

--M-1992 Recordable injury / Illness Frequency Rate 4.5 -

I GOOD I

--O-1993 Fort Calhoun Goal ( 2.0) y 3.5 -

3-2.5 -

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0 Jan93 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec93 RECORDABLE INJURY /lLLNESS CASES FREQUENCY RATE This indicator shows the 1993 recordable injury / illness cases frequency rate. The 1992 recordable injury / illness cases frequency rate is also shown.

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

The recordable injury / illness rate for January through November 1993 was reported as 1.34. There were no recordable injury / illness cases reported for the month of Novem-ber. There have been 10 recordable injury / illness cases in 1993.

The recordable injury / illness rate for the past twelve months is 1.5.

The 1993 goal for this indicator is a maximum value of 2.0.

Data Source: Sorenson/Skaggs (Manager / Source) 1 j

Accountability: Richard Positive Trend SEP 15,25,26 & 27 I

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PersonnelContamination Rate 2.4 -

2.2 -

2 2-5

.8-Cycle 15 1

1 Refueling 1.6 -

Outage tr 1.4-o g1.2-

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11 13 15 17 19 21 23 25 27 29 CONTAMINATIONS 22,000 COUNTS / MINUTE PER PROBE AREA This indicator chows the Personnel Contamination Rate for contaminations 22,000 counts / minute per probe area for the reporting month. There were 19 outage contami-nations by November 30,1993.

There has been a total of 137 reportable / recordable contaminations in 1993. 35 of these contaminations were classified as non-outage and 99 were classified as outage contaminations. (3 outage contaminations occurred during the maintenance outage.)

The 1993 year-end on-line goal for contaminations 22,000 counts / minute per probe area is 0.4 PCR/1,000 RWP hours. The 1993 year-end outage goal for contaminations -

22,000 counts /minuto per probe area is 1.5 PCR/1,000 RWP hours.

Data Source: Chase / Williams (Manager / Source)

Accountability: Chase /Lovett Adverse Trend: None SEP 15 & 54 4

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Licensee Event Reports 40-5 Personnel Errors Reported in LERs 32 33 Cumulative Licensee Event Reports 31

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20-15

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'92 Jan93 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec93

% of Total LERs that are Attributed to Personnel Error (Year to-Date)

-O-1993 Fort Calhoun Year End Goal (s12%)

60%-

47 %

50%-

31% 32 %

40%-

24 % 3 0 % -

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'92 Jan93 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec93 NUMBER OF PERSONNEL ERRORS REPORTED IN LERS The top graph shows the number of Licensee Event Reports (LERs) submitted during each month in 1993, the LERs attributed to personnel error for each month and the cumulative totals for each item. The bottom graph shows the percentage of total LERs submitted that have been attributed to personnel error. The year-end totals for the four previous years are also shown for both graphs.

In November there was 1 LER reported. The percentage of total LERs submitted year-to-date that have been attributed to personnel error was 33.3% at the end of November.

The following LERs have been attributed to personnel error in 1993:

LER 92-032 Failure to Satisfy Fire Watch Requirements for impaired Halon System LER 93-006 Failure to Maintain Continuous Fire Watch for impaired Halon System LER 93-007 Unplanned Emergency Diesel Generator Start and Reactor Trip Signal LER 93-010 Failure to Address Low Halon Tank Pressure Following Surveillance Test LER 93-011 Reactor Trip on Loss of Load During Switchyard Maintenance The 1993 goal for this indicator is that a maximum of 12% of the total LERs submitted will be attributed to personnel error.

Data Source: Short/Cavanaugh (Manager / Source)

Accountability: Chase Adverse Trend: None SEP 15 5

0 Safety System Failures

===== Fort Calhoun Trend

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Peer Plant Average Trend l GOODI

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91-2 91-3 91-4 92-1 92-2 92-3 92-4 93 1 Year - Quarter SAFETY SYSTEM FAILURES This indicator illustrates the number of N9C Safety System Failures as reported 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.

The following NRC safety system failures occurred between the second quarter of 1991 and the first quarter of 1993:

Second Quarter 1991: 1) Failure of high energy auxiliary steamlines in various equipment rooms could render equipment vital for safe shutdown inoperable. 2) All 4 channels of the pressurizer pressure low signal trip could have been nonconservatively calibrated due to an inadequate calibration procedure. 3) A steam generator blowdown was performed while the radiation monitor was inoperable. This was caused by the mode selector switch on the monitor being left in the calibrate position.

Third Quarter 1991: 1) Both EDGs could have been rendered unable to perform their design function due to radiator exhaust damper failure. The dampers had cracked pins in their cou-plings. 2) The' station batteries were declared inoperable due to cracks developing in the cell casings. This was caused by inadequate design of the terminal post seals. 3) An error in an operating procedure could cause improper manipulation of nitrogen backup bottles for instru-ment air. This could cause a loss of the containment spray system.

First Quarter 1992: 1) Defective control switches in the 4KV switchgear could have rendered safety equipment inoperable. 2) All 4 channels of the SG DP trip for RPS had been calibrated nonconservatively. This occurred due to an incorrect procedure which specified a tolerance band that was too wide.

Second Quarter 1992: Fuse and breaker coordination problems for the DC buses could cause a loss of the entire bus if a fault occurred on one of the loads.

Data Source: Nuclear Regulatory Commission Accountability: Chase Adverse Trond: None 6

1993 Month!y High Pressuro Safety injection System g

Unavailability Value 1993 High Pressure Safety injection System Unavailability Value Year to-Date

-O-Fort Calhoun Goal V

--b-1995 INPO Industry Goal (0.02)

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Industry Upper 10% (0.0011) 0.02 - a a

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Refueling Outage 0.01 -

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i 1992 Unavailability Value Jan93 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec93 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 report-ing month.

The High Pressure Safety injection System unavailability value for the month of Novem-ber 1993 was 0.0.

The 1993 year to-date HPSI unavailability value was 0.00032 at the end of November. The value for the last 12 months was 0.00028.

There has been a total of 6.08 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months of planned unavailability (for maintenance and surveillance tests) and no hours of unplanned unavailability for the HPSI system year-to-date.

The 1993 and 1992 Fort Calhoun goals for this indicator are a maximum of 0.008. The 1995 INPO industry goal is 0.02 and the industry upper ten percentile value (for the three year period from 7/90 through 6/93) is approximately 0.0011.

Data Source: Jaworski/Schaffer Accountability: Jaworski/Schaffer Positive Trend 7

E Monthly Auxiliary Feedwater System Unavailabimy value 1993 Auxiliary Feedwater System Unavailability Value Year-to4 ate lGOODI

-O-1993 Fort Calhoun Goal ( 0.01)

V 1995 INPO Industry Goal ( 0.025)

-O-Industry Upper 10% (0.0029) 0.025 -

A A

A 0.02-Cycle 15 Refueling 0.015 -

Outage 0.01 -

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1992 Unavailability Value Jan93 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec93 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 November 1993 was 0.0. The 1993 year-to-date AFW unavailability value was 0.0024 at the end of November. The value for the last 12 months is 0.0024.

There has been a total of 28.01 hours1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months of planned unavailability (for maintenance and surveillance tests) and 2.02 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months of unplanned unavailability for the auxiliary feedwater system year-to-date.

The 1993 and 1992 Fort Calhoun year-end goals for this indicator are a maximum value of 0.01. The 1995 INPO industry goalis 0.025 and the industry upper ten percentile value (for the three year period from 7/90 through 6/93) is approximately 0.0029.

Data Source: Jaworski/Nay Accountability: Jaworski/Nay Positive Trend 8

5 Monthly Ernergency AC Power Unavailability Value Ernergency AC Power Unavailability Value Year to-Date

-O-Fort Calhoun Goal ( 0.023)

--b-1995 INPO Industry Goal (0.025)

-D-Industry Upper 10% (0.004) 0.03-0.025 -

A A

O O

0.02-Cycle 15 Refueting 0.01 -

Outage 0.005 -

D

-C J--

Q O

O 0.001 W

o u-

.1 a

i i

1992 Unavailability Va!ue Jan93 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec93 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 November 1993 is 0.0.

There were no hours of planned or unplanned unavailability for the month. The Emer-gency AC Power System unavailability value year-to-date is 0.0028. The value for the last 12 months is 0.0027.

There was a total of 41.04 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months of planned unavailability for surveillance tests and maintenance, and 0.22 hours2.546296e-4 days 0.00611 hours 3.637566e-5 weeks 8.371e-6 months of unplanned unavailability for the emergency AC power system year-to-date.

The 1993 Fort Calhoun goal for this indicator is 50.023. The 1992 goal was 50.024.

The 1995 INPO industry goal is 0.025 and the industry upper ten percentile value (for the three year period from 7/90 through 6/93) is approximately 0.004.

Data Source: Jaworski/Ronning Accountability: Jaworski/Ronning Positive Trend 9

4 e

5 Fuel Reliability indicator

--6--

1995 INPO Industry Fuel Defect Reference (5 X 10-4 Microcuries/ Gram) l GOOD]

-O--

1993 & 1992 Fort Calhoun Goals y

10-k C

C C

O O

j 6-l s

a a

s-a y4-Cycle 15 Refueling Outage d,

M y,

PRet Dec92 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov93

Beginning in Jan. '93 FRI uses INPO's revised calculation rnethod.

FUEL RELIABILITY INDICATOR The Fuel Reliability Indicator (FRI) values for October and November 1993 were not available because the plant was shutdown for the Cycle 15 Refueling Outage.

The Fuel Reliability Indicator (FRI) for September 1993 was 1.952 X 10-4 microcuries/

gram. The purpose of the FRI is to monitor industry progress in achieving and maintain-ing a high level of fuelintegrity. The September FRI value continues to indicate a defect free core. The September FRI was calculated based on fission product activities present in the reactor coolant during full power operation, September 1 through Sep-tember 17.

Fission product activity data from plant full power operation and power reduction and shutdown, September 18 through 26, shows no Xenon-133 activity increases and no lodine spiking present. This is another indication of a defect free core. A detailed fuel ultrasonic inspection and possible reconstitution program will not be necessary during the 1993 refueling outage. The last detected fuel failure was during Cycle 13.

The INPO September 1992 Report " Performance Indicators for U.S. Nuclear Utility industry" (INPO No.92-011) states that "...the 1995 industry goal for fuel reliability is that units should strive to operate with zero fuel defects. A value larger than 5.0 X 10~'

microcuries/ gram indicates a high probability of unit operation with one or more fuel defects. The determination of current defect-free operation requires more sophisticated analysis by utility reactor engineers." The value of 5.0 X 10-' microcuries/ gram is not an INPO industry goal. It is defined as a " Fuel Defect Reference" number or a "Zero Leaker Threshold". Each utility will calculate whether the core is defect free or not.

Data Source: Holthaus/Guliani Accountability: Chase /Spijker Adverse Trend: None 10

Number of Failures /20 Demands

-N-Trigger Values for 20 Demands O

Number of Failures /50 Demands

-Y-Trigger Values for 50 Demands E

Number of Failures /100 Demands

- - Trigger Values for 100 Demands 8-l GOOD l

+

6-Y Y

Y Y

7 Y

Y Y

4-3 2

2 2

l l

E 1

l 1

l l

C 1

1 1

n e

e e

h f

f f

k 00 I 00 f 00 00 7 0

00 00 00 00 00 00 0

0 Dec92 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov93 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 val-ues. The Fort Calhoun 1993 goalls 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 mini-mum of one hour and to be loaded with at least 50% of design load (see exceptions and j

other demand criteria in the Definition Section of this report).

Data Source: Jaworski/Ronning (Manager / Source)

Accountability: Jaworski/Ronning Positive Trend 11

i O

DG-1 Failures /25 Demands IGOODI E

DG-2 Failures /25 Demands f

V 5-O Failure Trigger Value for 25 Demands / Fort Calhoun Goal 4-C O

O O

3-2-

1 1

0 0

00 00 00 00 00 00 00 00 l

1 i

i i

i I

6 l

l 6

i Dec92 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov93 DIESEL GENERATOR RELIABILITY (25 DEMANDS)

This indicator shows the number of failures experienced by each emergency diesel generator during the last 25 start demands and the last 25 load-run demands. A trigger value of 4 failures within the last 25 demands is also shown. This trigger value of 4 failures within 25 demands is the Fort Calhoun goal for 1992 and 1993.

It must be emphasized that in accordance with NUMARC criteria, certain actions will take place in the event that any one emergency diesel generator experiences 4 or more failures within the last 25 demands on the unit. These actions are described in the Definitions Section of this report. 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 not experienced any failures during the last 25 demands on the unit.

Diesel Generator DG-2 has not experienced any failures during the last 25 demands on the unit.

Data Source: Jaworski/Ronning (Manager / Source)

Accountability: Jaworski/Ronning Positive Trend 12

O DG-1 Unreliability Value DG-2 Unreliability Value lGOODI

-+- Station Unreliability Value 0.003 -

Industry Upper 10% (0.002 for 0.0025 -

a Three Year Average) 0.002 -

O O

0.0015 -

0.001 -

0.0005 -

0,0 0,0 0,0 0,0 0,0 0,0 0,0 0,0 0.0 0,0 0,0

- i - i - i i

i-iv i

v i

- i -

- i Jan93 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec93 EMERGENCY DIESEL GENERATOR UNRELIABILITY The purpose of this indicator is to monitor the likelihood that emergency AC power generators will respond to off-normal events or accidents. It also provides an indication of the effectiveness of maintenance, operation and test practices in controlling genera-tor unreliability.

The yecr-to-date station EDG unreliability value at the end of November 1993 was 0.0.

For DG-1: There were 3 start demands for the reporting month with no failures.

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

For DG-2: There were 3 start demands for the reporting month with no failures.

In addition, there was 1 load-run demand without 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: Jaworski/Ronning (Manager / Source)

Accountability: Jaworski/Ronning Positive Trend 13

O Control Room Equipment Deficiencies Repairable On-Line IGOODI O

Total Number of Control Room Equipment Deficiencios V

80-

--O-Fort Calhoun Goal For Total Equipment Deficiencies 1

70-i

~

60 -

,?

C h

0 5

I i

0 5:

7

[

d j

30-5:

[

20 -

[

l

).

f j

I'

~

10-

~

p y

p p

O

~;

i i

Dec92 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov93 O

Operator Work Around items Repairable On-Line O

Total Number of Operator Work Around items 10-

-O-Fort Calhoun Goal for Total Operator V/ork Around items 8-6-

O O

O,*

C C

O O

O 4-r 7N V

rG,.,s,

,A,A 9,

n 0

i i

I Dec92 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov93 NUMBER OF CONTROL ROOM EQUIPMENT DEFICIENCIES This indicator shows the number of control room equipment deficiencies that are repair-able during plant operations (on-line), the total number of control room equipment defi-ciencies, the number of Operator Work Around (OWA) Items repairable on-line, the total number of OWAs and the Fort Calhoun goals.

There was a total of 57 control room equipment deficiencies at the end of November 1993. 40 of these deficiencies are repairable on-line and 17 require a plant outage to repair.

There were no identified Operator Work Around items at the end of the month.

The 1993 Fort Calhoun monthly goals are to have a maximum of 45 control room equip-ment deficiencies (total) and a maximum of 5 OWAs (total).

Data Source: Chase / Tills (Manager / Source)

Accountability: Chase /Bobba Adverse Trend: None 14

O Monthly Personnel Radiation Exposure Personnel Cumulative Radiation Exposure (Person-Rem)

-O-Fort Calhoun AnnualGoal

--b-1995 INPO Industry Goal (185 Person-Rem) 300 -

-O-Industry Upper 10% (109 Person-Rem for a Three Year Average) 256 IGOODl Cycle 15 Refueling V

Outage 200 -

C O

O O

A A

C O

O O

O 100-g

A h

52 E'0 a

w i

i i

'90 91 92 Jan93 Feb Mar Apr May Jun Jul Aug Sep Od Nov Dec93 COLLECTIVE RADIATION EXPOSURE t

During November 1993,36.126 person-rem was recorded by TLDs worn by personnel while working at the Fort Calhoun Station. The year-to-date exposure is 153.125 per-son-rem. The exposure for the last 12 months is 155.319 person-rem.

The Fort Calhoun goal for collective radiation exposure for 1993 is a maximum of 200 person-rem.

The 1995 INPO industry goalis 185 person-rem per year. The industry upper ten percentile value (for the three year period from 7/90 through 6/93) is approximately 109 person-rem per year. The yearly average for Fort Calhoun Station for the three years from 12/90 through 11/93 was 161.393 person-rem per year.

Data Source: Chase / Williams (Manager / Source)

Accountability: Chase /Lovett Adverse Trend: None SEP 54 15

O Highest Exposure for the Month (mrem)

O Highest Exposure for the Year (mrem) 5000-OPPD 4500 mrem /yr. Limit 4000-3000 -

Fort Calhoun 1500 mRemlyr. Goal 000 -

1180 1000-596 0

i November 1993 MAXIMUM INDIVIDUAL RADIATION EXPOSURE During November 1993, an individual accumulated 596 mrem, which was the highest individual exposure for the month.

The maximum individual exposure for the year was 1,180 mrem at the end of Novem-ber.

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

year. The 1993 Fort Calhoun year-end goalis a maximum of 1,500 mrem.

Date Source: Chase / Williams (Manager / Source)

Accountability: Chase /Lovett i

Adverse Trend: None 16

Violations per 1,000 Inspection Hours O

-O-Fort Calhoun Goal 4-e V

Sx

.63 -

2-N O

C C

C 1.2 g

E,0 p1-

.9 90 91 Nov92 Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oc193 VIOLATIONS PER 1,000 INSPECTION HOURS This indicator displays the number of NRC violations cited in inspection reports per 1,000 NRC inspection hours. This indicatoris one month behind the reporting month due to the time involved with collecting and processing the data.

The violations per 1,000 inspection hours indicator was reported as 2.41 for the twelve months from November 1,1992 through October 31,1993.

The following inspections ended during this reporting period:

IER No.

Illig No. of Hours 93-22 Steam Generator Tube integrity and ISI Program 240 93-24 Monthly Resident inspection 480 93-25 AIT - CEA Withdrawal Event 152 To date, OPPD has received a total of 10 violations in 1993:

Level 111 Violations (0)-

Level IV Violations (5)

Level V Violations (0)

Non-Cited Violations (NCV)

(5)

The 1993 and 1992 Fort Calhoun goals for this indicator are a maximum of 1.5 viola-tions per 1,000 inspection hours.

Data Source: Short/Cavanaugh (Manager / Source)

Accountability: Short Adverse Trend: None g

Q NRC Significant Events lGooDI 4

Fort Calhoun Trend

-O-Industry Average Trend 0.7 nV O.5 -

' ]?

0.2 -

g, 91 2 91-3 91-4 92-1 92-2 92-3 92-4 93-1 Year - Quarter Q INPO Significant Events (SERs) 2-1 1

1 W/$/b Wb V/////b 91-2 91-3 91-4 92-1 92-2 92-3 92-4 93-1 Year - Quarter SIGNIFICANT EVENTS This indicator illustrates the number of NRC and INPO Significant Events for Fort Calhoun Station as reported by the Nuclear Regulatory Commission's Office for Analysis and Evaluation of Operational Data in the biannual" Performance Indicators for Operating Commercial Nuclear Power Reactors" report and INPO's Nuclear Network.

The following NEG significant events occurred between the second quarter of 1991 and the first quarter of 1993:

Second Quarter 1991: Safety related equipment was not adequately protected from a high energy line break.

Third 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.

The following INPO significant events, as reported in Significant Event Reports (SERs), oc-curred between the second quarter of 1991 and the first quarter of 1993:

Second Quart 6r 1992: Personnel and accessible building areas were contaminated with tran-suranic, alpha-emitting radionuclides.

Third Quarter 1992: The failure of a nonessentialinverter during troubleshooting caused a turbine load rejection. This resulted in a high reactor coolant pressure automatic scram and the opening of the pressure relief valves and one of two pressurizer safety valves. One pressurizer safety valve subsequently reopened at a lower reactor coolant system pressure and remained partially open, resulting in a release of reactor coolant to containment via the pressurizer quench tank.

First Quarter 1993: The plant operated for 4 months with reversed upper and lower nuclear instrument excore detector input signals to one of four channels of the reactor protection sys-tem.

Data Source: Nuclear Regulatory Commission & INPO Accountability: Chase Adverse Trend: None 18

. =.

3-

@ Nurnberof Missed STs Resulting in LERs 1

2-1 1-0 7//x 0

0 0

t i

I 4

4 4

4 i

i i

4 6

l 91 92 Dec92 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov93 NUMBER OF MISSED SURVEILLANCE TESTS 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 November 1993.

During the month of January 1993 it was discovered that during December 1992 an ASME Section XI Code required surveillance was not completed nor corrective mainte-nance performed as a result of AC-10A falling into the " Alert Range" (LER 93-003 Fail-ure to Satisfy inservice Testing Requirements for Raw Water Pump).

The 1993 and 1992 Fort Calhoun goals for this indicator are zero.

Data Source: Monthly Operating Report & Plant Licensee Event Reports (LERs)

Accountability: Chase /Jaworski Positive Trend SEP 60 & 61 L

19

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

8 E

F l

l t

l 20 f

_ =

~'

E Net Generation (10,000 Mw hours) s 40-35.03 35.12 32.51 32.14 31.21 h30-~

Cycle 15 28.01

?

z Refueling 25.03 Outage g

l20-10-1.54 0

i i

i Dec92 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov93 STATION NET GENERATION I

l During the month of November 1993 a net total of 15,442 MWH was generated by the 7

j Fort Calhoun Station. Energy losses for September, October and November 1993 are attributable to the shutdown for the Cycle 15 refueling outage, which began on Septem-i ber 25 and ended on November 26.

l Unplanned energy losses for the months of June and July were attributable to a forced l

outage that began on June 24 when the inadvertent jarring of a 345 KV fault relay in the l

switchyard caused a turbine and reactor trip. The plant returned to 100% power on July 2nd.

l Planned energy losses for the months of April and May were the result of a mainte-nance outage.

4 i

Data Source: Station Generation Report Accountability: Chase l

Adverse Trend: None 21 i

I

. =.. -,...-

f Forced Outage Rate l GOOD l

-O-1993 & 1992 Fort Calhoun Goals 12%-

y 9.7 10%-

8%-

Cycle 15 Refueling Outage 4%-

C C

C 1.4 2%-

i i

i i 0%

'89 90 S1 Dec92 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov93 FORCED OUTAGE RATE The forced outage rate (FOR) was reported as 0.99% for the twelve months from December 1,1992 to November 30,1993. The slight increase in the FOR from Sep-tember thru November occurs because there are very few generator on-line hours during those months due to the Cycle 15 Refueling Outage.

There was one forced outage during the month of June 1993. This outage, which occurred when the inadvertent jarring of a 345 KV fault relay in the switchyard caused a turbine and reactor trip, lasted 70.6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

The 1993 and 1992 Fort Calhoun goals for the Forced Outage Rate are a maximum of 2.4%.

Data Source: Monthly Operations Report & NERC GAD Forms Accountability: Chase Positive trend 22

l 1

1 O

Monthly EAF 1993 Year to-Date Average Monthly EAF 4

-+- 1992 Year-to-Date Average Monthly EAF lGOODI

--QD-Industry Median Value (76.7%)

Cycle 15 100%-

Refueling

~

Outage l

85.6 4

+

g g_,,,,g,,,_g_

_g_{_g_g_,,_g

'y 80*,'. -

II j

~

9

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)

~

j gjff M-

^

60.8 56.6 M 60% -

y Fi s'

l AY

\\*

W,,

e 4

!ikff (f

l 3

NI 40%-

x fp

^

/

El uJ y

20%-

g a,

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l W

w u

n y

Y

{

l' l

p i

i i

i o%

i i

90 91

'92 Dec92 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov93 EQUIVALENT AVAILABILITY FACTOR This indicator shows the plant monthly Equivalent Availability Factor (EAF), the year-to-date average monthly EAF for 1993, and the EAF for the previous 3 years.

The EAF for November 1993 was reported as 5.6% due the Cycle 15 Refueling Outage, which ended on November 26. The year-todate average monthly EAF was reported as 74.2% at the and of November.

The April, May and June 1993 EAF values are the result of a maintenance outage and a forced outage that occurred when the inadvertent jarring of a 345 KV fault relay in the switchyard caused a turbine and reactor trip.

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

Data Source: Dietz/Parra (Manager / Source)

Accountability: Chase l

Adverse Trend: None 1

23

)

l

O Monthly Unit Capability Factor

-M--

Year-to-Date Unit Capability Factor

-+-- 36 Month Average Unit Capability Factor 4

-O-1993 & 1992 Fort Calhoun Goals l GOOD I 1995 INPO Industry Goal ( 80%)

Cycle 15 industry Upper 10% (85.4% for a Three Year Average)

Refueling Outage 10W. -

g g

O

@k-?-9-E-A 7-s[

e g

,g 7

g 4 9 gi: p 9

s k

fffh k

(jfl 40%- %

k fff 2g;- g g

g git, E E

d

$f a

Dec92 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov93 UNIT CAPABILITY FACTOR This indicator shows the plant monthly Unit Capability Factor (UCF) value, the 1993 and 1992 year-to-date UCFs, the goals, the 36 month average UCFs, the 1995 INPO industry goal and the approximate industry upper ten percentile value. UCF is defined as the ratio of the available energy generation over a given period of time to the reference energy generation (the energy that could be produced if the unit were operated continuously at full power under reference ambient conditions) over the same time period, expressed as a percentage.

The UCF for November 1993 was reported as 4.2%. Energy losses for the month were due to the Cycle 15 Refueling Outage, which began on September 25. The year-to-date UCF was reported as 75.4%. The 36 month average UCF was reported as 74.9% at the end of Novem-ber. The UCF for the last 12 months was 77.5%

The UCF for June 1993 was reported as 82.6%. Energy losses for the month were due to Moderator Coefficient Testing and a forced outage from June 24 through June 27.

i The UCF for May 1993 was reported as 88% Energy losses for the month were due to the maintenance outage that began on April 24 and continued through May 1 and the subsequent rampup. The UCPwas reported as 77.1% for the month of April 1993. Planned energy losses for April were the result of the maintenance outage from April 24 through 30.

The 1995 INPO industry goal is 80% and the industry upper ten percentile value (for the three year period from 7/90 through 6/93)is approximately 85.4%

The 1993 Fort Calhoun goal for Unit Capability Factor is 74.1% The basis for this goal is 56 l

days for the Cycle 15 Refueling Outage,20 days rampup (10 full power equivalent days),

unplanned loss of 11.5 full power equivalent days, and 10 day ramp up (5 full power equivalent days), mini outage of 7 full power equivalent days, and 10 day ramp up (5 full power equivalent days). Based on the station operating record through the end of Cycle 14; the Cycle 15 Refueling Outage and rampup, and including the December 6 forced outage; the maximum possible 1993 UCF is 76.8%

i i

Data Source: Generation Totals Report & Monthly Operating Report Accountability: Chase Adverse Trend: None 24

O Monthly Unplanned Capability Loss Factor Year-to-Date Unplanned Capability Loss Factor

--O-1993 & 1992 Fort Calhoun Goals ( 4.5%)

lG00D]

t 1995 INPO Industry Goal ( 4.5%)

30%-

Industry Upper 10% (1.65% for a Three Year Average) 25% -

Cycle 15 Refueling 20% -

Outage 15%-

l 5

10% -

4 5%-

O O

O O----U-- C O

O O---

00 s

.e y-0%

,-i-i-,-i i

i i

Dec92 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov93 UNPLANNED CAPABILITY LOSS FACTOR This indicator shows the plant monthly Unplanned Capability Loss Factor (UCLF), the 1993 and 1992 year-to-date UCLFs, the goals, the 1995 INPC industry goal and the approximate industry upper ten percentile value. 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), ex-pressed as a percentage.

The UCLF for the month of November 1993 was reported as 17.3% Unplanned energy losses for the month were a result of the Cycle 15 Refueling Outage extension. The year-to-date UCLF for 1993 was 3.1% The 36 month average UCLF was reported as 9.8% at the end of November. The UCLF for the last 12 months was 2.9%

)

i The UCLF was reported as 16.6% for the month of June 1993. Unplanned energy losses for the month were the result of a forced outage that occurred as a result of the inadvertent jarring of a 345 KV fault relay in the switchyard.

The 1995 INPO industry goalis 4.5% and the industry upper ten percentile value (for the three year period from 7/90 through 6/93) is approximately 1.65%

The 1993 Fort Calhoun goal for Unplanned Capability Loss Factor is 4.5% The basis for this goal is an unplanned loss of 11.5 full power equivalent days and 10 day rampup (5 full power equivalent days).

Data Source: Generation Totals Report & Monthly Operating Report Accountability: Chase Adverse Trend: None 25

)

- FCS Reactor Scrams Per 7,000 Hours Critical (Year-to-date)

-+- FCS Reactor Scrams Per 7,000 Hours Critical (for the last 36 months)

-O-1993 & 1992 Fort Calhoun Goals

--6--

1995 INPO Industry Goal

--D-Industry Upper 10% (0.51 per 7,000 hours0 days 0 hours 0 weeks 0 months critical over a 36 month time period) 4-3-

2-k k

k A

A M

I~

$ r-O, br-0 r-t b i 5

0 o,

5 0

i i

Dec92 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov93 4-B Number of FCS Reactor Scrams Cycle 15 3

3-Refueling Outage 2

2-3 h

1-0 0

0 0

pl!']

0 0

0 0 0 0 i

i i

i io i

i i

'89 '90 '91 '92 Dec92 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov93 UNPLANNED AUTOMATIC REACTOR SCRAMS PER 7,000 HOURS CRITICAL The upper graph shows the number of unplanned automatic reactor scrams per 7,000 hours0 days 0 hours 0 weeks 0 months critical (as defined in INPO's 12/92 publication " Detailed Descriptions of Interna-tional Nuclear Power Plant Performance indicators and Other Indicators") for Fort Cal-houn Station. This value is calculated by multiplying the total number of scrams in a specified time period by 7,000 hours0 days 0 hours 0 weeks 0 months , then dividing that number by the total number of critical hours in the same time period. 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 is 1.1 at the end of November 1993. The value for the last 12 months is 0.98. The value for the last 36 months is 1.36.

An unplanned automatic reactor scram occurred on June 24,1993 when the inadvertent jarring of a 345 KV fault relay in the switchyard caused a turbine and reactor trip.

The 1993 and 1992 goals for unplanned automatic reactor scrams per 7,000 hours0 days 0 hours 0 weeks 0 months critical have been set at zero. The 1995 INPO industry goal is a maximum of one unplanned automatic reactor scram por 7,000 hours0 days 0 hours 0 weeks 0 months critical. The industry upper ten percentile value is approximately 0.51 scrams per 7,000 hours0 days 0 hours 0 weeks 0 months critical for the 36 rnonth time period from 7/90 through 6/93.

Data Source: Monthly Operations Report & Plant Licensee Event Reports (LERs)

Accountability: Chase Adverse Trend: None 26

3-Safety System Actuations(INPO Definition)

--O--

1993 & 1992 Fort Calhoun Goals

-O-Industry Upper 10 Percentile 2-Cycle 15 1

1 Refueling j

!l Outage i

l l

1 h

0

^0 0

O O

O i

i i

i r

i i

i

'90'91 '92 Dec92 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov93 UNPLANNED SAFETY SYSTEM ACTUATIONS -(INPO DEFINITION)

There were no unplanned safety system actuations during the month of November 1993. The Cycle 15 Refueling Outage, which began on September 25, ended on No-vember 26.

The last unplanned safety system actuation occurred during the month of July 1992 and was due to the loss of an inverter and the subsequent reactor trip on 7/3/92.

The 1993 and 1992 goals for the number of unplanned safety system actuations are zero.

Data Source: Monthly Operations Report & Plant Licensee Event Reports (LERs)

Accountability: Jaworski/Foley/Ronning Positive Trend l

l 27

12 Month Running Total SSAs (NRC Definition)

-+-- Critical Hours

@ Safety System Actuations (NRC Definition) lo-1000 900 8

800 g-H ii 700 e l

2 cyde 14 3

Q 6-Refuehng 600 o fr, uta9e 500 g 4

-400 g

4-g 300 0 2

32-e 200 o

^

'90 '91 '92 DJFMAMJJASONDJFMAMJ JASO Cycle 15 1991 1992 1993 Refuehng Outage 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 Emer-gency Diesel Generators. The NRC classification of SSAs includes actuations when major equipment is operated and when the logic systems for these safety systems are challenged.

i The last unplanned safety system actuation occurred during June 1993 when the inndvertent jarring of a 345 KV fault relay in the switchyard caused a turbine and reactor trip.

An unplanned safety system actuation occurred on April 30,1993 when a non-licensed operator mistakenly opened the wrong potential fuse drawer causing a low voltage alarm on bus 1 A1, a loadshed on bus 1 A1 and an auto start of an EDG.

An unplanned safety system actuation occurred on August 22,1992 due to the failure of an AC/

DC converter in the Turbine Electro Hydraulic Control system. Pressurizer safety valve RC-142 then opened prior to reaching design pressure during a plant transient and trip.

Two unplanned safety system actuations occurred in July 1992: 1) On July 3 there was an inverter failure and the subsequent reactor trip; 2) On July 23 there was an unplanned diesel generator start when an operator performing a surveillance test inadvertently pushed the normal start button instead of the alarm acknowledge button.

An unplanned safety system actuation occurred on May 14,1992 when the turbine generator tripped on a false high level moisture separator trip signal which caused a simultaneous reactor trip and subsequent anticipatory start signal to both diesel generators.

There have been 0.50 unplanned safety system actuations/ quarter for the last 12 months. The 1993 and 1992 Fort Calhoun goals for this indicator are 0.

Data Source: Monthly Operations Report & Plant Licensee Event Reports (LERs)

Accountability: Jaworski/Foley/Ronning Adverse Trend: None 28

5 Monthly Gross Heat Rate

-A--

Year-to-Date Gross Heat Rate lG00Dl V

O 1993 Fort Calhoun Goal 10.5-10304 10300 Cycle 15 Refuehng g

Ed E

Outage i

10177 e

z 5

m 10-a

.c

....z 9.5 -

g,

',...u

'90

'91

'92 Dec92 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov93 j

GROSS HEAT RATE This indicator shows the Gross Heat Rate (GHR) for the reporting month, the year-to-

']

date GHR, the 1993 goal and the year-end GHR for the previous 3 years.

The gross heat rate for Fort Calhoun Station was not calculated for the months of Octo-ber and November 1993 because of the Cycle 15 Refueling Outage.

l 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 i

Fahrenheit.

The year-to-date gross heat rate was reported as 10,234 BTU /KWH at the end of Sep-tember.

The 1993 year-end gross heat rate goalis a maximum of 10,168 BTU /KWH.

i l-Data Source: Holthaus/ Gray (Manager / Source)

Accountability: Chase /Jawors'Ki t

i Adverse Trend: None L

1

~

G Monthly Thermal Performance

--et-1992 Year-to Date Average Monthly Thermal Performar.ce

--+-- 1993 Year-to-Date Average Monthly Thermal Performance I GOOD l

- O---

1993 & 1992 Fort Calhoun Goals

~&-

1995 INPO Industry Goal (99.5%)

--{"}--

Industry Upper 10% (99.9%)

C C

C D

C C

U""

N" C

C

~

Thermal rg p

a 6

P rfum ---

r f

g 99% -

, required or Cycle 15 trendable Refueling l

below l C Outage

(

80%

fx Y.

$g h

98 %

4 _

" - - -j pg power Dec92 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov93 THERMAL PERFORMANCE This indicator rhows the Thermal Performance value for the reporting month, the year-to-date average thermal performEnce value, the 1993 and 1992 Fort Calhoun goals, the 1995 iNPO industry goal and the approximate industry upper ten percentile value.

The thermal performance value for the months of November and October 1993 was not cal:ulated due to the Cycle 15 Refueling Outage. The average monthly thermal perfor-mance value from January through November (excluding April, October and November) was 99.4%. The average monthly value for the last 12 months (excluding April, October and November) is 99.4%.

The thermal performance value for April 1993 could not be calculated (per INPO guid-ance) because the plant was operated at less than 80% power from April 1 through 23 prior to the maintenance outage.

j The decline in thermal performance values through March was attributed to circulating water flow reductions possibly caused by condenser fouling and/or circ. water pump degradation. Inspection of CW-1B during the "B" cell outage on 4/93 showed no abnor-mal degradation of the pump impeller. Inspections during the April maintenance outage indicated considerable fouling of condenser tubes, a leaking divider plate gasket in FW-4B, and a tom backwash valve seat. The condenser was cleaned and equipment repairs made.

The 1993 Fort Calhoun Goal for this indicator is a minimum of 99,4%. The 1992 goal was a minimum of 99.3%. The 1995 INPO industry goalis 99.5% and the industry upper ten percentile value (for the one year period from 7/92 through 6/93) is approxi-mately 99.9%.

Data Source: Jaworski/Popek Accountability: Jaworski/Popek 3

Adverse Trend: None 30 i

O Thermal Output

-O--

Fort Calhoun 1495 MW Goal

- Tech Spec 1500 MW Limit 1500 -

1400 -

1300 -

1200 -

1100 -

1000 -

g 900 -

CYCLE 15 I

y REFUELING

$ 800-OUTAGE

E j 700-600 -

500 -

400 -

300 -

200 -

100 -

0-1 3

5 7

9 11 13 15 17 19 21 23 25 27 29 DAILY THERMAL OUTPUT The thermal output graph displays the daily operating power level during November 1993, the 1500 thermal megawatt average technical specification limit, and the 1495 thermal megawatt Fort Calhoun goal. The Cycle 15 Refueling Outage ended on No-vember 26.

Data Source: Hohhaus/ Gray (Manager / Source)

Accountability: Chase / Tills Adverse Trend: None 31

'~

--M--

Equipment Forced Outage Rate /1,000 Critical Hours

--O--

1993 Fort Calhoun Goal (r:,0.20) 0.75-GOOD V

0.53 0.5 0.5 -

Cycle 15 Refueling Outage 0.25-C O

O O

i i

0 0,0,0,=,0,

,0,0,0,=

,0,

'90

'91

'92 Jan93 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec93 EQUIPMENT FORCED OUTAGES PER 1,000 CRITICAL HOURS The equipment forced outage rate per 1,000 critical hours was 0.0 for the months from January through November 1993. The value for the last 12 months is 0.0.

The last equipment forced outage occurred in August 1992 and continued through September. It was due to the failure of an AC/DC converter in the Turbine Electro Hydraulic control System.

The 1993 Fort Calhoun goal for this indicatoris a maximum value of 0.20.

Data Source: Monthly Operations Report & Plant Licensee Event Reports (LERs)

Accountability: Chase /Jaworski Positive Trend 32

. # of Cornponent Categories 40-

+ # of Application Categories 35-

--*- Total # of Categories m 30-2 f

315-

/

0 h

3.y

_ m" 10-5-

0 J92 J A

S O

N D92 J93 F M

A M

J J

A S

O N93 E WearOut/ Aging D OtherDevices

@ Manufacturing Defect O uaintenance/ Testing O Engineering / Design

@ Error 46.0%

10.0%

Percent of Total Failures During the 10 0%

Past 18 Months

/

l t

/

$ [.

6.0%lllll 27.0%

COMPONENT FAILURE ANALYSIS REPORT (CFAR)

SUMMARY

l The top chart illustrates the number of component categories, application categories and total j

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 months (from March 1992 through August 1993). Fort Calhoun Station reported a higher failure rate in 7 of the 87 component categories (valves, pumps, motors, etc.) during the past 18 months. The station reported a higher failure rate in 7 of the 173 application categories (main steam stop valves, auxiliary /

emergency feedwater pumps, control element drive motors, etc.) during the past 18 months.

The pie chart depicts the breakdown by INPO cause categories (see the " Definitions" section of this report for descriptions of these categories) for the 83 failure reports that were submitted to INPO by Fort Calhoun Station during the past 18 months. Of these, the failure cause was known for 70. The pie chart reflects known failure causes.

Data Source: Jaworski/ Dowdy (Manager / Source)

Accountability: Jaworski/ Dowdy Adverse Trend: None 33 i

Components With More Than One Failure l GOOD l X

Components With More Than Two Failures V

25-21 20 -

18 15-11 11 11 11 10-9 9

5 4

O Dec92 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov93 REPEAT FAILURES The Repeat Failures Indicator (formerly called the " Maintenance Effectiveness" perfor-mance indicator) was developed in response to guidelines set forth by the Nuclear Regulatory Commission's Office for Analysis and Evaluation of Operational Data (NRC/

AEOD). The NRC requirement for a Maintenance Effectiveness Performance Indicator has been dropped, but station management considers it useful to continue to track repetitive component failures using the Nuclear Plant Reliability Data System (NPRDS).

This indicator shows the number of NPRDS components with more than one failure during the last eighteen months and the number of NPRDS components with more than two failures during the last eighteen months.

During the last 18 reporting months there were 9 NPRDS components with more than 1 failure. 2 of the 9 had more than two failures. The tag numbers of the components with more than two failures are AC-10C and CH-18. Recommendations and actions to correct these repeat component failures are listed in the quarterly Component Failure Analysis Report.

Data Source: Jaworski/ Dowdy (Manager / Source)

Accountability: Chase /Bobba Adverse Trend: None 34

j 6-Calculated Check Valve Failure Rate per Million Cornponent Hours 5-

-A-Industry Check Valve Failure Rate per Million Component Hours l

--O-Fort Calhoun Goal l GOOD l

+

u>b i

A A

M A

2-C O

O O

1 1

1

'90 91 92 Dec92 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov93 No. of Check Valve Failures CHECK VALVE FAILURE RATE This indicator shows the calculated Fort Calhoun check valve failure rate, the Fort Calhoun goal and the industry check valve failure rate. This rate is based upon failures during the previous 18 months. The number of check valve failures at Fort Calhoun Station for the previous three years are shown on the left.

The data for the industry check valve failure rate is three months behind the reporting -

month due to the time involved in collecting and processing the data.

i For August 1993, the Fort Calhoun Station reported an actual check valve failure rate of 0.0, while the industry reported an actual failure rate of 2.31 E-6. At the end of Novem-ber 1993, the Fort Calhoun Station reported a calculated check valve failure rate of 0.0.

The 1993 and 1992 Fort Calhoun goals for this indicator are a maximum failure rate of 2.00 E-6.

Data Source: Jaworski/ Dowdy (Manager / Source)

Accountability: Jaworski/Rollins Positive Trend SEP 43 35

25000-Cumulative Dry Active Waste Sent For Processing (in cubic foot) 20000-15000-10000-5000-0 17,',

Jan93 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec93 5

Radioactive Waste Buried This Month (in cubic feet)

Cumulative Radioactive Waste Buried

-O-Fort Calhoun Goal For Waste Buried -

1995 INPO Industry Goal (3,884 cubic feet)

-O-Industry Upper 10% (1,740.2 cubic feet) 4000 -

A A

A 3000-ms F/

2000-

/

O O

jy7p//s 1334 y

1000-C O

'91

'92 Jan93 Feb Mar Apr May Jun Jul Aug sep Oct Nov Dec93 Year-end Total VOLUME OF LOW-LEVEL SOLID RADIOACTIVE WASTE The upper graph shows the volume of dry radioactive waste sent for processing. The lower graph shows the volume of the monthly radioactive waste buried, the cumulative annual total for radioactive waste buried, and the year-end totals for radioactive waste buried the previous 2 years.

Curnulative amount of solid radwaste shipped off-site for processing (cubic feet) 12,740.0 Amount of solid radwaste shipped off site for processing during November (cubic feet) 4,160.0 Volume of Solid Radwaste Buried during November (cubic feet) 26.3 Cumulative volume of solid radioactive waste buried in 1993 (cubic feet) 505.2 Amount of solid radioactive waste in temporary storage (cubic feet) 0.0 The 1993 Fort Calhoun goal for the volume of solid radioactive waste which has been buried is 1,000 cubic feet. The 1995 INPO industry goalis 110 cubic meters (3,884 cubic feet) per year. The industry upper ten percentile value from 7/90 through 6/93 is approximately 49.27 cubic meters (1,740.22 cubic feet) per year.

Data Source: Chase /Breuer (Manager / Source)

Accountability: Chase /Lovett Adverse Trend: None iP 54 36

+

4 E

Primary System Chemistry Percent of Hours Out of Limit l GOOD l 3%-

-O-Fort Calhoun Goal ( 2%)

2%-

C O

O O

O Cycle 15 Refueling Outage 1%-

?

{

l f

0%

i i

i Dec92 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov93 PRIMARY SYSTEM CHEMISTRY PERCENT OF HOURS OUT OF LIMIT The Primary System Chemistry Percent of Hours Out of Limit indicator tracks the pri-mary system chemistry performance by monitoring six key chemistry parameters. The key parameters are: lithium, dissolved oxygen, chlorides, fluoride, hydrogen and sus-pended solids.100% equates to all six parameters being out of limit for the month.

The Primary System Chemistry Percent of Hours Out of Limit was 0.0% for the month of November 1993. The Cycle 15 Refueling Outage ended at 6:15 a.m. on November 26.

The 1993 and 1992 Fort Calhoun monthly goals for this indicator are a maximum of 2%

Hours Out of Limit.

Data Source: Smith / Spires (Manager / Source)

Accountability: Chase / Smith Adverse Trend: None j

i 37

)

E secondary System CPI

-O-Fort Calhoun Goal l GOOD l k

-tr--

1995 INPO Industry Goal (0.30) 1.5 -

l Secondary System CPI Limit

-O-Industry Upper 10% (0.18) 1-l l

l l

Cycle 15 0.5 -

Ou e

i i

I i

i e

i i

'90

'91 Dec92 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov93 3_l GOOD l E % of Hours Chemistry is Outside OG Guidelines k

q%

l

??

Cycle 15 1%-

y 3

Refueling

.J Outage 0%

i i

Dec92 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov93 SECONDARY SYSTEM CHEMISTRY The top graph, Secondary System Chemistry Performance Index (CPI), is calculated using the following three parameters: cation conductivity in steam generator blowdown, sodium in steam generator blowdown, and condensate pump discharge dissolved oxygen. The bottom graph shows the percent of total hours of 13 parameters exceed-ing the Owners Group (OG) guidelines during power operation.

The CPI and percent of hours outside the OG guidelines were not reported for the months of October and November 1993 because the plant was shutdown for the Cycle 15 Refueling Outage. The average monthly CPI for the last 12 months (excluding October and November) is 0.526.

The 1993 Fort Calhoun monthly goal for the CPIis a maximum value of 0.60. The INPO 1995 Industry goalis 0.30. The Fort Calhoun goalis based on site specific chem-istry treatment,i.e. morpholine. The INPO goal does not consider the influence of morpholine and the by-products of morpholine from thermal decomposition.

The industry upper ten percentile value for this indicator was approximately 0.18 for the twelve months from 7/92 through 6/93.

Data Source: Smith / Spires (Manager / Source)

Accountability: Chase / Smith Adverse Trend: None 38

COST Goal: To operate Fort Calhoun Station in a manner that cost efTectively maintains nuclear generation as a viable source of electricity.

4 1

l l

39

I l

~ Actuals

-O-Budget A

Plan l

3.75-3.5 -

I3xg325-4 80 3-l l

2.75-2.5 D91 D92 J93 F M

A M

J J

A S

O N D93 D94 D95 D96 D97 j

Months CENTS PER KILOWATT HOUR l

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 kilo-watt hour on a 12 month rolling average for the current year. The basis for the budget curve is the approved 1993 budget. The basis for the actual curve is the Financial and Operating Report.

I The December 31 amounts are also shown for the prior years 1991 and 1992. In addi-tion, the report shows the plan amounts for the years 1994 through 1997 for reference.

The basis for the dollars are the Nuclear Long Range Financial Plan and the 1993 Corporate Planning and Budget Review. The basis for the generation is provided by Nuclear Fuels.

The unit price before August 1993 was averaging higher than budget due to the forced outages experienced in July and August 1992. The increase in June 1993 is due to the forced outage. Unit price is lower than budget in September since the 1992 forced outages are out of the 12 month average end the one-week delay in the refueling out-age allowed for more generation and lower outage costs than budgeted in September.

Data Source: Scofield/Jamieson (Manager / Source)

Accountability: Scofield Adverse Trend: None 40

O Actuai oivision starting O Autnorized civision starting

~

4 457 400 -

300 -

192 1M 200_

estg sa 117 122 i

M%$jj'

'i 100-e s

45 r

a1 s'

O i

i i

Nuclear Operations Production Engineering Nuclear services STAFFING LEVEL The authorized and actual staffing levels at the end of November 1993 are shown for the three Nuclear Divisions.

Data Source: Ponec (Manager & Source)

Accountability: Ponec Adverse Trond: None SEP 24 i

I 41 j

17-Spare Parts inventory Value ($ Million)

Cycle 15

=

Refueling Outage 16-15-14 -

f 13-12-11 -

10 Dec92 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov93 SPARE PARTS INVENTORY VALUE The spare parts inventory value at the Fort Calhoun Station at the end of November 1993 was reported as $15,763,195.

Data Source: Steele/Huliska (Manager / Source)

Accountability: Willrett/McCormick Adverse Trend: None l

42

DIVISION AND DEPARTMENT PERFORMANCE INDICATORS These indicators may be deleted from this report if the responsible group con-tacts the Manager - Station Engineering to request their removal. Indicators referencing SEP ltems require documentation to ensure that the original intent and scope of the SEP ltem will not be altered by removal of the indicator from this

report, 43 I

10000 -

9000-O TotatBackiog(uanhours) 10000-B Backlog >3 uonths Oid (uanhours) 9000-8000-8000-7000-Cycle 15 7000-Cycle 15 e,

g 6000-Refueling

$ 6000-Refueling g 5000-Outage 2 5000-Outage g 4000-E 4000_

3000 -

2492 2594 2

3000-2000-1605 I8 2000-1371

~

NWhW$

n I

i i

i September'93 October'93 November'93 September 33 October'93 November 93 Safety Related Backlog Safety Related Backlog >3 g (Manhours) 5000-Months Old (Manhours) 5000 -

4000 -

4000-2 Cycle J5 2

Cycle 15 g 3000-Refueling g 3000-Refueli5 Outage r

r E 2000-E2000_

Outage 2

1126 1138 2

gg4 980 k

kk

?hk'0'h h

Q R]

I I

I September'93 October'93 November'93 September'93 October'93 November'93 O High Priority Backlog (Manhours) e 1500-E Cycle 15 j

~

Refueling 2 500 -

Outage 0

0 0

~

0 September'93 October 93 November '93 MAINTENANCE WORKLOAD BACKLOGS (CORRECTIVE NON-OUTAGE)

This indicator shows the estimated manhours for corrective non-outage MWOs remain-ing open at the end of the reporting month, along with a breakdown by several key categories.

Action plans for adverse trends will not be addressed until after January 1,1994 be-cause of the inability to perform non-outage work during the Cycle 15 Refueling Outage.

Data Source: Chase /Schmitz (Manager / Source)

Accountability: Chase /Bobba Adverse Trend: None SEP 36 44

O Ratio of Preventive to TotalMaintenance 100% -

90%-

80%-

ei w

s a

se 70% -

g f

p

g r

'a 60%-

g#

4 50%-

?

f y

g si

y J

40%-

g 4;[

4

^^

8 3;f" 30%-

5

+

~

20%-

~

10%-

[

g

')

W 0%

Dec92 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov93 2%-

O Preventive Maintenance items Overdue l GOOD

-O-Fort Calhoun Goal y

Data 1%-

Unavailable due to Cycle C

O Q-- O - -O-O --C O

O 2.

15 Refueling Outage I

I 0%

4 I

I I

i i

i 4

Dec92 Jan Feb Ma Apr May Jun Jul Aug Sep Oct Nov93 RATIO OF PREVENTIVE TO TOTAL MAINTENANCE & PREVENTIVE MAINTENANCE ITEMS OVERDUE The top graph shows the ratio of completed non-outage preventive maintenance to total completed non-outage maintenance.

The ratio of preventive to total maintenance was 91.76% in November 1993.

l The lower graph shows the percentage of preventive maintenance items overdue. Due to the Cycle 15 Refueling Outage, data for the month of November was unavailable.

The 1993 and 1992 Fort Calhoun goals are to have less than 0.5% per month of the preventive maintenance items overdue.

Accountability: Chase /Bobba Data Source: Chase /Schmitz1Brady(Manager / Sources)

Adverse Trend: None SEP 41 l

45

Rework As identified By Planning or Craft

--O-1993 Fort Calhoun Goal (<4.0%)

4%-

C O

O O

Cycle 15

]

Refueling f

Outage j 3*/.~

2.71 %

u) 2.56 %

2.57 %

O

$mphUN 2.38 %

w

..~

44-4 2

2.13%

r'--

n m.a. y 5 2%-

1.82 %

H

.... j:

p.r;.a ss a.

]

y.

i:. y:'ir:Q

}[- g.:

M '%,. [

..[

o

~. :;;;

.}

(; y' @{

~

0 1%-

1 y;g.]

}l:gQ Q._.;;

+.m :,

u.

a.; i

,.u. ;

~.

v.

a

.l

.s. '.;;

r,. g

.c..q

.. q.

.7,..>,.

,- :.g,, y a._,

y _,n.,yy

_.../

0%

.,.f i

Jun93 Jul Aug Sep Oct Nov93 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.

The 1993 goal for this indicator is to maintain less than 4% rework per month.

Data Source: Bobba/Schmitz (Manager / Source)

Accountability: Chase /Bobba Positive Trend 46

=

i E

Maintenance Overtime 80%-

I

-M--

12 Month Average Maintenance Overtime

+

70%-

-O-Fort Calhoun "On-Line" Goal 60%-

50%-

Cyde 15 Refueling Outage l

40% -

h l g 30%-

I h 20%-

18 y

g h l l

10*/. -

O O

g (

]

0%

M A

t Dec92 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov93 t

MAINTENANCE OVERTIME l

1 The Maintenance Overtime Indicator monitors the ability to perform the desired mainte-nance activities with the allotted resources.

j

-i The percent of overtime hours with respect to normal hours was reported as 36.1% for the month of November 1993. The 12 month average percentage of overtime hours with respect to nbrmal hours was reported as 12.32% at the end of the month.

The 1993 and 1992 Fort Calhoun goals for the "on-line" percentage of maintenance

'l overtime hours worked are a maximum of 10%

i Data Source: Chase /Schmitz (Manager / Source)

Accountability: Chase / Bobba Adverse Trend: None 1

j 47

~. -.

O Open irs Related to the Use of Procedures (Maintenance)

@ Closed irs Related to the Use of Procedures (Maintenance) 3 Procedural Noncornpliance irs (Maintenance) 2-l l

1-0 !. 0 000 000 000 000 00 000 000 000 0 0

00 000 I

I I

I l

Dec92 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov93 PROCEDURAL NONCOMPLIANCE INCIDENTS (MAINTENANCE)

This indicator shows the number of open Maintenance incident Reports (irs) that are related to the use of procedures, the number of closed irs that are related to the use of procedures, and the number of open and closed irs that received procedural noncom-pliance cause codes for each of the last twelve months.

There were no procedural noncompliance incidents for maintenance reported for the month of November 1993.

Data Source: Chase / Keister (Manager / Source)

Accountability: Chase /Bobba Adverse Trend: None SEP 15,41 & 44

5 Completed Scheduled Activities (AllCrafts)

D Numberof Emergent MWOs Completed O

Fort Calhoun Goat ( 85%)

110 j 100%-

100 h 90%-

90 y

O 2

Q-80%-

8 73.5 %

20 E E 70%-

b 70 8

Cycle 15 m

5 60% -

Refueling 30 $

j Outage

s 50%-

48 50 i:

~

'//:

YI:

Data Not

0 E 5 30% -

?I:

Available 30 b

g:

s o

E 20%-

'//

20 f 5

Z g 10%-

pp; 10 b

0%

O August '93 September Oc1ober November '93 PERCENT OF COMPLETED SCHEDULED MAINTENANCE ACTIVITIES (ALL MAINTENANCE CRAFTS)

This indicator.shows the percent of the number of completed maintenance activities as compared to the number of scheduled maintenance activities concerning all Mainte-nance Crafts. Maintenance activities include MWRs, MWOs, STs, PMOs, calibrations, and miscellaneous maintenance activities. The number of emergent MWOs completed for the month is also shown.

Because of the Cycle 15 Refueling Outage, data for this indicator will not be available until after the first month on-line during Cycle 15.

The 1993 Fort Calhoun Station monthly goal for the percent of completed scheduled maintenance activities is a minimum of 85%.

Data Source: Chase /Schmitz (Manager / Source)

Accountability: Chase /Bobba Adverse Trend: None SEP 33 49

O Number of instruments Out-of-Service

-O-Fort Calhoun Goal y

24 q 20-M

~ I4_;_.

18 Cycle 1s 18 Refueling 16 16-34 Outage 11 12 -

gg 0

Dec92 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov93 IN-LINE CHEMISTRY INSTRUMENTS OUT-OF-SERVICE This indicator shows the total number of in-line chemistry system instruments out-of-service at the end of the reporting month. The chemistry systems involved in this indi-cator include the Secondary System and the Post Accident Sampling System (PASS).

At the end of November 1993 there was a total of 10 in-line chemistry instruments out-of-service. Of these 10 instruments,9 were from the Secondary System and 1 was from PASS.

The trend for PASS instruments for this reporting period has not changed. The trend for Secondary instruments this reporting period has increased to 9 due to water plant instrumentation failure. 2 instruments (CPD and FH-6 oxygen) remain out-of-service at the Al-125/126 panel and are awaiting replacement under an ECN.1 instrument is out-of-service on Al-107 because of recorder failure and 2 are out-of service because of failed function checks and awaiting repair. 4 instruments are out-of-service on Al-104 because of failed function checks or malfunctions. The dissolved oxygen meter on Al-105 was returned to service following repairs.

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.

The 1993 Fort Calhoun goal for the number of in-line chemistry system instruments that g

j are out-of-service has been set at a maximum of 5. The 1992 goal was a maximum of

6. Six out-of-service chemistry instruments make up 10% of all the chemistry instru-ments that are counted for this indicator.

Data Source: Chase /Renaud (Manager / Source)

Accountability: Chase /Jaworski Adverse Trend: None 50

Waste Produced Each Month (Kilograms)

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

-EB--

Fort Calhoun Monthly Average Goal (s100 Kg)

--O-Federal & State Monthly Limit (Max. of 1,000 Kg) 1000 -

C O

O O

800 -

$ 600-2 Eg 400-200 -

G S

S S

0 i

Dec92 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov93 HAZARDOUS WASTE PRODUCED This indicator shows the total amount of hazardous waste produced by the Fort Calhoun Station each month, the monthly average goal and the monthly average total for hazard-ous waste produced during the last 12 months. This hazardous waste consists of non-halogenated hazardous waste, halogenated hazardous waste, and other hazardous waste produced.

During the month of November 1993,0.0 kilograms of non-halogenated hazardous waste was produced,0.0 kilograms of halogenated hazardous waste was produced, and 0.0 kilograms of other hazardous waste was produced. The total for hazardous waste produced during the last 12 months is 299 kilograms. The monthly average for hazardous waste produced during the last 12 months is 24.9 kilograms.

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

The 1993 and 1992 monthly average goals for hazardous waste produced are a maxi-mum of 100 kilograms.

Date Source: Chase /Henning (Manager / Source)

Accountability: Chase /Henning Positive Trend 51

E Decontaminated Radiation Controlled Area

+

-O-Fort Calhoun Goal (non-outage months) lG00Dl 100 % -

-O-Fort Calhoun Goal (outage months)

Cycle 15 Refueling Outage 90% -

' 80% -

70%-

60%-

50%

Dec02 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov93 DECONTAMINATED RADIATION CONTROLLED AREA l

This indicator shows the percentage of the RCA that is decontaminated (clean) based l

on the total square footage. The 1993 non-outage goalis a minimum of 88% decon-taminated RCA and the outage goalis a minimum of 85% decontaminated RCA. The 1992 non-outage goal was a minimum of 88% decontaminated RCA.

At the end of the reporting month,89% of the total square footage of the RCA was not l

contaminated.

1 Data Source: Chase /Gundal(Manager / Source)

Accountability: Chase /Lovett Positive Trend SEP54 1

1 52 i

i

=

Number of identified PRWPs Cyclo 15 R

ng C

Fort Calhoun Non-Outage Goal 9

18 15-10-C C

C C

O S-3 1

1 1

o

' ~

i i

i I

4 1

I i

3 6

I I

Jan93 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec93 RADIOLOGICAL WORK PRACTICES PROGRAM The Radiological Work Practices Program Indicator shows the number of Poor Radio-logical Work Practices (PRWPs) which were identified during the reporting month. The PRWPs are identified through supervisory review of the Radiological Occurrence Re-ports and Personnel Contamination Reports written 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 November 1993, there was 1 PRWP identified. The PRWP oc-curred when an individual removed their booties and stepped on the floor in the posted CA instead of the step off pad. The individual was immediately counseled by RP super-vision and the affected area was surveyed to ensure there was not a spread of contami-nation.

The 1993 monthly non-outage goal for the number of PRWPs is a maximum of 10 per month.

Data Source: Chase / Williams (Manager / Source)

Accountability: Chase /Lovett Adverse Trend: None SEP52 53

5 Total Number of Hot Spots O

Number of Additional Hot Spots identified Removal Planned

-- + -- Cumulative Hot Spots Removed (Year-to-Date) 100-

-O-Fort Calhoun Goal for Hot Spots Removed (1/ month)

I 80-Cycle 15 Refueling i

Outage 60-

\\

q g

e A

l kf f

y j

40-h g

f a

3 E

I l'

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O-i Jan93 Feb Mar Apr May June July Aug Sept Oct Nov Dec93 NUMBER OF HOT SPOTS This indicator shows the total number of hot spots which have been identified to exist in the Fort Calhoun Station and have been documented through the use of a hot spot identification sheet. A hot spot is defined as a smalllocalized source of high radiation.

A hot spot occurs when the contact dose rate of an item or piece of equipment is at least 5 times the General Area dose rate and the item or piece of equipment's dose rate is equal to or greater than 100 mrem / hour in rad areas.

At the end of November 1993, there was a total of 18 hot spots identified. There were no new hot spots identified during the month. The decrease in the total number of hot spots from October to November is due to criteria defining point sources, as established in RP-306 " Hot Spot & Point Source identification and Tracking Procedure". The total number of hot spots reported prior to November included both hot spots and point l

sources.

20 hot spots were removed during the month. These hotspots were in containment and were deposted when they were closed out at the end of the uutage.

Removalis planned for 2 hot spots.

There has been a total of 46 hot spots removed in 1993.

The 1993 Fort Calhoun goalis to remove three hot spots per quarter and achieve a net I

reduction of one hot spot per quarter.

Data Source: Chase / Williams (Manager / Source)

Accountability: Chase /Lovett Adverse Trend: None i

54 l

l

- = -

=. _.

s Documents Scheduled for Review rd Documents Reviewed 250-Overdue Documents T

200-

,3 3

h 7

p 4

h 150-2 a

y 1

F l

3 3

-l 3

~

3 l

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Dec92 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov93 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 Security Plan, Maintenance Procedures, Preventive Maintenance Procedures, and the Operating Manual.

During November 1993 there were 64 document reviews completed while 51 document reviews were scheduled. At the end of November, there were 4 document reviews more than 6 months overdue.

There were 13 new documents initiated in November.

The 1993 monthly goal for this indicator is no (0) documents more than 6 months over-due.

Data Source: Chase / Keister (Manager / Source)

Accountability: Chase /Jaworski Adverse Trond: None SEP 46 55

i E Non-System Failures lGOODI V

11 12-jo 10-8-

6 5

6-4 4

4-1-

3 3

2

~

f 0

i i

Dec92 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov93

@ System Failures l GOOD l 80-l 70-y l

So -

47 l

50-38 40 -

30 31 33 30 31 32 l-27 30-rm 25 25

'F g

\\

I i

i i

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l Dec92 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov93 i

LOGG ABLE/ REPORTABLE INCIDENTS (SECURITY)

The Loggable/ Reportable Incidents (Security) Indicator is depicted in two separate graphs. The top graph depicts the total number of loggable/ reportable non-system failures concerning Security Badges, Access Control and Authorization, Security Force Error, and Unsecured Doors. The bottom graph shows the total number of loggable/

l reportable incidents concerning system failures which occurred during the reporting month.

During the month of November 1993, there were 35 loggable/ reportable incidents identi-fied. System failures accounted for 32 (90%) of the loggable/ reportable incidents.

There were 13 loggable search equipment failures during the reporting month. Explo-sive detector failures accounted for 10 of the 13 loggable equipment incidents. These failures were mainly due to the increase in usage during the 1993 refueling outage.

Efficiency should improve now that the refueling outage is complete.

Data Source: Sefick/Woerner (Manager / Source)

I Accountability: Sefick l

Adverse Trend: None SEP 58 56

l 1

5 Temporary Modifications >1 cycle old (RFO required for Removal)

C Temporary Modifications >6 months old (Removable on-line) l

{

Fort Calhoun Goals for Temporary Modifications >1 cycle old &

Temporary Modifications >6 months old (0) 8-y 7-6-

5 t}'j-5- 4 4- '//// /,' /'/ / // /,/,/// '////, '//// 3- ////, '//// g '/ / / /,. '//// ///// g hI / 1-0, t'/f4 0, //U. 0,,//// 0,~//// 0 m m v o i August '93 September '93 October '93 November '93 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 J of temporary modifications removable on-line that are greater than six months old. Also provided are the Furt Calhoun goals for temporary modifications. 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 November 1993 there i were 7 temporary modifications installed that were greater than six months old that can be removed on-line. These were: 1) Camera and mounting bracket removal, which is awaiting completion of MWO 924757; 2) Localindication for BAST CH-11 A and CH-11B, in which Operatior ' viewing a draft FLC. After review, Licensing is to issue an FLC, and the NRC is to as..se; 3) Time delay relay for PC-1902B, electrical portion of ECN to be completed by 12/31/93 to support temp mod closeout; 4) LP-30 transformer, which is awaiting NPRC review for installation date of ECN 93-183; 5) Refrigerated air dryer for Rm-057, which is awaiting installation of MR FC-84-155D, scheduled comple-tion date of 6/30/94; 6) Polar crane (HE-1) temporary power feed; and 7) Epoxy repairs to ST-4B which is open, awaiting station engineering review. At the end of November 1993, there was a total of 21 TMs installed in the Fort Calhoun Station. 3 of the 21 installed TMs require an outage for removal and 18 are removable on-line in 1993 a total of 62 temporary modifications have been installed. Data Source: Jaworski/ Tumor (Manager / Source) Accountability: Jaworski/Gorence Adverse Trend: This is not an adverse trend because: 1) outage modifications were changed to on-line removal; 2) outage work took priority over on-line temp mod removal; and 3) schedules are in place to remove 4 of these overdue temp mods by 2/1/94. SEP 62 & 71 57

I 350 - 1 E Totai uodification Packages opon 00 - 0 1993 Fort Calhoun Monthly Goal (s150) 264 l 250 - 200 - ^ ^ ^ ^ ^ ^ ^ ^ ^ O 150 - A 136 133 100 - i '90 '91 '92 Dec92 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov93 ) OUTSTANDING MODIFICATIONS This indicator shows the total number of outstanding modifications (excluding outstand-ina modifications which are orocosed to be cancelled). Cateaorv Reoorting Month Form FC-1133 Backlog /In Progress 1 Mod. Requests Being Reviewed 5 Design Engr. Backlog /In Progress 48 Construction Backlog /in Progress 34 Design Engr. Uodate Backloc/In Proaress 15 Total 103 At the end of November 1993,20 additional modification requests had been issued this year and 94 modification requests had been cancelled. The Nuclear Projects Review Committee (NPRC) had completed 213 backlog modification request reviews this year. The Nuclear Projects Committee (NPC) had completed 58 backlog modification request reviews this year. The 1993 Fort Calhoun monthly goalis a maximum of 150 total outstanding modifica-tions. Data Source: Jaworski/ Turner (Manager / Source) Scofield/Lounsbery (Manager / Source) Accountability: Scofield/Phelps Positive Trend 58

EARS Requiring Engin:sring Closecut - Not in Clossout O oEN 5 sE 40-40-40-40-00-30-30- _ 30-20 20-20- ~ 20-Sept Oct Nov sept Oct Nov Sept Oct Nov Sept Oct Nov 0-3 months 3-6 months 6-12 months >12 months November '93 Overduo EARS O Closecut O Engineering Response 60-50-40- ~ 30- _I r.-. i O i Priority 0 Priority 1 Priority 2 Priority 3 Priority 4 Priority 5 Priority 6 Priority 3 Total Open EARS Prionly 1 & 2 s 200 - 150-. Data 100 - Not 50- E E i Available i QQ 0-i i i i i i i i i i i i Dec92 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov93 O s2 overdue Respon.e. C 51 E ARs Resolved and in Closecut C 43 Overdue Closecuts O 93 EARS Requiring Response Q 49 EARS on Schedule .:as, w -.,, 29.9 % 36.1%

yg

-l ; 35.4% ' N p-@ G4,G% = ENGINEERING ASSISTANCE REQUEST BREAKDOWN This indicator shows a breakdown of the number of EARS assigned to Design Engineer-ing and System Engineering. The 1993 goal for this indicator is a maximum of 150 outstanding EARS. Total EAR breakdown is as follows: EARS opened during the month 17 EARS closed during the month 21 Total EARS open as of the end of the month 144 Data Source: Phelps/Pulverenti (Manager / Source) Accountability: Jaworski/Phelps Positive Trend SEP 62 59 l

~ 5 ECNs Backlogged in DEN 350-0 ECNs Received During the Month 300- @ ECNs Completed During the Month 250-200-150-Doc 92 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov93 ENGINEERING CHANGE NOTICE STATUS This indicator shows the number of Engineering Change Notices (ECNs) awaiting completion by DEN, the number of ECNs opened during the reporting month, and the number of ECNs completed by DEN during the reporting month. At the end of November 1993, there was a total of 169 DEN backlogged open ECNs. There were 66 ECNs received by DEN, and 43 ECNs completed during the month. Although the number of open ECNs is currently high, activities are in progress to reduce the backlog of open ECNs. Data Source: Phelps/Pulverenti (Manager / Source) Accountability: Phelps/Jaworski { Adverse Trend: None SEP 62 60 l

O DEN - Engineering not complete G System Engineering - Engineering complete, response under review @ Maintenance / Construction - MWO/CWO scheduled, but work not complete E Maintenance / Construction - MWO/CWO complete, awaiting closeout 112 120 - 100-80 - ~ 4-26 15 6 0 1 4 0 2 l .Q 2-l l _ _ 0 - 3 months 3 - 6 months > 6 months ECN FACILITY CHANGES OPEN O DEN - Engineering not complete 6 System Engineering - Engineering complete, response under review @ Maintenance / Construction - MWO/CWO scheduled, but work not complete E Maintenance / Construction - MWO/CWO complete, awaiting closeout 73 E 38 32 26 15 10 2 4 12 g 7ppppp 2 2 8 4 l [ i l I O - 3 months 3 - 6 months > 6 months ECN SUBSTITUTE REPLACEMENT ITEMS OPEN O DEN - Engineering not complete @ System Engineering - Walkdown or confirmation not complete 80 60 - 52 l N 40-20 - 10 10 3 2 0 0 - 3 months 3 - 6 months > 6 months ECN DOCUMENT CHANGES OPEN ENGINEERING CHANGE NOTICE BREAKDOWN This indicator shows a breakdown of the number of Engineering Change Notices (ECNs) that are assigned to Design Engineering Nuclear (DEN), System Engineering, and Maintenance or Construction for November 1993. The graphs provide data on ECN Facility Changes Open, ECN Substitute Replacement items Open, and ECN Document Changes Open. Data Source: Phelps/Pulverenti (Manager / Source) Accountability: Phelps/Jaworski Adverse Trend: None SEP 62 61

O Administrative Control Problem O Licensed Operator Error Q Other Personnel Error @ Maintenance Problem 3-E Design / Construction / Installation / Fabrication Problem @ Equipment Failures 2-1- ] ] 0 ~ i Doc 92 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov93 LICENSEE EVENT REPORT (LER) ROOT CAUSE BREAKDOWN This indicator shows the LERs by report date broken down by Root Cause Code for each of the past twelve months from December 1,1992 through November 30,1993. The cause codes are intended to identify possible programmatic deficiencies. For detailed descriptions of these codes, see the " Performance Indicator Definitions" section of this report. There was 1 LER submitted in November 1993. Data Source: Short/Cavanaugh (Manager / Source) Accountability: Chase Adverse Trend: None 62

O Total Requalification Training Hours O simuiator Training Hours Q Non-Requalification Training Hours ) 50-B Numberof Exam Failures 40-36 33 33 33 33 ~ 30 30-27 I 20-U 13 12 10-a 7 7 7 _7 0 Cycle 92-7 Cycle 93-1 Cycle 93-2 Cycle 93-3 Cycle 93-4 Cycle 93-5 Cycl 6 93-6

Note: The Simulator was out-of service for maintenance and modifications during Cycle 92-7 and Cycle 93-6.

LICENSED OPERATOR REQUALIFICATION TRAINING This indicator provides information on the total number of hours of training given to each crew during each cycle. The Simulator training hours shown on the graph are a subset of the total training hours. Non Requalification Training Hours are used for AOP/EOP verification & validation, INPO commitments, GET, Fire Brigade, Safety Meetings, and Division Manager lunches. Exam failures are defined as failures in the written, simulator, and Job Performance Measures (JPMs) segments of the Licensed Operator Requalification Training. There were 3 written exam failures during Cycle 93-6. All 3 individuals who failed the written exam were removed from licensed operator duties for remediation. Remediation was completed and all 3 individuals were subsequently returned to their licensed opera-tor duties. There was no impact on shift operations. The simulator was shutdown for maintenance and modifications during this training cycle. Data Source: Gasper / Lazar (Manager / Source) Accountability: Gasper / Lazar Adverse Trend: None SEP 68 63

O S O Exams Mministerd 15-O saO Exams eassed E RO Exams Administered O RO Exams Passed 10-l NRC Exams 5- / ) 3 5 l / / 0 Dec92 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov93 LICENSE CANDIDATE EXAMS This indicator shows the number of Senior Reactor Operator (SRO) and Reactor Opera-tor (RO) quizzes and exams taken and passed each month. These internally adminis-tered quizzes and exams are used to plot the SRO and RO candidates' monthly progress. There were no OPPD Reactor Operator or Senior Reactor Operator exams adminis-tered during November 1993. Currently, there is no Hot License class being conducted. The next class is tentatively scheduled to begin in April 1994. Data Source: Gasper / Lazar (Manager / Source) Accountability: Gasper / Lazar Adverse Trend: None SEP 68 64

O TotalOpen CARS 8 Total Open irs @ Open CARS > Six Months Old 2 Open irs > Six Months Old Cycle 15 240 - Refuehng 240 Outage 200-200 160-160 I 120 120-80 8U ~ ~ [ 5 5 I 2 ' I ! I ~ 40 40- "d N _a" ~2 5 h 7 t + m i N ."y 7lmj l. 7 / / 0 0 i i i i i i i i i i i i Dec92 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov93 I Cycle 15 60 - E Open Significant CARS O Open SignificantiRs ne,ueiing 50 - Outage g 40-3 30 - 25 d 24 2{ 21 20 - 10-4 3 3 3 3 2 2 2 2 2 2 2 0 i i Dec92 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov93 OPEN CORRECTIVE ACTION REPORTS AND INCIDENT REPORTS This indicator shows the total number of open Corrective Action Repods (CARS), CARS >6 months old, the total number of Open irs, irs >6 months old, the number of open significant CARS and the number of open significant irs. l At the end of November 1993 there were 67 open CARS.13 of these CARS were greater than 6 months old. There were 2 Open Significant CARS at the end of the month. Also, at the end of November there were 225 open irs. 37 of these irs were greater than 6 months old. There were 45 Open Significant irs at the end of the month. The 1993 monthly goal for the number of CARS greater than 6 months old is a maxi-mum of 30. l Data Source: Orr/Gunis (Manager / Source) & CHAMPS Accountability: Andrews/Gambhir/ Gates Adverse Trena: None 65

.4 m ,44 L-4 a-- -h--C k2"--#A 4 - - - -'r--- 4*-- h1-a h 8 4 ACTION PLANS FOR ADVERSE TRENDS j 66

ACTION PLANS FOR ADVERSE TRENDS This section lists action plans that have been developed for the performance indicators cited as exhibiting adverse trends during the three months preceding this report. There have been no performance indicators cited as exhibiting adverse trends during the three months preceding this report. P ') J a l 3 h i 1 67

= PERFORMANCE INDICATOR DEFINITIONS AUXILIARY FEEDWATER SYSTEM SAFETY SYSTEM CENTS PER KILOWATT HOUR PERFORMANCE The purpose of this indicator is to quantify the economi-The sum of the known (planned and unplanned) unavail-cal operation of Fort Calhoun Station. The cents per able hours and the estimated unavailable hours for the kilowatt hour indicator represents the budget and actual auxiliary feedwater system for the reporting period di-cents per kilowatt hour on a 12 month rolling average for vided by the critcal hours for the reporting period multi-the current year, The basis for the budget curve is the plied by the number of trains in the auxiliary feedwater approved 1993 budget. The basis for the actual curve is system. the Financial and Operating Report. CHECK VALVE FAILURE RATE CONTAMINATIONS 22,000 COUNTS / MINUTE PER Compares the Fort Calhoun ched valve f ailure rate to PROBE AREA the industry check valve f ailure rate (f ailures per 1 million Reportab:e skin and clothing mntaminations. This indi-component hours). The data for the industry failure rate cator tracks personnel performance for SEP #15 & 54. is three months behind the Pl Report reporting month. This indcator tracks performance for SEP #43. DAILY THERMAL OUTPUT This indicator shows the daily core thermal output as COLLECTWE RADIATION EXPOSURE measured from computer point XC105 (in thermal mega-Collective radiation exposure is the total external whole-watts). The 1500 MW Tech Spec limit, and the unmet body dose received by all on-site personnel (including portion of the 1495 MW FCS daily goal for the reporting contractors and visitors) during a time period, as mea-month are also shown. sured by the thermoluminescent dosimeter (TLD). Col-lective radiation exposure is reported in units of person-DIESEL GENERATOR RELIABILITY (25 DEMANDS) rem. This indicator tracks radiological work performance This indicator shows the number of f ailures occurring for for SEP #54. each emergency diesel generator during the last 25 start demands and the last 25 load-run demands. COMPONENT FAILURE ANALYSIS REPORT (CFAR)

SUMMARY

DECONTAMINATED RADIATION CONTROLLED The number of INPO categories for Fort Calhoun Station AREA with signifcantly higher (1.645 standard deviations) fail-The percentage of the Radiation Controlled Area, which ure rates than the rest of the industry for an eighteen includes the auxiliary building, the radwaste building, and month time period. Failures are reporlod as mmponent areas of the C/RP building, that is demntaminated based (i.e. pumps, motors, valves, etc.) and application (i.e. on the total square footage. This indcator tracks perfor-charging pumps, main steam stop vatves, control ele-mance for SEP # 54. ment drive motors, etc.) categories. Failure Cause Categories are: DISABLING INJURY /lLLNESS FREQUENCY RATE Wear Out/ Aging - a failure thought to be the conse-(LOST TIME ACCIDENT RATE) quence of expected wear or aging. This indicator is defined as the number of acx:idents for Manuf acturing Def ect - a f ailure attnbutable to inad-all utility personnel permanently assigned to the station, equate assembly or initial quahty of the responsible com-involving days away from work per 200,000 man-hours ponent or system. worked (100 man-years). This does not include contrac-Engineering /Desigri - a f ailure attributable to the inad-tor personnel. This indicator tracks personnel perfor-equate design of the responsible component or system. mance for SEP #25 & 26. Other Devices - a f ailure attributable to a f ailure or misoperation of another component or system, including DOCUMENT REVIEW (BIENNIAL) associated devices. The Document Review Indicator shows the number of Maintenance / Testing - a f ailure that is a rs sult of im-documents reviewed, the number of documents sched-proper maintenance or testing, lack of maintenance, or uled for review, and the number of document reviews ( personnel errors that occur during maintenance or test-that are overdue for the reporting month. A document ing activities performed on the responsible component or review is considered overdue if the review is not com-system, including failure to follow procedures. plate within 6 months of the assigned due date. This Errors f ailures attributable to inwrrect procedures that indicator tracks performance for SEP #46. were followed as wntten, improper installation of equip-ment, and personnet errors (including f ailure to follow EMERGENCY AC POWER SYSTEM SAFETY SYSTEM procedures properly). Also included in this category are PERFORMANCE failures for whid the cause is unknown or cannot be as-The sum of the known (planned and unplanned) unavail-sgned to any of the preceding categories. able and the estimated unavailable hours for the emer-gency AC power system for the reporting period divided by the number of hours in the reporting period multiplied by the number of trains in the emergency AC power sys-tem. 68

PERFORMANCE INDICATOR DEFINITIONS (Cont'd) EMERGENCY DIESEL GENERATOR UNIT RELIABIL-EMERGENCY DIESEL GENERATOR UNRELIABlUTY ITY This indicator measures the total unreliability of emer. This indicator shows the number of failures that were gency diesel generators. In general, unreliability is the reported during the last 20,50, and 100 emergency die-ratio of unsuccessful operations (starts or load-runs) to sel generator demands at the Fort Calhoun Station. Also the number of valid demands, Total unreliabiltty is a ) shown are trigger values which correlate to a high level combination of start unreliabilrty and load-run of confidence that a unit's diesel generators have ob-unreliability. tained a reliability of greater than or equal to 95% when the demand f ailures are less than the trigger values. ENGINEERING ASSISTANCE REQUEST (EAR)

1) Number of Start Demands: All valid and inadvertent BREAKDOWN start demands, including all start-only demands and all This indicator shows a breakdown, by age and priority of start demands that are followed by load-run demands, the EAR, of the number of EARS assigned to Design En-whether by automatic or manualinitiation. A start only gineering Nuclear and System Engineering. This indica-demand is a demand in which the emergency generator for tracks performance for SEP #62.

is started, but no attempt is made to load the generator.

2) Number of Start Failures: Any failure within the emer-ENGINEERING CHANGE NOTICE (ECN) BREAK-gency generator system that prevents the generator frorn DOWN achieving specified frequency and voltage is classified as This indicator breaks down the number of Engineering a vahd start failure. This includes any condition identified Change Notices (ECNs) that are assigned to Design in the course of maintenance inspections (with the emer-Engineering Nuclear (DEN), System Engineering, and gency generator in standby mode) that definitely would Maintenance. The graphs provide data on ECN Facility have resulted in a start failure if a demand had occurred.

Changes open, ECN Substitute Replacement Parts

3) Number of Load-Run Demands: For a valid load-run open, and ECN Document Changes open. This indicator i

I demand to be counted the load-run attempt must meet tracks performance for SEP #62. one or more of the following enteria: A) A load-run of any duration that results from a real au-ENGINEERING CHANGE NOTICE (ECN) STATUS tomatic or manualinitiation. The number of ECNs that were opened, ECNs that were B) A load-run test to satisfy the plant's load and duration completed, and open backlog ECNs awaiting completion i as stated in each test's specifications. by DEN for the reporting month. This indicator tracks C) Other special tests in which the emergency generator performance for SEP #62. is expected to be operated for at least one hour while loaded with at least 50% of its design load. EQUIPMENT FORCED OUTAGES PER 1,000 CRIT 1-

4) Number of Load-Run Failures: A load-run failure CAL HOURS should be counted for any reason in which the emer-Equipment forced outages per 1000 cntical hours is the gency generator does not pick up load and run as pro-inverse of the mean time between forced outages dicted. Failures are counted during any valid load-run caused by equipment failures. The mean time is equal demands.

to the number of hours the reactor is critical in a period

5) Exceptions: Unsuccessf ul attempts to start or load-run (1000 hours) divided by the number of forced outages should not be counted as valid demands or f ailures when caused by equipment f ailures in that period, they can be attributed to any of the following:

A) Spurious trips that would be bypassed in the event of EQUIVALENT AVAILABILITY FACTOR an emergency. This indicator is defined as the ratio of gross available B) Malfunction of equipment that is not reauired during generation to gross maximum generation, expressed as an emergency. a percentage. Available generaton is the energy that C) Intentional termination of a test because of abnormal can be produced if the unit is operated at the maximum conditions that would not have resulted in major diesel power level permitted by equipment and regulatory limi-generator damage or repair. tations Maximum generation is the energy that can be D) Malfunctions or operating errors which would have not produced by a unit in a given period if operated continu-prevented the emergency generator from being restarted ously at maximum capacity, and brought to load within a few minutes. E) A f ailure to start because a portion of the starting sys-FORCED OUTAGE RATE tem was disabled for test purpose, if followed by a suc-This indicator is defined as the percentage of time that cessful start with the starting system in its normal align-the unit was unavailable due to forced events compared m ent, to the time planned for electrical generation. Forced Each emergency generator failure that results in the gen-events are failures or other unplanned conditions that erator being declared inoperable should be counted as require removing the unit from service before the end of one demand and one failure. Exploratory tests during the next weekend. Forced events include start-up fail-conective maintenance and the sucx:essful test that fol-uros and events initiated while the unit is in reserve shut-lows repair to venfy operabihty should not be counted as down (i.e., the unit is available but not in seivice).

1emands or failures when the EDG has not been de-cered operable again.

69

= PERFORMANCE INDICATOR DEFINITIONS (Cont'd) FUEL RELIABluTYINDICATOR UCENSED OPERATOR REQUAUFICATION TRAIN-This indicator is defined as the steady-state primary cool-ING ant 1-131 activity, corrected for the tramp uranium contri-The total number of hours of training given to each crew buton and normalized to a common punfication rate. during each cycle. Also provided are the simulator train-Tramp uranium is fuel which has been deposited on re-ing hours (which are a subset of the total training hours), actor core internals from previous defective f uel or is the number of non-requalification training hours and the present on the surface of fuel elements from the manu-number of exam f ailures. This indicator tracks training facturing process. Steady state is defined as continuous performance for SEP #68. operation for at least three days at a power level that does not vary more than + or 5%. Plants should collect UCENSEE EVENT REPORT (LER) ROOT CAUSE data for this indicator at a power level above 85%, when BREAKDOWN possible. Plants that did not operate at steady-state This indicator shows the number and root cause code for power above 85% should collect data for this indicator at Licensee Event Reports. The root cause codes are as the highest steady-state power level attained during the follows: month.

1) Administrative Control Problem - Management and The density correction factor is the ratio of the specific supervisory deficiencies that affect plant programs or volume of coolant at the RCS operating temperature activities (i.e., poor planning, breakdown or lack of ad-(540 degrees F., Vf - 0.02146) divided by the specific equate management or supervisory control, incorrect volume of coolant at normal letdown temperature (120 procedures, etc.)

degrees F at outlet of the letdown cooling heat ex-

2) Ucensed Operator Error - This cause code captures changer, Vf - 0.016204), which results in a density cor-errors of omission / commission by licensed reactor opera-rection factor for FCS equal to 1.32.

tors during plant activities.

3) Other Personnel Error - Errors of omission /commis-GASEOUS RADIOACTIVE WASTE BEING DIS-sion committed by non-licensed personnelinvolved in CHARGED TO THE ENVIRONMENT plant activities.

This indicator displays the total number of Curies of all

4) Maintenance Problem - The intent of this cause gaseous radioactive nuclides released from FCS. This code is to capture the full range of problems which can indicator is included in the report when new data is avail-be attributed in any way to programmatic deficiencies in able, i.e., every 6 months.

the maintenance functional organization. Activities in-cluded in this category are maintenance, testing, surveil-GROSS HEAT RATE lance, calibration and radiation protection. 1 Gross heat rate is defined as the ratio of total thermal

5) Design / Construction / Installation / Fabrication Problem energy in British Thermal Units (BTU) produced by the

. This cause code covers a full range of programmatic reactor to the total gross electrical energy produced by deficiencies in the areas of design, construction, installa-the generator in kilowatt-hours (KWH). tion, and f abrication (i.e., loss of control power due to underrated fuse, equipment not qualified for the environ-HAZARDOUS WASTE PRODUCED ment, etc.). The total amount (in Kilograms) of non halogenated ha2-

6) Equipment Failures (Electronic Piece-Parts or Envi-ardous waste, halogenated hazardous waste, and other ronmental-Related Failures) - This code is used for spuri-hazardous waste produced by FCS each month.

ous f ailures of electronic piece-parts and failures due to j meteorological conditions such as lightning, ice, high HIGH PRESSURE SAFETY INJECT 10N SYSTEM winds, etc. Generally, it includes spurious or one-time SAFETY SYSTEM PERFORMANCE f ailures. Electric components included in this category The sum of the known (planned and unplanned) unavail-are circuit _rds, rectifiers, bistables, fuses, capacitors, able hours and the estimated unavailable hours for the diodes, rasistors, etc. high pressure safety injection system for the reporting penod divided by the crrtical hours for the reporting pe-UQUID RADIOACTIVE WASTE BEING DISCHARGED riod multiplied bl the number of trains in the high pres-TO THE ENVIRONMENT sure safety injection system. This indicator displays the total number of curies from all liquid releases from FCS to the Missouri River. This IN-LINE CHEMISTRY INSTRUMENTS OUT OF SER-ladicator is includad in the report when new data is avail-VICE able, i.e., every 6 months. ] Total number of in line chemistry instruments that are out-of service in the Secondary System and the Post LOGGABLE/ REPORTABLE INCIDENTS (SECURITY) Accident Sampling System (PASS). The total number of security incidents for the reporting month depicted in two graphs. This indicator tracks so-UCENSE CANDIDATE EXAMS curity performance for SEP #58. This indicator shows the number of SRO and/or RO quiz-zes and exams that are administered and passed each MAINTENANCE OVERTIME month. This ind cator tracks training performance for The % of overtime hours compared to normal hours for i SEP #68. maintenance. This includes OPPD personnel as well as j contract personnel. 70

PERFORMANCE INDICATOR DEFINITIONS (Cont'd) MAINTENANCE WORKLOAD BACKLOGS NUMBER OF HOT SPOTS This indicator is a breakdown of the manhours associ-The number of radiological hot spots which have been ated corrective non-outage maintenance work orders by identified and documented to exist at FCS at the end of several categories. Safety related MWOs are those the reporting month. A hot spot is a smalllocalized MWOs in which the Equipment Data Base in CHAMPS source of radiation. A hot spot occurs when the contact has identified the equipment as Critical Quality Equip-dose rate of an item is at least 5 times the General Area ment (COE). Therefore, this indicator is identifying those dose rate and the item's dose rate is equal to or greater MWOs that have been identified as COE and reports the than 100 mrem / hour. number of estimated manhours associated with the backlog. This indicator tracks maintenance performance NUMBER OF PERSONNEL ERRORS REPORTED IN for SEP #36. LERS The number of Licensee Event Reports (LERs) attributed MAXIMUM INDIVIDUAL RADIATION EXPOSURE to personnel error on the original LER submittal. A Per-The total maximum amount of radiation received by an sonnel Error is an event for which the root cause is inap-ir dividual person working at FCS on a monthly, quarterly, propriate action on the part of one or more specified indi-and annual basis. viduals (as opposed to being attributed to a department or a general group). Also, the inappropriate action must MWO PLANNING STATUS (CYCLE 15 REFUELING have occurred within approximately two years of the OUTAGE)

Event Date" specified in tt's LER. This indicator trends The total number of Maintenance Work Orders that have personnel performance for SEP #15.

been approved for inclusion in the Cycle 15 Refueling Outage and the number that are ready to work (parts NUMBER OF MISSED SURVEILLANCE TESTS RE-staged, planning complete, and all other paperwork SULTING IN LICENSEE EVENT REPORTS ready for field use). Also included is the number of The number of Surveil:ance Tests (STs) that result in MWOs that have engineering holds (ECNs, procedures Licensee Event Reports (LERs) during the reporting and other miscellaneous engineering holds), parts hold. month. This indicator tracks missed STs for SEP #60 & (parts staged, not yet inspected, parts not yet arrived) 61. and planning hold (job scope not yet completed). Main-tenance Work Requests (MWRs) are also shown that OPEN CORRECTIVE ACTION REPORTS & INCIDENT have been identified for the Cycle 15 Refueling Outage REPORTS and have not yet been converted to MWOs. This indicator displays the total number of open Correc-tive Acton Reports (CARS), the number of CARS that are NUMBER OF CONTROL ROOM EQUIPMENT DEFI-older than six months and the number of open significant CIENCIES CARS. Also displayed are the number of open incident A control room equipment deficiency (CRD)is defined as Reports (irs), the number of irs thet are greater than six any component which is operated or controlled from the months old and the number of open significant irs. Control Room, provdes indication or alarm to the Control Room, provides testing capabihties from the Control OUTSTANDING MODIFICATIONS Room, provides automatic actions f rom or to the Control The number of Modification Requests (MRs)in any state Room, or provides a passive function for the Control between the issuance of a Modification Number and the Room and has been identified as deficient, i.e., does not completion of the drawing update. perform under all conditions as designed. This definition

1) Form FC-1133 Backlog /In Progress. This number rep-also applies to the Alternate Shutdown Panels Al-179 resents modification requests that have not been plant AI.185, and Al-212.

approved during the reporting month. A plant component which is deficient or inoperable is

2) Modification Requests Being Reviewed. This category considered an " Operator Work Around (OWA) Item" if includes:

some other action is required by an operator to compen-A.) Modification Requests that are not yet reviewed. sate for the condition of the component. Some examples B.) Modification Requests being reviewed by the Nuclear of OWAs are: 1) The control room level indcator does Projects Review Committee (NPRC). not work but a local sightglass can be read by an Opera-C.) Modification Requests being reviewed by the Nuclear for out in the plant; 2) A deficient pump cannot be re-Projects Committee (NPC) paired because replacement parts require a long lead These Modification Requests may be reviewed several time for purchase / delivery, thus requiring the redundant times before they are approved for accomplishment or pump to be operated continuously; 3) Special actions cancelled. Some of these Modification Requests are are required by an Operator because of equipment de-returned to Engineering for more information, some ap. sign problems. These s'tions may be described in Op-proved for evaluation, some approved for study, and orations Memorendums, Operator Notes, or may require some approved for planning. Once planning is com-l changes to Operating Procedures. 4) Deficient plant pleted and the scope of the work is clearly defined, these equipment that is required to be used during Emergency Modifcation Requests may be approved for accomplish-Operating Procedures or Abnormal Operating Proce-ment with a year assigned for construction or they may dures. 5) System indication that provides criticalinfor-be cancelled. Allof these different phases require re-f mation during normal or abnormal operations. view. 71

PERFORMANCE INDICATOR DEFINITIONS (Cont'd)

3) Design Engineering Backlog /In Progress. Nuclear PROGRESS OF REFUEUNG OUTAGE MODIFICA-Planning has assigned a year in which construction will T10N PLANNING (FROZEN SCOPE OF 24 MODIFICA-be completed and design work may be in prog' ass.

T10NS)

4) Construction Backlog /In Progress. The Conutruction This indicator shows the status of modifications ap-Package has been issued or construction has begun but proved for completion during the Refueling Outage.

the modification has not been accepted by the System Acceptance Committee (SAC). RADIOLOGICAL WORK PRACTICES PROGRAM

5) Design Engineering Update Backlog /In Progress. PED The number of identified poor radiological work practices has received the Modification Completion Report but the (PRWPs) for the reporting month. This indicator tracks drawings have not been updated.

radiological work performance for SEP #52. The above mentioned outstanding modifications do not include modifcations which are proposed for cancella-RATIO OF PREVENTIVE TO TOTAL MAINTENANCE & PREVENTIVE MAINTENANCE ITEMS OVERDUE l tion. The ratio of preventive maintenance (including surveil-OVERALL PROJECT STATUS (REFUELING OUTAGE) lance testing and calibration procedures) to the sum of This indicator shows the status of the projects which are non-outage corrective maintenance and preventive main. in the swpe of the Refueling Outage. tenance completed over the reporting period. The ratio, expressed as a percentage, is calculated based on man-4 PERCENTAGE OF TOTAL MWOs COMPLETED PER hours. Also displayed are the % sf preventive mainte-l MONTH IDENTIFIED AS REWORK nance items in the month that word not completed by the The percentage of total MWOs completed per month scheduled date plus a grace period equal to 25 % of the identified as rework. Rework activities are identified by scheduled interval. This indicator tracks preventive maintenance planning and craft. Rework is: Any main-maintenance adivities for SEP #41, tenance work repeated to correct a deficiency which has re-ocx:urred within 60 days following similar work activi-RECORDABLE INJURY /lLLNESS CASES FRE-ties. Any additional work required to correct deficiencies QUENCY RATE discovered during a failed Post Maintenance Test to en. The number of injuries requiring more than normal first sure the component / system passes subsequent Post aid per 200,000 man-hours worked. This indicator Maintenance Tests. This definition can be found in S. O. trends personnel performance for SEP #15,25 & 26. I M-101. REPEAT FAILURES The number of Nuclear Plant Reliability Data System t PERCENT OF COMPLETED SCHEDULED MAINTE. (NPRDS) components with more than 1 failure and the NANCE ACTIVITIES number of NPRDS components with more than 2 failures The % of the number of completed maintenance activi-for the last eighteen months. ties as compared to the number of scheduled mainte-nance activities each month. This % is shown for all SAFETY SYSTEM FAILURES maintenance crafts. Also shown are the number of Safety system failures are any events or conditions that emergent MWOs. Maintenance activities include MWRs, could prevent the fulfillment of the safety functions of MWOs, STs, PMOs, calibrations, and other misceha-structures or systems. If a system consists of multiple neous activities. This indicator tracks Maintenance per-redundant subsystems or trains, failure of all trains con-formance for SEP #33. stitutes a safety system failure. Failure of one of two or more trains is not counted as a safety system failure. PRIMARY SYSTEM CHEMISTRY % OF HOURS OUT The definition for the indicator parallels NRC reporting OF UMIT requirements in 10 CFR 50.72 and 10 CFR 50.73. The The % of hours out of limit are for six primary chemistry following is a list of the major safety systems, sub-parameters divided by the total number of hours possible systems, and components monitored for this indicator: l for the month. The key parameters used are: Lithium, Accident Monitoring instrumentation, Auxiliary (and Chloride Hydrogen, Dissvived Oxygen, Fluoride, and Emergency) Feedwater System, Combustible Gas Con. Suspended Solids. EPRI limits are used. trol, Component Cooling Water System, Containment and Containment isolation, Containment Coolant Sys-PROCEDURAL NONCOMPLIANCE INCIDENTS tems, Control Room Emergency Ventilation System, (MAINTENANCE) Emergency Core Cooling Systems, Engineered Safety The number of identified incidents concerning mainte-Features instrumentation, Essential Compressed Air nance procedural problems, the number of closed irs Systems, Essential or Emergency Service Water, Fire related to the use of procedures (includes the number of Detection or Suppression Systems, Isolation Condenser, closed irs caused by procedural noncompliance), and Low Temperature Overpressure Protection, Main Steam the number of closed procedural noncompliance irs. Line Isolation Valves, Onsite Emergency AC & DC This indcator trends personnel perf ormance for SEP Power w/ Distribution, Radiation Monitoring Instrumenta-l

15,41 & 44.

tion, Reactor Coolant System, Reactor Core Isolation Cooling System Reactor Trip System and instrumenta-tion. Recirculation Pump Trip Actuation Instrumentation, 72 i l

PEFIFORMANCE INDICATOR DEFINITIONS (Cont'd) Residual Heat Removal Systems, Safety Valves, Spent systems and are not shown on the latest revision of the Fuel Systems, Standby Liquid Control System and Ulti-P&lD, schematic, connection, wiring, or flow diagrams. mate Heat Sink.

2) Jumpers and blocks which are installed for Surveil-lance Tests, Maintenance Procedures, Calibration Pro-SECONDARY SYSTEM CHEMISTRY PERFORMANCE cedures, Special Procedures, or Operating Procedures INDEX are not considered as temporary modifcations unless the The Chemistry Performance Index (CPI) is a calculation jumper or block remains in place after the test or proce-based on the concentration of key impurities in the sec-dure is complete. Jumpers and blocks installed in test or ondary side of the plant. These key impurities are the lab instruments are not considered as temporary modifi-most likely cause of deterioration of the steam genera-cations.

tors. The chemistry parameters are reported only for the

3) Scaffolding is not considered a temporary modifica-period of time when the plant is operated at greater than tion. Jumpers and blocks which are installed and for 30 percent power.

which MRs have been submitted will be considered as r The CPI is calculated using the following equation: CPI - temporary mod:fications untilfinal resoluton of the MR (Ka/0.8) + (Na/20) + (O,/10) / 3 where the following are and the jumper or block is removed or is permanently monthly averages of: Ka - average blowdown cation remrded on the drawings. This indicator tracks tempo-conductivity, Na - average blowdown sodium concen-rary moddications for SEP #62 & 71. tration, O, - average condensate pump discharge dis-solved oxygen concentration. THERMAL PERFORMANCE The ratio of the design gross heat rate (corrected) to the SIGNIFICANT EVENTS adjusted actual gross heat rate, expressed as a percent-I Signifcant events are those events identified by age. NRCstaff through detailed screening and evaluaton of operating experience. The screening process includes UNIT CAPABILITY FACTOR the daily review and discussion of all reported operating The ratio of the available energy generation over a given reactor events, as well as other operational data such as time period to the reference energy generation (the en-special tests or construction activities. An event identi-ergy that could be produced if the unit were operated fied from the screening process as a signifcant event continuously at full power under reference ambient con-candidate is further evaluated to determine if any actual d:tions) over the same time period, expressed as a per-or potential threat to the health and safety of the public contage. was involved. Specific examples of the type of criteria are summarized as follows: 1) Degradation of important UNPLANNED AUTOMATIC REACTOR SCRAMS PbR safety equipment; 2) Unexpected plant response to a 7,000 CRITICAL HOURS transient; 3) Degradation of fuelintegrity, primary cool-This indicator is defined as the number of unplanned au-ant pressure boundary, important associated features; tomatic scrams (reactor protection system logic actua-

4) Scram with complication: 5) Unplanned release of tions) that occur per 7,000 hours of critical operation.

radioactivity; 6) Operation outside the limits of the Tech-The value for this indicator is calculated by multiplying nical Specifcatons; 7) Other. the total number of unplanned automatic reactor scrams INPO significant events reported in this indcator are in a specific time period by 7,000 hours, then dividing SERs (Sgnif cant Event Repo ts) which inform utikties of that number by the total number of hours criticalin the significant events and lessons leamed identified through same time period. The indcator is further defined as the SEE-IN screening process. follows:

1) Unplanned means that the scram was not an antici-SPARE PARTS INVENTORY VALUE pated part of a planned test, The dollar value of the spare parts inventory value for

2) Scram means the automatic shutdown of the reactor FCS during the reporting penod.

by a rapid insertion of negative reactivity (e.g., by control rods, liquid injection system, etc.) that is caused by ac-STAFFING LEVEL tuation of the rt actor protecton system. The scram sig-The actual staffing level and the authorized staff ng leW nal may have resulted from exceeding a setpoint or may for the Nuclear Operations Division, the Pr % ton Fi. % been spurious. h Automatic means tha' the initial signal that caused neering Division, and the Nuclear Servir s divisiur i e indicator tracks performance for SEP #24. e.::Wion of the reactor protection system logic was pro-vided from one of the sensors monitoring plant param-STATION NET GENERATION eters and mnditions, rather than the manual scram The net generation (sum) produced by the FCS during switches or, in manual turbine trip switches (or push-but-the reporting month. tons) provided in the main control room.

4) Criticaf means that during the steady-state condition of TEMPORARY MODf FICAT10NS the reactor prior to the scram, the effective multiplcation The number of temporary mechanical and electrical con-f actor (k,) was essentially equal to one.

figurations to the plant's systems.

1) Temporary configuratons are defined as electrical jumpers, electrical blocks, mechanical jumpers, or me-chanical blocks which are installed in the plant operating 73

PEFIFORMANCE INDICATOR DEFINITIONS (Cont'd) UNPLANNED CAPABluTY LOSS FACTOR VOLUME OF LOW LEVEL SOLID RADIOACTIVE The ratio of the unplanned energy losses during a given WASTE period of time, to the reference energy generation (the This indicator is defined as the volume of low-level solid energy that could be produced if the unit were operated radioactive waste actualty shipped for burial. This indica-continuously at full power under reference ambient con-tor also shows the volume of low-level radioactive waste ditions) over the same time pared, expressed as a per-which is in temporary storage, the amount of radioactive centage. oil that has been shipped off-site for processing, and the volume of solid dry radioactive waste which has been UNPLANNED SAFETY SYSTEM ACTUATIONS-shipped off-site for processing. Low-levelsolid radioac-(INPO DEFINITION) tive waste consists of dry active waste, sludges, resins, This indicator is defined as the sum of the following and evaporator bottoms generated as a result of nuclear safety system actuations: power plant operation and maintenance. Dry radioactive 1)The number of unplanned Emergency Core Cooling waste includes contaminated rags, cleaning materials, System (ECCS) actuations that result from reaching an disposable protective clothing, plastic containers, and ECCS actuation setpoint or from a spurious / inadvertent any other material to be disposed of at a low-level radio-ECCS signal. active waste disposal site, except resin, sludge, or

2) The number of unplanned emergency AC power sys-evaporator bottoms. Low-level refers to all radioactive tem actuations that resutt from a loss of power to a safe-waste that is not spent fuel or a by-product of spent fuel guards bus. An unplanned safety system actuation oc-processing. This indicator tracks radiological work per-cuts when an actuation setpoint for a safety system is formance for SEP #54.

reached or when a spurious or inadvertent signal is gen-erated (ECCS only), and major equipment in the system is actuated. Unplanned means that the system actuation was not part of a planned test or evolution. The ECCS actuations to be counted are actuations of the high pres-sure injedion system, the low pressure injection system, or the safety injection tanks. UNPLANNED SAFETY SYSTEM ACTUATIONS(NRC DEFINITION) The number of safety system actuations which include (pph) the High Pressure Safety injection System, the Low Pressure Safety injection System, the Safety injec-tion Tanks, and the Emergency Diesel Generators. The NRC classification of safety system actuations includes actuations when major equipment is operated gad when the logic systems for the above safety systems are chal-lenged. VIOLATIONS PER 1,000 INSPECTION HOURS This indicator is defined as the number of violations sited in NRC inspection reports for FCS per 1,000 NRC in-spection hours. The violations are reported in the year that the inspection was actualty performed and not based j on when the inspection report is received. The ho;rs 1 reported for each inspection report are used as the in-spection hours. l 1 74 I 1

SAFETY ENHANCEMENT PROGRAM INDEX The purpose of the Safety Enhancement Program (SEP) Performance Indicators Index is to list perfor-mance indicators related to SEP items with parameters that can be trended. SEP Reference Number 15 EaQ2 increase HPES and IR Accountability Through Use of Performance Indicators Procedural Noncompliance incidents (Maintenance). . 48 Contaminations ;t2,000 Counts / Minute Per Probe Area. .4 Recordable injury / Illness Cases Frequency Rate. .3 Number of Personnel Errors Repor1ed in LERs. .5 l SEP Reference Numbar 24 Complete Staff Studies Staffing Level . 41 SEP Reference Number 25 Training Program for Managers and Supervisors Implemented Disabling injury / Illness Frequency Rate. .2 Recordable Injury / Illness Cases Frequency Rate. .3 SEP Reference Number 26 Evaluate and implement Station Standards for Safe Work Practice Requirements Disabling injury / Illness Frequency Rate. .2 Recordable injury / Illness Cases Frequency Rate. .3 SEP Ref erence Number 27 Implement Supervisory Enforcement of industrial Safety Standards Disabling injury / Illness Frequency Rate. .2 Recordable injury /111 ness Cases Frequency Rate. .3 SEP Reference Number 31 Develop Outage and Maintenance Planning Manual and Conduct Project Management Training MWO Planning Status (Cycle 15 Refueling Outage). .. Not Reported During R.F. O. Overall Project Status (Cycle 15 Refueling Outage).. ..Not Reported During R.F. O. Progress of Cycle 15 Outage Modification Planning. .. NJt Reported During R.F. O. SEP Reference Number 33 Develop On-Line Maintenance and Modification Schedule Percent of Completed Scheduled Maintenance Activities (All Maintenance Crafts). . 49 SEP Reference Number 36 Reduce Corrective Non-Outage Backlog Maintenance Workload Backlogs (Corrective Non-Outage). . 44 i SEP Reference Number 41 Develop and Implement a Preventive Maintenance Schedule Ratio of Preventive to Total Maintenance & Preventive Maintenance llems Overdue. . 45 Procedural Noncompliance Incidents. . 48 SEP Eaference Number 43 Implement the Check Valve Test Program Check Valve Failure Rate. . 35 75

i SAFETY ENHANCEMENT PROGRAM INDEX (continued) SEP Reference Numbar 44 EaQ2 Compliance With and Use of Procedures Procedural Noncompliance incidents (Maintenance). . 48 SEP Reference Number 46 Design a Procedures Control and Administrative Program I Document Review... .55 SEP Reference Number 52 Establish Supervisory Accountability for Workers Radiological Practices RadiologicalWork Practices Program. . 53 SEP Reference Number 54 Complete implementation of Radiological Enhancement Program Collective Radiation Exposure.. .15 Volume of Low-Level Solid Radioactive Waste.. .36 Contaminations 22,000 Counts / Minute Per Probe Area. .4 Decontaminated Radiation Controlled Area.. .52 SEP Reference Number 58 Revise Physical Security Training and Procedure Program Loggable/ Reportable incidents (Secunty). .56 SEP Reference Number 60 Improve Controls Over Surveillance Test Program Number of Missed Surveillance Tests Resulting in Licensee Event Reports. .19 SEP Reference Number 61 Modify Computer Program to Correctly Schedule Surveillance Tests Number of Missed Surveillance Tests Resulting in Licensee Event Reports. .19 SEP Reference Number 62 Establish Interim System Engineers l .. 57 Temporary Modifications.. . 59 Engineering Assistance Request (EAR) Breakdown.. . 60 Engineering Change Notice Status. Engineering Change Notice Breakdown. . 61 l SEP Reference Number 68 Assess Root Cause of Poor Operator Training and Establish Means to Monitor Operator Training Licensed Operator Requalification Training. . 63 . 64 License Candidate Exams.. SEP Reference Number 71 Improve Controls over Temporary Modifications Temporary Modifications. .57 i 76

i m REPORT DISTRIBUTION LIST R. L. Andrews D. L. Lovett J. H. MacKinnon G. L Anglehart K. L. Belek J. W. Marcil B. H. Biome N. L Marfice J.P.Bobba R. D. Martin T. J. Mcivor C. E. Boughter C. J. Brunnert K. A. Miller i G. R. Cavanaugh Nuclear Licensing J. W. Chase & Industry Affairs A. G. Christensen J. T. O'Connor W. W. Orr 4 O. J. Clayton R. P. Clemens T. L. Patterson R. T. Pearce J. L. Connolley G. M. Cook R. L. Phelps D. C. Dietz R. L. Plott H. J. Faulhaber W.J.Ponec C. R. Rice M. A, Ferdig M. T. Frans A. W. Richard S. K. Gambhir D. G. Ried G. K. Samide J. K. Gasper W. G. Gates M. J. Sandhoefner M. O. Gautier F. C. Scofield S. W. Gebers H. J. Sef'ck J. W. Shannon L. V. Goldberg R. W. Short R.H. Guy C. F. Simmons J. B. Herman K. C. Holthaus E.L.Skaggs J. L. Skilos C.K. Huang C.J. Husk F. K. Smith T. W. Jamieson R. L. Sorenson R. L. Jaworsk) K. E. Steele R. A. Johansen M. A. Tesar W. C. Jones J. J. Tesarek J. W. Tills J. D. Keppler D. D. Kloock J. M. Waszak L.T.Kusek S. J. Willrett M. P. Lazar 77

FORT CALHOUN STATION OPERATING CYCLES AND REFUELING OUTAGE DATES Event Date Range Production (MWH) Cumulative (MWH) Cycle 1 09/26/73 -02/01R5 3,299,639 3,299,639 1st Refueling 02/01/75-05/09/75 j l Cycle 2 05/09/75 10/01/76 3,853,322 7,152,961 ) 2nd Refueling 10/01/76 12/13/76 Cycle 3 12/13/76 - 9/30/77 2,805,927 9,958,888 3rd Refueling 09/30/77-12/09/77 Cycle 4 12/09/77-10/14/78 3,026,832 12,985,720 4th Refueling 10/14/78-12/24/78 i Cycle 5 12/24/78 - 01/18/80 3,882,734 16,868,454 51h 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 -12/06/82 3,561,866 24,330,034 7th Refueling 12/06/82 - 04/07/83 Cycle 8 04/07/83 - 03/03/84 3,406,371 27,736,405 j 1 8th Refueling 03/03/84 07/12/84 Cycle 9 07/12/84 - 09/28/85 4,741,488 32,477,893 91h Refueling 09/28/85- 01/16/86 l Cycle 10 01/16/86 - 03/07/87 4,356,753 36,834,646 10th Refueling 03/07/87 - 06/08/87 Cycle 11 06/08/87 - 09/27/88 4,936,859 41,771,505 11th Refueling 09/27/88 - 01/31/89 Cycle 12 01/31/89 02/17/90 3,817,954 45,589,459 12th Refueling 02/17/90- 05/29/90 Cycle 13 05/29/90 02/01/92 5,451,069 51,040,528 13th Rofueling 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 11/2F'93 - 03/11/95 15th Refueling 03/11/95- 04/29/95 (Planned Dates) FORT CALHOUN STATION CURRENT PRODUCTION AND OPERATIONS " RECORDS" First Sustained Reaction August 5,1973 (5:47 p.m.) First Electricity Supplied to the System August 25,1973 Commercial Operation (180,000 KWH) September 26,1973 Achsved Full Power (100%) rJay 4,1974 Longest Run (477 days) Jurse 8,1987 Sept. 27,1988 Highest Monthly Net Generation (364,468,800 KWH) October 1987 Most Productive Fuel Cycle (5,451,069 MWH)(Cycle 13) May 29,1990 Feb.1,1992}}

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