Text

FCS Performance Indicators Oct 1994
	ML20080B478
Person / Time
Site:	Fort Calhoun
Issue date:	10/31/1994
From:	; OMAHA PUBLIC POWER DISTRICT
To:	;
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ML20080B477	List: LIC-94-0239, Forwards FCS Performance Indicators Oct 1994; ML20080B478;
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	NUDOCS 9412020247
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OMAHA PUBLIC POWER DISTRICT FORT CALHOUN STATION l l i PERFORMANCE INDICATORS REPORT Prepared By: Production Engineering Division System Engineering Test and Performance Group OCTOBER 1994 1 i

FORT CALHOUN STATION OCTOBER 1994 MONTHLY OPERATING REPORT OPERATIONS

SUMMARY

During the month of October, Fon Calhoun Station (FCS) operated at a nominal 100% power, except for a planned short term power reduction to characterize a potential fuel pin leak. FCS reduced power to 32% on October 21,1994, and returned to 100% power on October 26. Nor-mal plant maintenance, surveillance, equipment rotation activities and online modification activi-ties occurred during the month. The Reactor Protective System "B" Channel Trip Unit No.10 (Loss of Load) was declared inop-erable on October 6 for Instrumentation & Control (I&C) troubleshooting due to spurious pretrips. A 48-hour Limiting Condition for Operation, as required by Technical Specification 2.15.1, was entered and subsequently exited on October 7 after repairs were completed. On October 7, a one-hour report was made to the NRC pursuant to 10 CFR 50.72(b) (1) (ii) (B) and 10 CFR 50.72(b) (2) (iii) (B). A review of the raw water pumps' design basis determined that seal water is essential for pump operation. However, the current seal water system is not classified as critical quality element (CQE) equipment. Interim measures were implemented to ensure that the raw water pumps remained operable. A modification is being processed to pro-vide final resolution of this issue. On October 10, a switch from morpholine to ethanolamine (ETA) was implemented for second-ary chemistry control. The reason for this switch was to further reduce feed water iron concen-trations. On October 25, Chemistry sampling results determined that the paniculate concentration ex-ceeded the FCS administrative limits for the fuel oil in the Diesel Generator (DG) Storage Tank FO-1 and the DG-2 Day Tank. A fiher unit was placed into service on FO-1 and chemistry re-turned to specification on October 28. Filtering work continues on the DG-2 Day Tank. The following NRC inspection was completed during this reponing period: IER No. Descriotion 94-21 Monthly Resident inspection There were no Licensee Event Reports submitted during this reponing period. Source: Nuclear Licensing & Industry Affairs i

= Year-To-Date Value Performance Cateaories 7 m-- W- ~ g Performance in Industry I l i ^ LUh@annedk Thermal: Upper 10% and better I utorNatid$% [Pdformance::i than 1994 OPPD goal i UI)lfppntd Unit A Capability f %%illIY I. _Scremar7,0003 g Factor i LospFactor__ !(Hours Cdiscib Performance Better Than ~' l E ^ 1994 OPPD Goal I ^ ~ ll ll l l [ I .i i -x s} I AFW INifetpl !Fuelf... Performance Not Meeting. lq Safety iPS$ .,et,f tN form @aqc Perfordddclel MW l/Rellabilityh 1994 OPPD Goal Per'f6tMdrica {l6disatop Por e i-l l i i l _ _L _ _ _c w _r - = -. l l July August September i ^ 34 34 34 ddem$stry Collective VOBONiefg rid,ustrlidl ify,) Radiation ^ ' Low 4.evel.i - ty October 1994 l hposure fR# W % ' .[a Value A nW R Year-To-Date ee esten l l ps Best Possible l l ,m ---t Performance 1994 Year-End ~ ~ ~ ^ Performance o INPO PERFORMANCE INDICATORS (Performance for the months of January through October 1994)

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$ riti g Year-To-Date Value Performance Cateaories r~ .5 Performance BetterThan Industry Average Trend s.e ~ ,,n... sSofetyi JSignlitcant? ' gg-g =9Esents ^' x lfActuationsi;

- $1 Performance Better Than 1994 OPPD Goal 4 -

% w :. 2a e "Ju-s ~ ~ , HM 's Performance Not Meeting 1994 OPPD Goal or 2: 5 Industry Average Trend Forced r% Safety 3 3;:cjSystem 43 Outage N F M ures 4% Rate 3pyim t;. July August September hEnMS ~, ~gfi 34 34 34

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F Radiation Performance 1994 Year-End dit br{,000 l Exposure Performance i D ____A___ NRC PERFORMANCE INDICATORS (Safety System Failures and Significant Events ratings are averages for April 1991 through March 1994. Predictor blocks cannot be generated for these performance indicators because they are based on NRC biannual reports. All other indicator values are for the months of January through October 1994.)

FORT CALHOUN STATION PERFORMANCE INDICATORS REPORT OCTOBER 1994 -

SUMMARY

POSITIVE TREND REPORT A performance indicator with data representing three Primary System Chemistrv Percent of Hours Out of Limit consecutive months of improving performance or three (Page 39) consecutive months of performance that is superior to the stated goalis exhibiting a positive trend per Nuclear Samndary System Chemistry Operations Division Quality Procedure 37 (NOD-OP-37). (Page 40) The following performance indicators exhbited positive Cents Per Kilowatt Hour trends for the reporting month: (Page 42) Ratin of Preventive to Total Maintenance & Preventive Disablino inlurv/lliness Frecuency Rate (Lost Time Acci-Maintenance items Overdue dont Rate) (Page 47) (Page 3) l Maintenance Overtime Recordable Iniurv/ Illness Cases Freauency Rate (Page 49) (Page 4) in-Line Chemistry Instruments Out-of-Service Hioh Pressure Safety Iniection System Safety Svstem (Page 52) Performance (Page 8) Harardous Waste Produced (Page 53) i Auriliary Feedwater System Safety System Performance (Page 9) Contaminated Radiation Controlled Area (Page 54) Emeroency AC Power System Safety System Perfor-mADGE (Page 10) End of Positive Trend Report. Emeroency Diesel Generator Unit Reliability l (Page 11) i Diesel Generator Reliability (25 Demands) ADVERSE TREND REPORT (Page 12) A Performance Indicator with data representing 3 con-Emeroency Diesef Generator Unreliability secutive months of declining performance; or four or (Page 13) rnore consecutive months of performance that is trending towards declining as determined by the Manager - Sta-l Number of Missed Surveillance Tests Resultino in Lic-tion Engineering, constitutes an adverse trend per NOD. ensee Event Reoorts OP 37. A supervisor whose performance indicator ex-(Page 20) hibits an adverse trend by 'his definition may specify in written form (to be publishoo 'n this report) why the trend 1 Forced Outace Rate s not adverst ] (Page 23) 1 The following performance indicatt, exhibited an ad-1 Unit Canacitv Facto _r verse trend for the reporting month: (Page 24) j l l Unit Canability Factor Fuet Reliability Indicator (Page 26) (Page 14) An adverse trend is indicated based on the FRI value for Unolanned Canability Loss Factor the reporting month exceeding the 1994 Fort Calhoun (Page 27) monthly goal of less than 5.0 X 10% and the potential for Eoulomant Forced Outaces Per 1.000 Critical Hours j (Page 34) l End of Adverse Trend Report. l l l iv

FORT CALHOUN STATION PERFORMANCE INDICATORS REPORT I OCTOBER 1994.

SUMMARY

INDICATORS NEEDING INCREASED MANAGEMENT ATTENTION REPORT A performance indicator with data for the reporting period Percentaos of Total MWOs Comoleted Per Month identi-that is inadequate when compared to the OPPD goal is fied As Rework defined as *Needing increased Management Attention" (Page 48) per NOD-OP The percentage of totai e/IWOs identified as rework (3.16%) for the reporting month has exceeded the 1994 The following performance indicators are cited as need-monthly goal of <3% since September 1994. ing increased management attention for the reporting month: Temocrary Modifications (Page 58) Number of Control Room Eauioment Deficiencies The temporary modification associated with the surf ace (Page 15) sluice line (which is removable on-line) is greater than 6 i The total number of control room equipment deficiencies months old and, therefore, exceeds the 1994 goal. I at the end of the reporting month (51) exceeds the 1994 Fort Calhoun monthly goal of $45, in addition, the num-ber of identified Operator Work Around items for the re-End of Management Attention Report. porting month (7) exceeds the monthly goal of 55. Violations Per 1.000 Insoection Hours (Page 18) The number of NRC violations per 1,000 inspection hours has exceeded the Fort Calhoun goal of s1.4 since PERFORMANCE INDICATOR REPORT March 1994 IMPROVEMENTS / CHANGES Unolanned Automatic Reactor Serams Per 7.000 Hours This sectior' lists significant changes made to the report CrIDeal and to specific indicators within the report since the pre. ] (Page 28) vious month. The number of unplanned automatic reactor scrams per j 7,000 hours critical has exceeded the Fort Calhoun goal ) of 0 since February 1994. There have been no ( Eauioment Forced Outaces Per 1.000 Critical Hours l unplanned automatic reactor scrams since February 1994. (Page 34) This indicator has been revised to represent the equip-t 9** # Unolanned Safety System Actuations - flNPO Definition) 12 months, rather than the year-to-date value. Another (Page 29) graph has been added to show the number of equipment The number of INPO unplanned safety system actua-breed outages per month for the last 12 months. tions has exceeded the Fort Calhoun goal of 0 since February 1994. There have been no INPO unplanned safety system actuations since February 1994. yglume of Low-Level Solid Radioactive Waste fe"xfwafadded to this indicator to report the amount (in Unolanned Safety System Actuations -(NRC Definition) (Page 30) pounds) of metals from rack cut-up shipped off site for The number of NRC unplanned safety system actuations processing during the reporting month, has exceeded the Fort Calhoun goal of 0 since February 1994. There have been no NRC unplanned safety sys-tem actuations since February 1994. End of Performance Indicator Report improvements / l Thermal Performance (Page 32) l The year-to-date average monthly thermal performance value has been below the 1994 Fort Calhoun goal of 299.5% since January 1994. Maintenance Workload Backlocs l (Page 46) l The backlog of non outage MWOs for corrective mainte-nance has exceeded the 1994 monthly goal of a maxi-mum of 400 since August 1994. l l l V l

I-Table of Contents / Summary = EAGE -X GOALS.... EAGE SAFE OPERATIONS =.. . 2 INDUSTRIAL SAFETY ACCIDENT RATE - INPO.. 3 DISABLING INJURY /lLLNESS FREQUENCY RATE. RECORDABLE INJURY /lLLNESS CASES -4 FREQUENCY RATE........... CLEAN CONTROLLED AREA CONTAMINATONS =5 21,000 DISINTEGRATIONS / MINUTE PER PROBE AREA... ..6 PREVENTABLE / PERSONNEL ERROR LERs. .7 SAFETY SYSTEM FAILURES SAFETY SYSTEM PERFORMANCE: .8 HIGH PRESSURE SAFETY INJECTON SYSTEM - .9 AUXILIARY FEEDWATER SYSTEM... 10 EMERGENCY AC POWER SYSTEM.. EMERGENCY DIESEL GENERATOR 11 UNIT RELIABILITY EMERGENCY DIESEL GENERATOR .12 RELIABILITY (25 DEMANDS).- -... ~.... EMERGENCY DIESEL GENERATOR - 13 UNRELIABILITY - 14 FUEL RELIABILITY INDICATOR NUMBER OF CONTROL ROOM 15 EQUIPMENT DEFICIENCIES...... 16 COLLECTIVE RADIATION EXPOSURE. MAXIMUM INDIVIDUAL -17 RADIATON EXPOSURE........... .18 VOLATIONS PER 1,000 INSPECTON HOURS =19 SIGNIFICANT EVENTS. - 20 NUMBER OF MISSED SURVEILLANCE TESTS RESULTING IN LERS - PAGE PERFORMANCE _22 STATON NET GENERATON... 23 FORCED OUTAGE RATE.. . 24 UNIT CAPACITY FACTOR - vi

PERFORMANCE (continued) PAGE . 25 EQUIVALENT AVAILABILITY FACTOR.. j UNIT CAPABILITY FACTOR.. .26 .27 UNPLANNED CAPABILITY LOSS FACTOR. UNPLANNED AUTOMATIC REACTOR SCRAMS PER 7,000 HOURS CRITICAL.- .. 28 UNPLANNED SAFETY SYSTEM ACTUATONS -(INPO DEFINITON). . 29 UNPLANNED SAFETY SYSTEM ACTUATONS -(NRC DEFINITON); . 30 GROSS HEAT RATE.. . 31 THERMAL PERFORMANCE.. 32 DAILY THERMAL OUTPUT.. . 33 EQUIPMENT FORCED OUTAGES PER 1,000 CRITICAL HOURS. . 34 COMPONENT FAILURE ANALYSIS REPORT (CFAR)

SUMMARY

. 35 REPEAT FAILURES. .. 36 CHECK VALVE FAILURE RATE.. ... 37 VOLUME OF LOW LEVEL SOLID RADIOACTIVE WASTE. 38 PRIMARY SYSTEM CHEMISTRY PERCENT OF HOURS OUT OF LIMIT.. .39 CHEMISTRY INDEXSECONDARY SYSTEM CHEMISTRY.. . 40 COST PAGE CENTS PER KILOWATT HOUR. . 42 STAFFING LEVEL. . 43 SPARE PARTS INVENTORY VALUE. . 44 DfVISION AND DEPARTMENT PERFORMANCE INDICATORS PAGE MAINTENANCE WORKLOAD BACKLOGS (CORRECTIVE NON-OUTAGE).. . 46 vii

= DIVISON AND DEPARTMENT PERFORMANCE INDICATORS (continued) EAQE RATO OF PREVENTIVE TO TOTAL MAINTENANCE 8 PREVENTIVE MAINTENANCE ITEMS OVERDUE....

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

- 48 MAINTENANCE OVERTIME ; . 49 PROCEDURAL NONCOMPLIANCE INCIDENTS (MAINTENANCE).. . 50 PERCENT OF COMPLETED SCHEDULED MAINTENANCE ACTIVITIES - 51 (ALL MAINTENANCE CRAFTS).. IN-LINE CHEMISTRY INSTRUMENTS 52 OUT-OF-SERVICE. HAZARDOUS WASTE PRODUCED - - 53 CONTAMINATED RADIATION CONTROLLED AREA ; . 54 RADIOLOGICAL WORK PRACTICES PROGRAM = 55 DOCUMENT REVIEW...,. .. 56 LOGGABLE/ REPORTABLE INCIDENTS (SECURITY). . 57 TEMPORARY MODIFICATIONS- -- 58 OUTSTANDING MODIFICATIONS....- ...59 ENGINEERING ASSISTANCE REQUEST (EAR) BREAKDOWN.. . 60 ENGINEERING CHANGE NOTICE STATUS. . 61 . 62 ENGINEERING CHANGE NOTICES OPEN - LER ROOT CAUSE BREAKDOWN - . 63 LICENSED OPERATOR REQUAllFICATION TRAINING. ... 64 LICENSE CANDIDATE EXAMS . 65 OPEN CORRECTIVE ACTON REPORTS AND INCIDENT REPORTS.... . 66 MWO PLANNING STATUS (CYCLE 16 REFUELING OUTAGE). - 67 OVERALL PROJECT STATUS (CYCLE 16 REFUELING OUTAGE). . 68 PROGRESS OF CYCLE 16 OUTAGE MODIFICATION PLANNING.. . 69 PROGRESS OF 1994 ON-LINE MODIFICATION PLANNING - .. 70 Viii

6CTON PLANS. DEFINITONS. SEP INDEX & DISTRIBUTIOf[ LIST EAG,E ACTON PLANS.. . 71 PERFORMANCE '!DICATOR DEFINITONS. . 74 SAFETY ENHANC 'ENT PROGRAM INDEX.. . 81 REPORT DISTRIBL N LIST . 83 l ix

OPPD NUCLEAR ORGANIZATION GOALS Vice President-1994 Priorities MISSION The safe, reliable and cost effective generation of electricity for OPPD customers through the professional use of nuclear technology. The Company shall conduct these operations prudently, efficiently and effectively to assure the health, safety and protection of all personnel, the general public and the environment. 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 throughout the OPPD nuclear organi-zation, that assures safe operation so that Fort Calhoun Station is recognized as a nuclear indus-try leader. 1994 Priorities: Impmve S ALP ratings. Impmve INPO rating. Reduce NRC violations with no violations 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. 1994 Priorities: Impmve Quality, Pmfessionalism, and Teamwork. Improve Plant Reliability. Meet or exceed INPO key parameters and outage performance goals. Reduce the number of human performance errors. Identify programmatic performance problems through effective self assessment. Goal 3: COSTS Operate Fort Calhoun Station in a manner that cos: effectively maintains nuclear generation as a viable source of electricity. 1994 Priorities: Maintain total O & M and Capital expenditures within budget. Streamline work processes to improve cost effectiveness. Goals Source: Scofield (Manager) X

SAFE OPERATIONS t 1 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 so that Fort Calhoun Station is recognized as a nuclear indus-try leader. I t 1 \\ \\

~ Year-to-Date lNPO Industrial Safety Accident Rate O Fort Calhoun Year-End Goal ( 0.50) lGOODI 1.8 - --O-Industry Upper 10% V 1.6 - + 1995 INPO Industry Goal ( 0.50) 1.4 - 1.2 - 1-0.8 - 0.6 - O 0.4 - 0.2 - C C O O O O O O O O O O i i i i i e i i i i i i - Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 INDUSTRIAL SAFETY ACCIDENT RATE-INPO As stated in INPO's December 1993 publication ' Detailed Descriptions of World Asso-ciation of Nuclear Operators (WANO) Performance Indicators and Other Indicators for Use at U.S. Nuclear Power Plants': "The purpose of this indicator is monitor progress in improving industrial safety performance for utility personnel permanently assigned to the station." The INPO industrial safety accident rate value year-to-date was 0.50 at the end of October 1994. The value for the 12 months from November 1,1993 through October 31,1994 was 0.54. There were no restricted-time or lost-time accidents in October. There has been 1 restricted-time accident and 2 lost-time accidents in 1994. The values for this indicator are determined as follows: (number of restricted-time + lost-time accidents + fatalities) X 200.000 (number of station percon-hours worked) The 1994 Fort Calhoun year-end goalis 50.50. The 1995 INPO industry goal is 50.50. The approximate industry upper ten percentile value (for the period from 7/93 through 6/

94) is 0.12.

Data Source: Sorensen/Skaggs (Manager / Source) Chase / Booth (Manager / Source) Accountability: Chase / Conner Adverse Trend: None 2

- # -- 1994 Disabling injury /111 ness Frequency Rate l GOOD l X 1993 Disabling injury /lliness Frequency Rate V -O-- Fort Calhoun Year-End Goal ( 0.5) 1.2 - ~ 1-0.8 - A " y %" ^ ^ ^ ^ ^ c y" 0.2 - ~ 0 =.-, Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 DISABLING INJURY /lLLNESS FREQUENCY RATE (LOST TIME ACCIDENT RATE) This indicator shows the 1994 disabling injury / illness frequency rate. The 1993 dis-abling injury / illness frequency rate is also shown. The disabling injury / illness frequency rate year-to-date was 0.33 at the end of October 1994. There were no lost-time accidents reported for the month. There have been 2 lost-time accidents in 1994. The disabling injury / illness frequency rate for the 12 months from Novembei '993 through October 31,1994 was 0.41. The 1994 Fort Calhoun year-end goal for this indicator is a maximum value of 0.5. Data Source: Sorenson/Skaggs (Manager / Source) Accountability: Chase / Conner Positive Trend SEP 25, 26 & 27 3

-G-1994 Recordable injury /lliness Frequency Rate IGOODl -X-1993 Recordable injury /lliness Frequency Rate 2.5 - V O 1994 Fort Calhoun Year-End Goal ( 1.5) 2.25 - 2-1.75-1.5 - C O O O O O O O O ^ ^ m 1.25-X 1- __^ 0.75-0.5 - 025-0 i Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 RECORDABLE INJURY /lLLNESS CASES FREQUENCY RATE This indicator shows the 1994 recordable injury / illness cases frequency rate. The 1993 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 cases frequency rate year-to-date was 1.17 at the end of October 1994. There were 2 recordable injury / illness cases reported for the month of October. The injuries involved a cut finger and a finger caught in an elevator door. There have been 7 recordable injury / illness cases in 1994. The recordable injury / illness cases frequency rate for the 12 months from November 1, 1993 through October 31,1994 was 0.95. The 1994 Fort Calhoun year-end goal for this indicator is a maximum value of 1.5. Data Source: Sorenson/Skaggs (Manager / Source) Accountability: Conner Positive Trend SEP 15,25,26 & 27 4

-G-Contamination Events IGOODl --O-Fort Calhoun Year-End Goal ( 54) V 60-55 C O O O O O O O O O O O 50-45-h40-O $ 35-30- .!!E 25-f20-15-10-5- 0 Jan94 Feb Me Apr May Jun Jul Aug Sep Oct Nov Dec94 CLEAN CONTROLLED AREA CONTAMINATIONS 21,000 DISINTEGRATIONS / MINUTE PER PROBE AREA This indicator she as the Personnel Contamination Events in the Clean Controlled Area for contaminations 21,000 disintegrations / minute per probe area for the reporting month. This includes the contamination events associated with the spent fuel rerack project. There was 1 contamination ant in October 1994. There has been a total of 41 con-tamination events in 1994. The 1994 year-end goal for this indicator is a maximum of 54 contamination events. Data Source: Chase /Little (Manager / Source) Accountability: Chase /Lovett Adverse Trend: To exceed the year-end goal of a maximum of 54 contamination events,14 additional contamination events would have to occur in the l two remaining months of 1994. Based on a projected rate of approximately 4 events per month, the Station total will be 49 contamination events at the end of the year and the goal will be met. SEP 15 & 54 5

--M-Preventable (18 Month Totals) --C}- Personnel Error (18 Month Totals) O Personnel Errors (Each Month) 40-35-30-25-20- ~ 15-10-5- 0 i e i i i e i i i i i e i i i }" s# ,E 4 ? & 3z ,K 8 f a } s# ,E 4 ? m g a 2 o m PREVENTABLE / PERSONNEL ERROR LERs This indicator depicts 18 month totals for numbers of " Preventable" and " Personnel Error

LERs.

The graph shows the 18 month totals for preventable LERs, the 18 month totals for Personnel Error LERs and the Personnel Error totals for each month. The LERs are trended based on the LER event date as opposed to the LER report date. In September 1994, there were no events that were subsequently reported as an !.ER. No LERs were categorized as Preventable or as Personnel Error. The total LERs for the year 1994 (through September 30,1994) is 6. The total Person-nel Error LERs for the year 1994 is 2. The total Preventable LERs for the year is 2. The 1994 goals for this indicator are that the year-end values for the 18 month totals be no more than 12 Preventable and 5 Personnel Error LERs. (Note: Because this indica-tor is based on an 18 month period, the 1994 year-end totals will include LERs occur-ring in 1994 and the last 6 months of 1993.) Data Source: Trausch/Cavanaugh (Manager / Source) Accountability: Chase Adverse Trend: None SEP 15 6

i O startup D shutoown IGOODI 4-Operation j3- - Industry Average Trend Ig I T { 1-d z 7 g 3 s 0 o i i i i i e i e i i i i 91-2 91-3 91-4 92-1 92-2 92-3 92-4 93-1 93-2 93-3 93-4 94-1 Year-Ouarter SAFETY SYSTEM FAILURES This indicator illustrates the number of NRC Safety System Failures as reported by the Nuclear Regulatory Commission's Office for Analysis and Evaluation of Operational Data in the biannual" Performance Indicators for Operating Commercial Nuclear Power Reactors" report. The following NRC safety system failures occurred between the first quarter of 1993 and the first quarter of 1994: First Quarter 1993: The SG low pressure scram signal block reset values, for all 4 channels of both SGs, were greater than the allowed limits, rendering this scram input inoperable during certain operating conditions. Second Quarter 1993: A section of the piping configuration for the borated water source of the safety injection system was not seismically qualified. This could have resulted in a failure of the system to meet design requirements during a seismic event. Fourth Quarter 1993: 1) During surveillance testing, both PORVs for the LTOP system failed to open during multiple attempts. The failures were a result of differential expan-sion caused by a loop seal, inappropriate venting line back pressure, and cracked valve disks; 2) Calibration errors of the offsite power low signal relays could have prevented offsite power from tripping and the EDGs from starting in the required amount of time during a degraded voltage condition; 3) Both AFW pumps were inoperable when one was removed from service for testing and the control switch for the other pump's steam supply valve was out of the auto position; 4) Only one train of control room ventilation was placed in recirc when both toxic gas monitors became inoperable. Later during surveillance, the other train auto-started and brought outside air into the control room for a six minute period. First Quarter 1994: A single failure of an ESF relay could result in a loss of safety injection, due to premature actuation of recirculation flow, and a loss of containment spray flow. Data Source: Nuclear Regulatory Commission Accountability: Chase Adverse Trend: None 7

1994 Monthly High Pressure Safety injection System g Unavailability Value 1994 Year-to-Date High Pressure Safety injection

System Unavailability Value l GOOD l 0

1994 Fort Calhoun Goal ( 0.004) V 1995 INPO Industry Goal (0.02) -O-Industry Upper 10% (0.0011) 0.03 - 0.025 - 0.02 - A A A A A A A A A 0.015 - 0.01 - 0.005 - 0.00036 C U U ~~U U U 0 i -i-i i-i i i i i i i i i 1993 Unavailability Value Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov DecS4 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 October 1994 was 0.0. Tnere were no hours of planned or unplanned unavailability during the month. The 1994 year-to-date HPSI unavailability value was 0.0026 at the end of the month. The unavailability value for the last 12 months was 0.0024. There have been 57.48 hours of planned unavailability and no hours of unplanned j unavailability for the HPSI system in 1994. The 1994 Fort Calhoun year-end goal for this indicator is a maximum value of 0.004. ) The 1995 INPO industry goal is 0.02 and the industry upper ten percentile value (for the three year period from 7/91 through 6/94) is approximately 0.001. Data Source: Jaworski/Schaffer Accountability: Jaworski/Schaffer Positive Trend 8 i

l E Monthly Auxiliary Feodwate'r Systern Unavailability Value 1994 Year-to-Date Auxiliary Feedwater System Unavailability Value -O-1994 Fort Calhoun Goal ( 0.01) lGOODI i i V 1995 INPO Industry Goal ( 0.025) ~ O Industry Upper 10% (0.0021) i 0.025 - a a a a a a a a a a a a l l 0.02 - 0.01 5 - 0.01 - C O O O O O O O O O O O l i i 1993 Unavailability Value Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 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 October 1994 was 0.0048. There were 7.15 hours of planned unavailability for maintenance and no hours of unplanned unavailability during the month. The year-to-date unavailability value was i 0.0032 and the value for the last 12 months was 0.003 at the end of the month. There has been a total of 28.85 hours of planned unavailability and 17.26 hours of unplanned unavailability for the auxiliary feedwater system in 1994. The 1994 Fort Calhoun year-end goal for this indicator is a maximum value of 0.01. l The 1995 INPO industry goalis 0.025 and the industry upper ten percentile value (for the three year period from 7/91 through 6/94) is approximately 0.002. Data Source: Jaworski/Nay Accountability: Jaworski/Nay Positive Trend g --____-______________-_______________________-___________-___a

E Monthly Emergency AC Power Unavailability Value Year-to-Date Emergency AC Power Unavailability Value lGOODI 0 Fort Calhoun Goal ( 0.025) t -a-1995 INPO Industry Goal (0.025) 0.07-4 Industy Wdmate Upper 10*/. (0.0035) 0.06 - 0.05-0.04 - 0.03 - 0 0 3 0.02-w 0.01 - i _F1_ _ FB-B"E_II_JL-{3 O 0 1 Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 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 October 1994 was 0.0036. During the month, there were 5.3 hours of planned unavailability for surveillance tests, and no hours of unplanned unavailability. The Emergency AC Power System unavail-ability value year-to-date was 0.0146 and the value for the last 12 months was 0.0124 at 4 the end of the month. The large unavailability value for February is due to maintenance outages on both diesel generators. There has been a total of 202.04 hours of planned unavailability and 11.25 hours of unplanned unavailability for the emergency AC power system in 1994. The 1994 Fort Calhoun year-end goal for this indicator is a maximum value of 0.025. The 1994 DG unavailability has increased over 1993 DG unavailability due to changes in operational definitions of out-of service equipment. The 1995 INPO industry goalis 0.025 and the industry upper ten percentile value (for the three year period from 7/91 through 6/94) is approximately 0.0035. Data Source: Jaworski/Ronning Accountability: Jaworski/Ronning Positive Trend 10

Number of Failures 70 Demands Trigger Values for 20 Demands O Number of Failures /50 Demands -V-Trigger Values for 50 Demands E Number of Failures /100 Demands Trigger Values for 100 Demands 8- [ GOOD l ) + i 6-V V -V V Y Y Y Y Y Y Y Y 4-I l 4 = = = = = = = = = = = = 2-1 1 1 1 1 1 1 1 1 1 1 1 00h 00 00 00. 00. 00 00 00 00, 00i; 00 00 l I I I I I I I I I I I Nov93 Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct94 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 1994 goalis 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 manual initiation. 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 other demand criteria in the Definition Section of this report). Data Source: Jaworski/Ronning (Manager / Source) Accountability: Jaworski/Ronning Positive Trend 11

O DG-1 Failures /25 Demands lGOODI E DG-2 Failures /25 Demands 5-O Failure Trigger Value for 25 Demands / Fort Calhoun Goat 4-C O O O O O O O O O O O 3-2- 1-00 00 00 00 00 00 00 00 00 00 00 00 0 Nov93 Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct94 DIESEL GENERATOR REL! ABILITY (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 l 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 1994. 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. l Data Source: Jaworski/Ronning (Manager / Source) Accountability: Jaworski/Ronning Positive Trend 12 l

B DG-1 Unreliability Value B DG-2 Unreliability Value l GOODI --+- Station Unreliability Value 0.003 - industry Upper 10% (0.002 for 0.0025-a Three Year Average) 0.002-O O O O O O O O O O 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 0,0 0 0 Nov93 Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct94 EMERGENCY DIESEL GENERATOR UNRELIABILITY The purpose of this indicator is to monitor the likelihood tnat 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 year-to-date station EDG unreliability value at the end of October 1994 was 0.0. The 1994 goal for this indicator is a maximum value of 0.0. For DG-1: There was 1 start demand for the reporting month without a failure. In addition, there was 1 load-run demand without a failure. For DG-2: There was 1 start demand for the reporting month without a failure. In addition, there was 1 load-run demand without a failure. Emergency diesel generator unreliability is calculated as follows: value per DG = SU + LU - (SU x LU) where SU = Start Unreliability = number of unsuccessful starts number of valid start demands LU = Load-run Unreliability = number of unsuccessfulload-runs number of valid load-run demands Station Value = average of DG-1 and DG-2 values Data Source: Jaworski/Ronning (Managor/ Source) ) Accountability: Jaworski/Ronning ] Positive Trend 13 1 l

3 Fuel Reliability Indicator E A 1995 INPO Industry Fuel Defect Reference (5 X 104 Microcuries/ Gram) lGOODI 3 + O 1994 & 1993 Fort Calhoun Goals 15-a =cydeis _ i 4, ; y 0 i 3 Nov93 Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct94 FUEL RELIABILITY INDICATOR The Fuel Reliability Indicator (FRI) value for October 1994 was 13.89 X 10-4 microcuries/ gram. The purpose of the FRIis to monitor industry progress in achieving and maintaining a high level of fuel integrity. The October FRI value, which is greater than the zero defect threshold value, discussed below, indicates a potential fuel defect in the core. The plant operated at full power during the month except for the period from October 22 through 26. The October FRl was calculated based on the average fission product activities present in the reactor coolant during the steady state full power operation days, October 1 through 20,30, and 31. The October FRl value of 13.89 X 10d microcuries/ gram indicated a significant increase from the September value of 10.06 X 10d microcuries/ gram. The 13.89 X 10d microcuries/ gram FRI value exceeds the 1994 operational goal. The value will not significantly decrease until any leaking pin or pins are removed from the core but may show small monthly changes due to chemistry variability. Fission product activity data from October full power operation showed a Xenon-133 activity increase but no lodine spiking. The Westinghouse technical expert on fuel reliability has deter-mined that there is a potential for 1 or 2 defective fuel rod (s) in the Cycle 15 core. This predic-tion is based on a change in the Xe-133 to 1-131 ratio. This prediction has been supported by results from the CHIRON and CADE fuel reliability codes which also indicate 1 or 2 fuel pins may be failed. During the period of reduced power (October 21 through 24), we were success-fulin obtaining Cesium and lodine data that would support identification of the batch containing the failed fuel rod. Westinghouse will be sending a formal report on the evaluation by mid-November. ABB/CE reviewed the data and was also unable to conclude which batch contained a leaker. Both fuel suppliers believe that the leaker is in a very low power assembly (RPD <0.5) or it is a very tight leaker in any bundle. All of the very low power assemblies will be discharged at the end of the current fuel cycle. 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 10d microcuries/ gram indi-cates a high probability of reactor core operation with one or more fuel defects. The determina-tion of current defect-free operation reqdres more sophisticated analysis by utility reactor engineers." The value of 5.0 X 10d microcuries/ gram 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. The 1994 Fort Calhoun Station FRI performance indicator goal is to maintain a monthly FRI below 5.0 X 10-4 microcuries/ gram. Data Source: Holthaus/ Weber Accountability: Chase /Spijker Adverse Trend: An Adverse Trend is indicated based on not meeting the 1994 goal. 14 m

C Control Room Equipment Deficiencies Repairable On-Line IGOODI Q Total Number of Control Room Equipment Deficiencies V -O-Fort Calhoun Goal For Total Equipment Deficier4ics 80-70-m ] 60-5 C C- ~~~""~ 4 30-f j j f i 20-p .g g /, / ~/ / / ~. 10- / / / f f 0 Nov93 Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct94 Operator Work Around items Repairable On-Line ["] Total Number of Operator Work Around items 10- -O-Fort Calhoun Goal for Total Operator Work Around items 8-

~ c 0

0 0 0 0 0 0 0 0 c a 4-r a a n n n n E E I I i i i i i i i 1 i i Nov93 Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct94 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 number of outstanding control room equip-ment deficiencies, the number of Operator Work Around (OWA) Items repairable on-line, the number of outstanding OWAs and the Fort Calhoun goals. There was a total of 51 control room equipment deficiencies at the end of October 1994. 17 of these deficiencies are repairable on-line and 34 require a plant outage to repair. There were 15 deficiencies added and 13 deficiencies closed during the month. j There were 7 identified Operator Work Around items at the end of the month. The OWAs were on equipment tags: YCV-871B C/R Panel Al 308, CH-208 C/R Panel CB-1/2/3, RC-3C C/R Panel CB-1/2/3, RC-3D C/R Panel CB 1/2/3, F1-1392/94 C/R Panel CB-10/11, FP-368 C/R Panel CB-10/11, and MOV-D1 C/R Panel CB-10/11. 4 OWAs require an outage to repair, The 1994 Fort Calhoun monthly goal for this indicator is a maximum of 45 deficiencies and 5 OWAs. Data Source: Chase / Tills (Manager / Source) Accountability: Chase /Faulhaber Adverse Trend: None 15

i G Monthly Personnel Radiation Exposure (Non-Spent Fuel Rerack) l GOOD l -e - Personnel Cumulative Radiation Exposure (Non-Spent Fuel Rerack) + --O-Fort Calhoun Annual Goal ( 44 Person-Rem) b40-C O O O O O O O O O O O % 30-g 20-g 10-

O o.

i i i i i i i i i i i i Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 3 Monthly Personnel Radiation Exposure for Spent Fuel Rerack l GOOD l -+-- Personnel Cumulative Radiation Exposure for Spent Fuel Rerack V -O-Fort Calhoun Annual Goal ( 23 Person-Rem) e: C O O O O O O O O O O O e ~ O O O O 0 I i i i i i i i i i i i i 0-Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 COLLECTIVE RADIATION EXPOSURE The 1994 Fort Calhoun goal for collective radiation exposure, excluding the spent fuel rerack, is less than 44 person-Rem. The exposure for October 1994 was 0.659 person-Rem. The year-to-date exposure was 13.956 person-Rem. The Fort Calhoun goal for collective radiation exposure to complete the Spent Fuel Rerack is less than 23 person-Rem. The Spent Fuel Rerack exposure for October was 0.473 person-Rem. The year-to-date Spent Fuel Rerack exposure was 5.166 person-Rem. The collective radiation exposure at the end of October (i.e., the sum of non-spent fuel rerack exposure and spent fuel rerack exposure) was 19.123 person-Rem. The collec-tive radiation exposure for the last 12 months was 61.237 person-Rem at the end of the i month. The 1995 INPO industry goal for collective radiation exposure is 185 person-rem per year. The approximate industry upper ten percentile value (for the three year period from 7/91 through 6/94) is 106 person-rem per year. The yearly average for Fort Cal-houn Station for the three years from 11/91 through 10/94 was 146.386 person-rem per year. Data Source: Chase /Little (Mantger/ Source) Accountability: Chase /Lovett Adverse Trend: None SEP 54 16

O Highest Exposure for the Month (mrem) O Highest Exposure for the Year (mrem) 5000 - OPPD 4500 mrem /yr. Limit 4000 - 3000 - E ($ E 2000 - Fort Calhoun 1,000 mrem /yr. Goal 1000 - 674 $1m + 80 m,, 'w 0 October 1994 MAXIMUM INDIVIDUAL RADIATION EXPOSURE During October 1994, an individual accumulated 80 mrem, which was the highest individual exposure for the month. The maximum individual exposure for the year was 674 mrem at the end of October. i The OPPD limit for the maximum yearly individual radiation exposure is 4,500 mrem / year. The 1994 Fort Calhoun year-end goalis a maximum of 1,000 mrem. Date Source: Chase /Uttle (Manager / Source) Accountability: Chase /Lovett Adverse Trend: None 17 i i

Violations per 1,000 Inspection Hours 3.03 3-l GOOD l -O-- Fort Calhoun Goal .E C 2-1,0 mfb O O O .4 C O e 11 - E 8 i '92 '93 Oct93 Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep94 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 indicator is one month behind the reporting month due to the time in-volved with collecting and processing the data. The violations per 1,000 inspection hours indicator was reported as 1.46 for the twelve months from October 1,1993 through September 30,1994. The foilowing inspections ended during this reporting period: IER No- .Titla No. of Hours 94-19 10 CFR 20 Implementation 32 94-20 Special Inspection - Hydrazine Spill 32 92-21 Resident Monthly inspection 480 To date, OPPD has received 10 violations for inspections conducted in 1994: Level tilViolations (1) Level IV Violations (7) Level V Violations (0) Non-Cited Violations (NCV) (2) The 1994 Fort Calhoun goal for this indicator is a maximum of 1.4 violations per 1,000 inspec-tion hours. Data Source: Trausch/Cavanaugh (Manager / Source) Accountability: Trausch Adverse Trend: None 18 i .. ~.

O NRC Significant Events lGOODI Industry Average Trend y 1 1 ~ ys' AJ; 0.5 - MI Pd -n 0-i i 91-2 91-3 91-4 92-1 92-2 92-3 92-4 93-1 93-2 93-3 93-4 94-1 Year - Quarter lGOODI @ INPO Significant Events (SERs) V 2 ~ 1 1 1 1 M W// MM M I I I I I I I I I i i I 91-2 91-3 91-4 92-1 92-2 92-3 92-4 93-1 93-2 93-3 93-4 94-1 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 NBC significant events occurred between the second quarter of 1991 and the First quarter of 1994: Second Quarter 1991: Safety related electrical 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 fourth quarter of 1991 and the first quarter of 1994: Second Quarter 1992: Intake of Transuranics during Letdown Filter Change-out. Third Quarter 1992: 1) RC-142 LOCA; and 2) Premature Lift of RC-142. First Quarter 1993: Inoperability of Power Range Nuclear instrumentation Safety Channel D. Second Quarter 1993: SBFU Breaker Relay (Switchyard) Plant Trip Fourth Quarter 1993: Unexpected CEA Withdrawal. Data Source: Nuclear Regulatory Commission & INPO Accountability: Chase Adverse Trend: None g

i 3- @ Number of Missed STs Resulting in LERs 2-t 1-l 1 0 0 0 0 0 0 0 0 0 0 0 0 0 I I l l 1 I i i i i i i i i i i 92 93 Nov93 Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct94 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 October 1994. 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-t 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 1994 Fort Calhoun monthly goal for this indicatoris 0. Data Source: Monthly Operating Report & Plant Licensee Event Reports (LERs) Accountability: Chase /Jaworski Positive Trend SEP 60 & 61 20 f

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. l 21

l ~ E Net Generation (10,000 MW hours) l 40-4.6 34.85 M.88 33.56 3.91 34.14 33.88 12j30-27.8 i

1

~ o 10-l l 1.54 E 0 g i i j i i Nov93 Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct94 STATION NET GENEFIATION During the month of October 1994 a net total of 338,792 MWH was generated by the Fort Calhoun Station. The lower net generation compared to September reflects a planned reduction in power from October 22 through 24 to check for leaking fuel pins. Cumulative net generation for Cycle 15 was 3,759,608 MWH at the end of the month. Energy losses for the month of February 1994 were attributable to a generator and reactor trip that occurred following the failure of the relay for the Containment High Pressure Signal Supervisory Circuit. Energy losses for the month of January 1994 were attributable to derates to repair condenser tubes and a failed level control valve on a heater drain tank. i l l Energy losses for the month of December 1993 were a result of a forced outage that began on December 6 and ended on December 7. The outage was caused by an EHC test failure. Energy losses for September, October and November 1993 were attribut-ab.e to the shutdown for the Cycle 15 refueling outage, which began on September 25 and ended on November 26. Data Source: Station Generation Report Accountability: Chase l Adverse Trend: None 22 i

Forced Outage Rate { @Dl -O-Fort Calhoun Goal (2,4%) 12%- y 10.1 9.3 8%- 6%- Cycle 15 Refueleg outage 4%- C O O O O O O O O O O O

- ~

1.38 f 0% i '91 '92 '93 Nov93 Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct94 FORCED OUTAGE RATE The forced outage rate (FOR) was reported as 0.93% for the twelve months from November 1,1993 thru October 31,1994. The 1994 year-to-date FOR was 0.67% at the end of the month. A forced outage occurred on February 11,1994 due to a generator and reactor trip that occurred following the failure of the relay for the Containment High Pressure Signal Supervisory Circuit. The generator was off-line for 48.9 hours. A forced outage occurred on December 6,1993 when the plant tripped during weekly testing of the turbine EHC system. The generator was off-line for 27.1 hours. The 1994 Fort Calhoun year-end goal for this indicator is a maximum value of 2.4%. The 1993 Fort Calhoun year-end goal was a maximum value of 2.4%. Data Source: Monthly Operations Report Accountability: Chase Positive Trend 23

O Monthly Unit Capacity Factor -et-Cycle 15 Unit Capacity Factor -+- 36 Month Average Unit Capacity Factor 110% - ~ 100% - 90%- = m / N 80%- s c 0 0 y 70%- 4 m p F Cycle 15 50%- Re WN outage 40%- 30%- 20%- 10%- 0% Nov93 Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct94 UNIT CAPACITY FACTOR This indicator shows the plant monthly Unit Capacity Factor, the Unit Capacity Factor for the current fuel cycle and the 36 month average Unit Capacity Factor. The Unit Capacity Factor for October 1994 was reported as 95.1%. Energy losses for the month were due to a derate to 32% power to check for leaking fuel pins. At the end of the month the Cycle 15 Unit Capacity Factor was 89.8%, and the Unit Capacity Factor for the last 36 months was 77.6%. The Unit Capacity Factor is computed as follows: Net Electrice.1 Energy Generated (MWH) Maximum Dependable Capacity (MWe) X Gross Hours in the Reporting Period Data Source: Monthly Operating Report Accountability: Chase Positive Trend 24

Monthly EAF Year-to-Date Average Monthly EAF lGOODI industry Median Value (76.7% for a + Three Year Average) 100 % - im = l as 9 ll lft; $$) N ..N f(W $id N@Q V # l c g n; 85.6 P @Q .s W M 'r p g-m!hlk 76.2 80% - ld M d if 3 2 1 1 M d l M T f i $n1 "h "$s; a $a[g g y M q

c

+ ~ ?w"E e g r z u n 1 01 5 W N 0' Refuehng ;., gl( 60.8 [ g g y .g; p g gi 60%-- cydeis .- 9 gg g <r e g g p g i g g p; g g d ? l outage Pg $:yl ${ f4 M hii Fi Yl g n Q $W 5; p us. W+ n. gy q g. w &g l] - 5 40%- k 4 h+ k h by%y$ h( k

1 h

g g ? It O Md 6 h 6 g (4 y$ a et y 9 j p k 7 R Lis $1 y M F

9 t

5 a 2 M t% M T i 'a y L w. !4h N 20%- Sllt I b 5 h b b f.h l ~ M Q Q: h l &y T f 2 g) R y p$ a a s = ,$fd k N N kk $f kN [IIl N h 2 k N(( $ h h h c. M h s b 0% i i i i i i i i i i i '91 '92 '93 Nov93 Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct94 [ EQUIVALENT AVAILABILITY FACTOR This indicator shows the plant monthly Equivalent Availability Factor (EAF), the year-to-date average monthly EAF, and the year-end average monthly EAF for the previous 3 i years. t The EAF for October 1994 was reported as 96.92%. Energy losses for the month were due to a derate to 32% power to check for leaking fuel pins. The year-to-date monthly average EAF was 96.66% at the end of the month. Energy losses for the month of February were due to a generator and reactor trip that occurred following the failure of the relay for the Containment High Pressure Signal Supervisory Circuit. Energy losses for the month of January were due to derates for condenser tube repair and a failed level control valve on a heater drain tank. The Fort Calhoun average monthly EAF for the three years piior to this report was 1 78.03%. 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) i Accountability: Chase Adverse Trend: None 25 l g-

D Monthly Unit Capability Factor --t$- Year to-Date Unit Capability Factor -+- 36 Month Average Unit Capability Factor 4 O Fort Calhoun Goal l GOOD l 1995 INPO Industry Goal ( 80%) Industry Upper 10% (89.9% for a Three Year Average) 100% - = n ~ = /E E I 80%- a A Q R ~ 4 p L M b E Nk $h Cycle 15 hh I 40%- Refuehng $ k 4[ h ki 50 ($ 7 '8* E N k $fh di N k 5 I= 20%- e er m a e en r w w m a i I i i l 1 i i i I i i Nov93 Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct94 UNIT CAPABILITY FACTOR This indicator shows the plant monthly Unit Capability Factor (UCF) value, the year-to-date UCFs, the 36 month average UCFs, and the UCF goals. UCF is defined as the ratio of the available energy generation over a given period of time to the reference energy generation (the energy that could be produced if the unit were operated continu-ously at full power under reference ambient conditions) over the same time period, expressed as a percentage. The UCF for October 1994 was reported as 96.2%. Energy losses for the month were due to a planned derato to check for leaking fuel pins. The year-to-date UCF was 97.7%, the UCF for the last 12 months was 89.5%, and the 36 month average UCF was reported as 76.1% at the end of the month. Energy losses for the month of February 1994 were due to a generator and reactor trip that occurred following the failure of the relay for the Containment High Pressure Signal Supervisory Circuit. Energy losses for the month of January were due to derates to repair condenser tubes and a failed level control valve on a heater drain tank. Energy losses for the month December 1993 were due to rampup from the Cycle 15 Refueling Outage and a plant trip that occurred on December 6 during testing of the EHC system. The 1995 INPO lndustry goalis 80% and the industry upper ten percentile value (for the three year period from 7/91 through 6/94)is approximately 89.9%. The 1994 Fort Calhoun year-end goal for this indicator is a minimum of 96.03%. Data Source: Generation Totals Report & Monthly Operating Report Accountability: Chase Positive Trend 26

D Monthly Unplanned Capability Loss Factor 50%- -et-Year-to-Date Unplanned Capability Loss Factor O Fort Calhoun Goal 40%- 1995 INPO Industry Goal ( 4.5%) t Industry Upper 10% (1.36% for a Three Year Average) 30%- Cyde 1s Refueling 20%- h 10%- T n n n n = = e 9 g y m m a Nov93 Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct94 UNPLANNED CAPABILITY LOSS FACTOR This indicator shows the plant monthly Unplanned Capability Loss Factor (UCLF), the year-to-date UCLF and the goal. UCLF is defined as the ratio of the unplanned energy losses during a given period of time, to the reference energy generation (the energy that could be produced if the unit were operated continuously at full power under reference ambient conditions), expressed as a percentage. The UCLF for the month of October 1994 was reported as 0.0%. The year-to-date UCLF was 1.93%, the UCLF for the last 12 months was 3.65%, and the 36 month average UCLF was reported as 5.73% at the end of the month. Unplanned energy losses for the month of February 1994 were due to a generator and reactor trip that occurred following the failure of the relay for the Containment High Pressure Signal Supervisory Circuit. Unplanned energy losses for the month of January were due to derates to repair condenser tubes and a failed level control valve on a heater drain tank. Unplanned energy losses for the month of December 1993 were the result of a plant trip that occurred during EHC testing. The 1995 INPO industry goal is 4.5% and the industry upper ten percentile value (for the three year period from 7/91 through 6/94) is approximately 1.36%. The 1994 Fort Calhoun year-end goal for this indicator is a maximum value of 3.97%. Data Source: Generation Totals Report & Monthly Operating Report Accountability: Chase Positive Trend 27

- FCS Reactor Scrarns Per 7,000 Hours Cntical Year-to-date -+- FCS Reactor Scrams Per 7,000 Hours Critical for the last 36 months --O-1994 & 1993 Fort Calhoun Goals (0.0) -a-1995INPOIndustryGoal 6- -O-Industry Upper 10% (0.48 per 7,000 hours critical over a 36 month time period) 5-4- 3- ~ 2-a 0 0 ^ ? ? ? 0 0 ^ 1-h 0 0; .0 O, 0. O, 4 x 0--: r-t,- Nov93 Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct94 l cyde15 g Numberof FCS ReactorScrams 3 4~ " "8 m 2 3-outage $j h,0 2-1 1 1-0 0 0 0 0 0 0 0 0 0 0 0 '90 '91 '92 '93 Nov93 Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct94 i UNPLANNED AUTOMATIC REACTOR SCRAMS PER 7,000 HOURS CRITICAL The upper graph shows the number of unplanned automatic reactor scrams per 7,000 hours critical (as defined in INPO's 12/93 publication " Detailed Descriptions of Interna-tional Nuclear Power Plant Performance Indicators and Other Indicators") for Fort Cal-houn Station. The lower graph shows the number of unplanned automatic reactor scrams that occurred during each month for the last twelve months. The year-to-date station value was 0.96 at the end of October 1994. The value for the 12 months from November 1,1993 through October 31,1994 was 1.72. The value for the last 36 months was 1.94. An unplanned automatic reactor scram occurred on February 11,1994 when supervi-sory relay 86B/CPHSS failed. An unplanned automatic reactor scram occurred on December 6,1993 during EHC testing. The 1994 Fort Calhoun goal for this indicator is 0. The 1995 INPO industry goal is a maximum of 1 unplanned automatic reactor scram per 7,000 hours critical. The industry upper ten percentile value is approximately 0.48 scrams per 7,000 hours critical for the 36 month time period from 7/91 through 6/94. Data Source: Monthly Operations Report & Plant Licensee Event Reports (LERs) Accountability: Chase Adverse Trend: None 28

i i ~ E Safety System Actuations (INPO Definition) O Fort Calhoun Goal (0.0) O Industry Upper 10 Percentile l i 2-i l 1-cycle is Refuehng outege 0 0 0 -- i i e i 91 '92'93 Nov93 Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct94 UNPLANNED SAFETY SYSTEM ACTUATIONS -(INPO DEFINITION) There were no INPO unplanned safety system actuations during the month of October 1994. There was 1 INPO unplanned safety system actuation during the month of February 1994. It occurred on February 11 when supervisory relay 86B/CPHSS failed, which resulted in tripping relay 86B/CPHS. The CPHS relay trip actuated the Safety injection Actuation Signal, Containment isolation Actuation Signal, Ventilation Isolation Actuation Signal and Steam Generator Isolation Signal. The Steam Generator Isolation Signal automatically closed both main steam isolation valves, which resulted in a concurrent turbine and reactor trip. An INPO unplanned safety system actuation occurred during the month of July 1992. It was due to the loss of an inverter and the subsequent reactor trip on 7/3/92. The 1994 Fort Calhoun goal for this indicator is 0. i l Data Source: Monthly Operations Report & Plant Licensee Event Reports (LERs) Accountability: Jaworski/Foley/Ronning Adverse Trend: None 29

12 Month Running Total SSAs (NRC Definition) -+- Critical Hours Safety System Actuations (NRC Definition) 10- - 1000 E Cycle 15 - 900 g 8-Refueling - 800 v v - M. 700 e o Outage k 6- - 600 [ [ - 500 - 3 E4- - 400 f 2 - 300 o I2- - 200 0 i e i i '91 92 '93 NDJFMAMJJASONDJFMAMJJASO 1992 1993 1994 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 Safet/ hjection 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. There was 1 NRC unplanned safety system actuation during the month of Febrt ary 1994. It occurred on February 11 when supervisory relay 86B/CPHSS failed, which resulted in a concur-rent turbine and reactor trip. There were 3 NRC unplanned safety system actuations in 1993: 1) in December 1993 the main turbine and reactor tripped during Electro-Hydraulic Control pump start testing; 2) In June 1993 the inadvertent jamng of a 345 KV fault relay in the switchyard caused a turbine and reactor trip; and 3) In April 1993 a non. licensed operator mistakenly opened the wrong potential fuse l drawer, causing a low voltage alarm on bus 1 A1, a loadshed on bus 1 A1 and an auto start of an EDG. There were 4 unplanned safety system actuations in 1992: 1) In August, due to the failure of an AC/DC converter in the Turbine Electro Hydraulic Control system, pressurizer safety valve RC-142 opened prior to reaching design pressure during a plant transient and trip; 2) On July 3 there was an inverter failure and the subsequent reactor trip; 3) 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; and 4) in May 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 2 unplanned safety system actuations in the last 12 months. The 1994 Fort Calhoun goal for this indicator is 0. Data Source: Monthly Operations Report & Plant Ucensee Event Reports (LERs) Accountability: Jaworski/Foley/Ronning Adverse Trend: None 30

E Monthly Gross Heat Rate I --W - Year-to-Date Gross Heat Rate O 1994 &1993 Fort Calhoun Goals 10.5-10300 10223 10.25-h cyte is I , 9.75-g 8 b 10-i i '91 '92 '93 Nov93 Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct94 GROSS HEAT RATE This indicator shows the Gross Heat Rate (GHR) for the reporting month, the year-to-date GHR, the goals and the year-end GHR for the previous 3 years. The gross heat rate for Fort Calhoun Station was 10,161 for the month of October 1994. The 1994 year-to-date GHR was 10,202 at the end of the month. The GHR was not calculated for the month of November 1993 because of the Cycle 15 Refueling Outage. The GHR varies with fluctuations in river water temperature. In general, the GHR im-proves during the winter months and degrades during the summer. This is because the gross heat rate is not normalized to the design river water temperature of 60 degrees Fahrenheit. The 1994 Fort Calhoun year-end goal for this indicator is $10,190. Data Source: Holthaus/ Gray (Manager / Source) Accountability: Chase /Jaworski Adverse Trend: None 31

Monthly Thermal Performance - Year-to-Date Average Monthly Thermal Performance 0 1994 & 1993 Fort Calhoun Goals lGOODI --+- 1995 INPO Industry Goal ( 99.5%) Industry Upper 10% (99.9%) 100Y.- L L ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ Cycle 15 5 Re W l d" E ^ = 4 4 z 2 n o .h, a s a h*It g*g W ~gp* M M Mre t ~ 98 % I i i i I 6 i i i i i i Nov93 Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct94 THERMAL PERFORMANCE This indicator shows the Thermal Performance value for the reporting month, the year-to4 ate average monthly thermal performance value, the Fort Calhoun goals, the 1995 INPO industry goal and the approximate industry upper ten percentile value. The thermal performance value for October 1994 was 99.23%. The year-to-date aver-age monthly thermal performance value was 99.32% at the end of the month. The average monthly value for the 12 months from November 1,1993 through October 31, 1994 was 99.34%. Thermal Performance improved in May as a result of the backwash valve adjustments on "A" Condenser and improvements in Heater 2A level control. The low thermal parformance value for February 1994 is attributable to level control problems on heaters 3A and 5B, and to spring runoff resulting in screen carry-over and condenser fouling. Improvements made during the month of March were: warrn water recirc. was taken off-line; some recovery in condenser performance was achieved due to backwashing at regular intervals; and the level control problems for heater 3A were corrected. The 1994 Fort Calhoun year-end goal for this indicator is a minimum of 99.5%. The 1993 Fort Calhoun goal was a minimum of 99.4%. The 1995 INPO industry goalis 99.5% and the industry upper ten percentile value (for the one year period from 7/93 through 6/94) is approximately 99.9%. Data Source: Jaworski/Popek Accountability: Jaworski/Popek Adverse Trend: None 32

t l 1 l ThermalOutput -O-Fort Calhoun 1495 MW Goal - Tech Spec 1500 MW Limit 45 a 1400- ~ A 1350-yv

g"

~

W s

1300- f"4 s l l s s 1250-f g Rb 1200- ~ ' , W@ gff i 9 ,.jj;. 1100-ca

w 1050-

,'N* G Y ^ s c 1000-J

g

s 2 950 - ~ +1.m Ja; .= 'M EID 900 - M 2::w - m + < < 850 - :...' .g 800 - M .j.3 750 - a-- ~ + + gg 700 - 'c' zw ^.' ^ M. ~ 650 - ~ m 600 - 1 s 550-74 2 500 - 450 1 3 5 7 9 11 13 15 17 19 21 23 25 27 29 31 DAILY THERMAL OUTPUT The thermal output graph displays the daily operating power level during October 1994, the 1500 thermal megawatt average technical specification limit, and the 1495 thermal megawatt Fort Calhoun goal. Energy losses for the month were due to a planned derate to check for leaking fuel pins. Data Source: Holthaus/ Gray (Manager / Source) Accountability: Chasemlls Adverse Trend: None 33

~ Equipment Forced Outage Rate /1,000 Critical 0.86 Hours for a 12 Month Interval l GOOD l O 1993 & 1994 Fort Calhoun Year-End Goals ( 0.2) V 0.6 -< 0.5 1 ~ 0 0.4 - 0.2 - C O O O O O O O O O O O 0 i i i i 91 92 '93 Nov93 Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct94 r 2-E Number of Equipment Forced Outages Per Month 1-0 i i i i i i i i i i y 8 ,E S a 47 ,8 4 p m& 9 o a s s oz o EQUIPMENT FORCED OUTAGES PER 1,000 CRITICAL HOURS l The equipment forced outage rate per 1,000 critical hours for the 12 months fron No-l vember 1,1993 through October 31,1994 was 0.12. The rate per 1,000 critical haurs l for the months from January through October 1994 was 0.14. ( An equipment forced outage occurred on February 11,1994 when the plant expen-enced an unplanned automatic reactor trip as a result of the failure of the relay for.he Containment High Pressure Signal Supervisory Circuit. An equipment forced outage occurred in August 1992 and continued through Septem-ber. It was due to the failure of an AC/DC converter in the Turbine Electro Hydraulic Control System. The 1994 Fort Calhoun year-end goal for this indicator is a maximum value of 0.20. Data Source: Monthly Operations Report & Plant Licensee Event Reports (LERs) Accountability: Chase /Jaworski Positive Trend 1 34

l # of Component Categories 40-35- -+- # of Application Categories 30- -A-Total # of Categories $f 25-Fy 20-O A 10-

== h7 5-0 M93 J J A S O N D J F M A M J J A S 094 E WearOut/ Aging @ Other Devices 8 Manufacturing Defect O Maintenance / Action 4.8% 0 Engineering / Design @ Error / Operating Action 4.8% W 43 4% 4.8% Percent of Total Failures During / the Past 18 Months s' f 3.7% IIII 85 COMPONENT FAILURE ANALYSIS REPORT (CFAR)

SUMMARY

The top chart illustrates the number of component categories, application categories and total categories in which the Fort Calhoun Station has significantly higher (1.645 standard deviations) failure rates than the industry failure rates during the past 18 months (from January 1993 through June 1994). Fort Calhoun Station reported a higher failure rate in 5 of the 87 compo-nent categories (valves, pumps, motors, etc.) during the past 18 months. The station reported a higher failure rate in 6 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 catcgories) for the 96 failure reports that were submitted to INPO by Fort Calhoun Station during the past 18 months. Of these, the failure cause was known for 83. The pie chart reflects known failure causes.

Data Source: Jaworski/ Frank (Manager / Source) Accountability: Jaworski/ Frank Adverse Trend: None 35

--+-- Components With More Than One Failur l GOOD l 25- --M-- Components With More Than Two Failures 20 - ~ 15-14 \\12 12 12 12 10 10-v 9 8 8 8 7 7 5-g 4, 2 2, m_. 0 ~ NI A 1 1 1 1 i i i i i e i i i Nov93 Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct94 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 1 failure during the eighteen month CFAR period and the number of NPRDS components with more than 2 failures during the eighteen month CFAR period. During the last 18 reporting months there were 8 NPRDS components with more than 1 failure.1 of the 8 had more than 2 failures. The tag numbers of the components with more than 1 failure are: AC-10A, AC-100, AC-10D, FW-48, FW-4C, HCV-386-0, NT-001 and RC-374. The tag number of the component with more than 2 failures is AC-100. Recommendations and actions to correct these repeat component failures are listed in the quarterly Component Failure Analysis Report. Data Source: Jaworski/ Frank (Manager / Source) Accountability: Chase Adverse Trend: None 36 = ~

Calculated Check Valve Failure Rate per Million Cornponent Hours Calculated Industry Check Valve Failure Rate per g Million Component Hours 3- -O-Fort Calhoun Goal 2.5 - 2-C C $ 1.5-1 1 i_ 0.5 - 0 11*9293 Nov94 Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct94 No. of Failures CHECK VALVE FAILURE RATE This indicator shows the calculated Fort Calhoun NPRDS check valve failure rate, the Fort Calhoun goal and the industry check valve failure rate average. The failure rates are based on submitted NPRDS failure reports for an 18 month time interval. They do not include failure reports outside of the 18 month time interval. The interval starts 22 months prior to the current month and ends 4 months prior to the current month. For example, the October 1994 Component Failure Analysis Report (CFAR) covers the 18 month interval from January 1,1993 through June 30,1994. This delay is due to the time involved in collecting and processing failure report data. The actual numbers of NPRDS reportable check valve failures at Fort Calhoun Station are shown above on the graph at the left side of the page. For October 1994, the CFAR provided the following failure rates: Fort Calhoun Station 1.17 E-6 Industry (excluding FCS) 1.58 E-6 The recent increase in the FCS failure rate is due to 2 reportable failures of RC-374, Pressurizer RC-4 Spray Line Check Valve; one failure occurred in October and another in November 1993. The 1994 Fort Calhoun monthly goal for this indicator is s1.75 E-6. Data Source: Jaworski/ Frank (Manager / Source) Accountability: Jaworski/Rollins Adverse Trend: None SEP 43 37

D Radioactive Waste Buried This Month (in cubic feet) 750-Cumulative Radioactive Waste Buried l GOOD l -O-Fort Calhoun Goal For Waste Buried (500 cubic feet) V 1995 NO Must@oal(3,W ce feet) 600 - Industry Upper 10% (965.3 cubic feet) / C C C C C O _ 450-b E 300 - 150 -

i. N E

r %$;je i [ EQMs "d We $ $0i i i i i i i Jan94 Feb Mar Apr May Jun94 VOLUME OF LOW-LEVEL SOLID RADIOACTIVE WASTE [ This indicator shows the volume of the monthly radioactive waste buried, the cumulative annual total for radioactive waste buried, the Fort Calhoun and INPO goals, and the approximate industry upper 10%. Amount of solid radwaste shipped off site for processing during October (cubic feet) 2,080.0 Amount of metals frorn rack cut-up shipped off-site for processing during October (pounds) 38,900.0 Volume of Solid Radwaste Buried during June (cubic feet) 206.0 Cumulative volume of solid radioactive waste buried in 1994 (cubic feet) 543.6 Amount of solid radioactive waste in temporary storage after July 1,1994 (cubic feet) 0.0 The 1994 Fort Calhoun goal for the volume of solid radioactive waste which has been buried is 500 cubic feet. The goal was exceeded in June because OPPD's 18 month goal (established in 1993) allowed the opportunity to further reduce the amount of solid i radioactive waste. The 1995 INPO industry goalis 110 cubic meters (3,884 cubic feet) per year. The industry upper ten percentile value from 7/91 through 6/94 is approxi-mately 27.33 cubic meters (965.3 cubic feet) per year. Data Source: Chase /Breuer (Manager / Source) Accountability: Chase /Lovett Adverse Trend: Although the 1994 goal was exceeded, this indicator is not exhibiting an adverse trend because Fort Calhoun did not exceed the 18 month goal of 1,500 ft.8 that was established in 1993. The 18 month total for Fort Calhoun was 1,401.4 ft.8 at the end of June 1994. SEP 54 8 4 l l

E Primary System Chemistry Percent of Hours Out of Limit lGOODI -O-Fort Calhoun Goal ( 0.02) V 3%- 2%- O O O O O O O O O O l 1%- 0% i Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 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 6 key chemistry parameters. The key parameters are: lithium, dissolved oxygen, chlorides, fluoride, hydrogen and sus-pended solids.100% equates to all 6 parameters being out of limit for the month. The Primary System Chemistry Percent of Hours Out of Limit was 0.53% for the month of October 1994. The 1994 Fort Calhoun monthly goal for this indicator is a maximum of 2% hours out of limit. Data Source: Smith / Spires (Manager / Source) Accountability: Chase / Smith Positive Trend 39

E Secondary System CPI 2-l GOOD l --O-Fort Calhcun Goal ( 1.5) 4 1.9 - 1.8 - 1.7 - 1.6 - 1.5 - O O O O O O O O O O O 1.4 - 1.3 - 1 i i i._ I i i i i i i i i Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 SECONDARY SYSTEM CHEMISTRY Criteria for calculating the Secondary System Chemistry Performance Index (CPI) are:

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

per day. The CPI for October 1994 was 1.11. The year-to-date average monthiy CPI value was 1.18 at the end of the month. The CPI for December 1993 was 1.92. This relatively higher number was due primarily to iron transport following the plant start-up. The 1994 Fort Calhoun monthly goal for the CPI is a maximum value of 1.5. The CPI calculation is different from that reported in 1993 in that it reflects the recent INPO revision to the calculation. This revision addresses the penalties for the beneficial effect of alternative chemistry,i.e., morpholine, such as used at Fort Calhoun Station, and focuses more on specific impurities. Data Source: Smith / Spires (Manager / Source) Accountability: Chase / Smith Positive Trend 40

/ COST I Goal: To operate Fort Calhoun Station in a manner that cost effectively maintains nuclear generation as a viable source of electricity. I 41

i 4- -M-Actuals -O-Budget A Plan 3.75-3.5 - I h3 3.25-E b ^ 3-2.75- ~ 2.5 D91 D92 D93 J94 F M A M J J A S O N D94 D95 D96 D97 D98 Months CENTS PER KILOWATT HOUR The purpose of this indicator is to quantify the economical operation of Fort Calhoun Station. The cents per kilowatt hour indicator represents the budget and actual cents per kilowatt hour on a 12 month rolling average for the current year. The basis for the budget curve is the approved 1993 and 1994 revised budget. The basis for the actual curve is the Financial and Operating Report. The December 31 amounts are also shown for the prior years 1991,1992 and 1993. In addition, the report shows the plan amounts for the years 1995 through 1998 for refer-ence. The basis for the dollars are the Nuclear Long Range Financial Plan and the 1994 Corporate Planning and Budget Review. The basis for the generation is provided by Nuclear Fuels. The unit price (2.81 cents per kilowatt hour for the reporting month)is averaging lower than budget due to expenses being below budget while generation exceeds the budget. Data Source: Scofield/Jamieson (Manager / Source) Accountability: Scofield Positive Trend 42 i

l i M fuclear Services Division Staffing O Production Engineering Division Staffing @ Nuclear Operations Division Staffing B TotalNuclearStaffing 7 7 8 7 8 9 0 7 7 8 4 2 1 6 5 5 4 4 800-e 5 9 3 2 4 S 7 .m S I 5 $' S b f i M E 700- $L e 600 - 3 4 4 $ i ~ Q 4 4 4 g y 4 4 h f f f ,b. n E 500-c w w 4 s gf rff! f f ' f 400-7 I 1 1 1 1 300-0 ? 9 { 0 0 9 9 9 g 2 g -l 13 n 1 1 1 1 ? 3 5 g 6 2 f 200-p 1 1-1- 1 1 g h 4 7 6 3 6 100-5 [ 0 h lill3 h ? h 4 g g 4 5 5 8 h 0 i i i i i i i Jan90 Jan91 Jan92 Jan93 Jan94 Apr94 Jul94 Oct94 ACTUAL STAFFING LEVEL (UPDATED QUARTERLY) STAFFING LEVEL The actual staffing levels for the three Nuclear Divisions are shown on the graph above. The authorized staffing levels for 1994 are: 1994 Authorized Staffing 453 Nuclear Operations Division 191 Production Engineering Division 117 Nuclear Services Division Data Source: Ponec (Manager & Source) Accountability: Ponec Adverse Trend: None SEP 24 43 j i l A

- Spare Parts inventory Value ($ Million) 17-Cycle 15 Rdm% 16-15-25 y14-O o 13-5 12-11-i i i i e a i i i i i Nov93 Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct94 SPARE PARTS INVENTORY VALUE j The spare parts inventory value at the Fort Calhoun Station at the end of October 1994 was reported as $16,433,733. Data Source: Steele/Huliska (Manager / Source) Accountability: Wilfrett/McCormick Adverse Trend: None 44

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. 45

O Corrective Maintenance 9 Non-Corrective / Plant Irnprovements E Preventive Maintenance = Fort Calhoun Goal 776 800-723 752 720 691 700-626 617 581 600-g l 500-5g 9 % ? o = = 200- '/ // '/,- //. h (771 r77l F73 / O i i i i i i i i i i i Nov93 Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct94 Non-Outage Maintenance Work Order Backlog O Totaiuwos a uwos which exceed Maintenance Compietion coais 400-380 ) 350-300-250-230 200-150- -kh >ays 100- >3 90 >180 46 50 50 - 1 14 16 days ays yfffj d I days l l 30 i zz., - o i i i i i i l Priority 1 Priority 2 Priority 3 Priority 4 Priority 5 Priority 6 l Non-Outage Maintenance Work Order Aging MAINTENANCE WORKLOAD BACKLOGS l This indicator shows the backlog of non-outage Maintenance Work Orders remaining l open at the end of the reporting month. It also includes a breakdown by maintenance i classification and priority. The 1994 goal for this indicator has been changed to 400 non-outage corrective MWOs. To ensure that the MWO backlog is worked in a timely i i manner, non-outage maintenance completion goals have been established as: Gaal Priority 1 Emergency N/A Priority 2 Immediate Action 3 days j Priority 3 Operations Concem 14 days l Priority 4 Essential Corrective 90 days l Priority 5 Non-Essential Corrective 180 days Priority 6 Non-Corrective / Plant improvements N/A Data Source: Chase /Schmitz (Manager / Source) Accountability: Chase /Faulhaber Adverse Trend: None SEP 36 46 i l

O Ratio of Preventive to Total Maintenance 100% - 90%- 80% - 70%- ~~~~ ~ 60%- ^ 50%- 40% - 30%- 20%- 3. 10%- gg 0% i i Nov93 Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct94 2%- O Preventive Maintenance items Overdue GOOD --O-Fort Calhoun Goat V Data 1 % -- Unavailable due to ?=5,o-o-o-o r 2 c_ c o--o --o outage l 0% ,I I, Nov93 Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct94 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 48.34% for the month of October 1994. The trend of this ratio reflects the revised definition of corrective maintenance which was implemented in March. The lower graph shows the percentage of preventive maintenance items overdue. During October,524 PM items were completed.1 of these PM items (0.19% of the total) was not completed within the allowable grace period or administratively closed. The 1994 Fort Calhoun monthly goal for the percentage of preventive maintenance items overdue is a maximum of 0.5%. i Accountability: Chase /Faulhaber l Data Source: Chase /Schmitz/Meistad (Manager / Sources) Positive Trend SEP 41 1 47

E Rework As identified By Planning or Craft -O-Fort Calhoun Goal (>3%) l 5%- 4%- ey 3.16 % 3%- C l w w w w 2.51 % -g 2.43 % 2.44 % O 2.06 % o 2% - E 1.58 % 0 1%- 0% i i j i i Apr94 May Jun Jul Aug Sep Oct94 PERCENTAGE OF TOTAL MWOs COMPLETED PER MONTH IDENT!(IED 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 1994 Fort Calhoun monthly goal for this indicator is <3% Data Source: Faulhaber/Schmitz (Manager / Source) Accountability: Chase /Faulhaber Adverse Trend: None 48

80%- 5 Maintenance Overtime -M-12 Month Average Maintenance Overtime l GOOD l

~

--O-- Fort Calhoun *On-Line* Goal ( 10%) 60%- l 50%- Cycle 15 I Refuehng 40%- j 30%- l 1 20%- 10%- O O O O O O ^ ^ 0o,r i i i i i u Nov93 Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct94 MAINTENANCE OVERTIME I The Maintenance Overtime Indicator monitors the ability to perform the desired mainte-l nance activities with the allotted resources. l The percent of overtime hours with respect to normal hours was reported as 8.53% for I the month of October 1994. The 12 month average percentage of overtime hours with respect to normal hours was reported as 10.24% at the end of the month. The 1994 Fort Calhoun monthly "on-line" goal for this indicator is a maximum value of 10 % l l Data Source: Chase /Schmitz (Manager / Source) Accountability: Chase /Faulhaber Positive Trend 49 ) l l __ ___a

i O Open irs Related to the Use of Procedures (Maintenance) @ Closed irs Related to the Use of Procedures (Maintenance) E Procedural Noncornpliance irs (Maintenance) 2 -. l 1-000 000 000 000 00 00 000 000 000 000 0-000 4 8 1 1 I i i i i I 4 i Nov93 Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct94 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 October 1994. There was 1 procedural noncompliance incident (IR 940323) for maintenance reported for the month of September 1994. The IR was written to document procedural noncom-pliance that occurred when a mercury thermometer was used, rather than the required alcohol thermometer, during a surveillance test. Data Source: Chase / Keister (Manager / Source) Accountability: Chase / Conner Adverse Trend: None SEP 15,41 & 44 50

E Completed Scheduled Activities (All Crafts) O Numberof EmergentMWOsCompleted O Fort Calhoun Goal (80%) ] 110 m $ 100%- 2 100 v S g 90%- - 90 g 8 80 % - C 0 0 0 - 80 $ c 0 @ 70%- - 70 m o O 5 60 % - 60 g 50%- 46 lZ 50 g } 40%- '/V jl r a % Completed

//

% Completed ((I % Completed 34 % Completed //; 40 { 3 Scheduled '((: Scheduled /// Scheduled r'/ E Scheduled P': g 30%- Activities Not ((// Activities Not f'/f Activities Not I/ Activities Not 'S - 30 W

/p

W Available [/j Available $((: Available $[I 20 3 Available D 20%- f h //. 7/, /// o 10%- f' / f h,k: /h Z? 'Z'I o 0% -0 i 8 O July 94 August September October 34 PERCENT OF COMPLETED SCHEDULED MAINTENANCE ACTIVITIES (ALL MAINTENANCE CRAFTS) This indicator shows the percent of the number of completed scheduled maintenance activities as compared to the number of scheduled maintenance activities concerning all Maintenance Crafts. Maintenance activities include MWRs, MWOs, STs, PMOs, cali-brations, and miscellaneous maintenance activities. The number of emergent MWOs completed for the month is also shown. The percent of the number of completed scheduled maintenance activities as compared to the number of scheduled maintenance activities for the months of July, August, September and October 1994 are not available due to the software and data collection method changes involved with the implementation of the Integrated Plant Schedule. There were 55 emergent MWOs completed during the month of October. The 1994 Fort Calhoun monthly goal for completed scheduled maintenance activities is 80%. Data Source: Chase /Schmitz (Manager / Source) Accountability: Chase /Faulhaber Adverse Trend: None SEP 33 51

E % of Hours the in-Line Chemistry instruments are Inoperable 12- --O-1994 Fort Calhoun Goal ( 10%) l 11-l 10-C O O O O O O O O O O O l 9-l' 8-7- 6-E 5-4- Eh i I;;;I O i i i i i i i Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 IN-LINE CHEMISTRY INSTRUMENTS OUT-OF-SERVICE This indicator shows the percentage of hours the in-line chemistry system instruments l are inoperable for the reporting month. The chemistry systems involved in this indicator include the Secondary System and the Post Accident Sampling System (PASS). l At the end of October 1994 the percentage of hours the in-line chemistry system instru-l j ments were inoperable was 3.71%. 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 1994 Fort Calhoun monthly goal for this indicator is a maximum of 10% in-line chernistry instruments inoperable. 5 out-of-service chemistry instruments make up 10% of all the chemistry instruments that are counted for this indicator. Data Source: Chase /Reneaud (Manager / Source) Accountability: Chase /Jaworski Positive Trend 52 ---r-

Waste Produced Each Month (Kilograms) Monthly Average Waste Produced Dunng the Last 12 Months (Kilograms) -O-- Fort Calhoun Monthly Average Goal ( 100 kilograms) Federal & State Monthly Limit (Max. of 1,000 Kg) l 1000 - = = = = = = = = = = = = 800-3 l 600-E h 400-200-C O O O O- -C O O O O-0 i ~ ~, Nov93 Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct94 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. l During the month of October 1994,0.0 kilograms of non-halogenated hazardous waste was produced,398.7 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 560.1 kilograms. The monthly average for haz-ardous waste produced during the last 12 months is 46.67 kilograms. Hazardous waste is counted based upon a full drum of waste. The 1994 Fort Calhoun monthly average goal for hazardous waste produced during the last 12 months is a maximum of 100 kilograms. i Data Source: Chase / Smith (Manager / Source) Accountability: Chase / Smith Positive Trend 53 i

E Contaminated Radiation Controlled Area 15%- l GOOD l -O-Fort Calhoun Goal (nonautage months) -O-Fort Calhoun Goal (outage rnonths) 12%- C C C C C C C C C C C C 9%- 6%- 3%- 0% i i i i i i i i i Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 CONTAMINATED RADIATION CONTROLLED AREA This indicator shows the percentage of the RCA that is contaminated based on the total square footage. The 1994 monthly non-outage goalis a maximum of 10% contami-nated RCA and the monthly outage goal is a maximum of 13% contaminated RCA. At the end of October 1994, the percentage of the total square footage of the RCA that was contaminated was 9.4%. Data Source: Chase /Gundal(Manager / Source) Accountability: Chase /Lovett Positive Trend SEP54 54

Nurnber of identified PRWPs Year-To-Date IGOODI 30- --O-1994 Fort Calhoun Goal (<25). y g 25-C O O O O O O O O O O O e o f o3 ]15-F Oy10-m h o 5-1 I I i i l 4 4 4 1 4 i Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 t RADIOLOGICAL WORK PRACTICES PROGRAM i The Radiological Work Practices Progrsm Indicator shows the number of Poor Radio-logical Work Practices (PRWPs) whi'sn were identified during the reporting month. The number of PRWPs which are identified each month should indirectly provide a means to qualitatively assess si pervisor accountability for their workers' radiological performance. During the month of October 1994, there was 1 PRWP identified. The PRWP occurred when an individual exited the RCA and it was discovered that their ALNOR was turned off. There have been 7 PRWPs in 1994. The 1994 year-end goal for the number of PRWPs is a maximum of 25. j l Data Source: Chase /Little (Manager / Source) Accountability: Chase /Lovett Adverse Trend: None SEP52 55

O Documents scheduied for neview @ Docurnents Reviewed 5 Overdue Docurnents 350-300-250-200-7 150- / 100-2 Data 50 - g Unavailable ~ = 0 Nov93 Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct94 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. Document review information for October 1994 was not available for this report. During September 1994 there were 97 document reviews scheduled, while 162 docu-ment reviews were completed. At the end of the month, there ware no document re-i views more than 6 months overdue. There were 16 new documents iniGated in September. i Data Source: Chase / Keister (Manager / Source) Accountability: Chase /Jaworski Adverse Trend: None SEP 46 1-56

I E Non-System Failures lGOODI 16-14-12-10

o-8-

7 6-4 4 4 0 i i i i i i i i i i i Nov93 Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct94 60 - @ System Failures l GOOD l 50 - t y 40-32 30-26 15 h 16 17 20-17 '~ O i i i i i i i Nov93 Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct94 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/ reportable incidents concerning system failures which occurred during the reporting month. During the month of October 1994, there were 34 loggable/ reportable incidents identi-fied. System failures accounted for 30 (89%) of the loggable/ reportable incidents. 26 of the 30 system failures were environmental failures due to sun glare (19 failures) and poor weather conditions. Non-system failures included 2 lost / unattended security badges and 2 tailgating incidents by plant personnel. Through October 1994, system ) and non-system failures continued on a significant downward trend compared to 1993. Data Source: Sefick/Woerner (Manager / Source) Accountability: Sefick Adverse Trend: None SEP 58 ] 57

3 Temporary Modifications >1 cycle old (RFO required for Removal) O Temporary Modifications >6 months old (Removable on-line) -O-Fort Calhoun Goal for Temporary Modifications >1 cycle old --O-Fort Calhoun Goal for Temporary Modifications >6 months old 8-6 5 hh hh a w i hh a w i w July '94 August '94 September '94 October '94 TEMPORARY MODIFICATIONS This indicator provides information on the number of temporary modifications greater than one fuel cycle old requiring a refueling outage (RFO) for removal and the number of temporary modifications removable on-line that are greater than six months old. In addition, the 1994 Fort Calhoun monthly goals for this indicator are zero, however, specific temporary modifications have been approved by management to exceed these goals due to cost effectiveness considerations. These are listed below. There is currently 1 temporary modification that is greater than one fuel cycle old requir-ing a refueling outage to remove: Epoxy repairs to ST-48, which is awaiting completion of MWO 931325, scheduled start date 1995 Refueling Outage. This temporary modifi-cation was previously included in the on-line removable >6 months old classification, but was re-classified as an outage modification to save engineering resources from com-pleting 1 ECN to allow the epoxy repair to remain in place and a second ECN to remove it during the 1995 refueling outage. In addition, at the end of October 1994 there were 4 temporary modifications installed that were greater than six months old that can be removed on-line. These were: 1) Localindication for BAST CH-11 A and CH-118,in which Operations is reviewing a draft FLC. After review, Licensing is to issue an FLC, and the NRC is to approve; 2) Swap leads for DG-1 shutdown solenoid, which is awaiting completion of MWO 911809, scheduled for the next DG-1 outage; 3) Replace FP-156 with new design plug valve, which is awaiting the completion of MR-FC-92-019, scheduled for completion 12/94; and 4) Rubber patch on surface sluice line, wNch is awaiting completion of MWO 940774, re-scheduled for 1/23/95, after corps drops river level. Currently,1 temporary modification associated with the surface sluice line is over the goal of 6 months. The other 3 are exceptions to the goal as described in letter PED-STE-94-042. At the end of October 1994, there was a total of 26 TMs installed in the Fort Calhoun Station.16 of the 26 installed TMs require an outage for removal and 10 are removable on-line. In 1994 a total of 38 temporary modifications have been installed. Data Source: Jaworski/ Turner (Manager / Source) Accountability: Jaworski/Gorence Adverse Trend: None SEP 62 & 71 58

E Total Modification Packages Open 264 -O-Fort Calhoun Year-End Goal 250 e' i ~ 200 - 6 41 pg 150 - C ~ Y ~ Ry W@ 100-E# LI ? gg 50-W in k & % i di $9 ..j 0- "*T ~7 i i i i '91 '92 '93 Nov93 -oec Jan Feb Mar Apr May Jun Jul Aug sep Oct94 OUTSTANDING MODIFICATIONS This indicator shows the total number of outstanding modifications (excludino outstand-ino modifications which are orooosed to be cancelled). Categorv Reoortina Month Form FC-1133 Backlog /in Progress 2 Mod. Requests Being Reviewed 3 Design Engr. Backlog /In Progress 26 Construction Backlog /In Progress 16 Desian Engr. Uodate Backloc/in Proaress 6 Total - 53 At the end of October 1994,19 additional modification requests had been issued this year and 41 modification requests had been cancelled. The Nuclear Projects Review Committee (NPRC) had completed 128 backlog modification request reviews this year. The Nuclear Projects Committee (NPC) had completed 60 backlog modification request reviews this year. The 1994 year-end Fort Calhoun goal for this indicator is a maximum of 80 outstanding modifications. Data Source: Jaworski/ Turner (Manager / Source) Scofield/Lounsbery (Manager / Source) Accountability: Scofield/Phelps Adverse Trend: None 59

EAR 3 Requiring Engineering Closeout - Not in Closeout O DEN E SE 70-60-40-40-40-5 30-30-30-30-20- ,,,_, 20 - 20-20-10-10-10-10-i 7M go-- 7 T-1 0 ,0 ,0 Aug Sep Oct Aug Sep Oct Aug Sep Oct Aug Sep Oct 0-3 months 3-6 months 6-12 months >12 months October '94 Overdue EARS O Closeout (SE) O Engineering Response H P m i e i e i i i i Priority 0 Priority 1 Priority 2 Priority 3 Priority 4 Priority 5 Priority 6 O Priority 1 & 2 5 Priority 3 Total Open EARS 200 - 150 - 100 - 50- g g Q k ] 3 0 Nov93 Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct94 @ 66 EARS Resolved and in Closeout 0 71 Overdue Responses E 50 Overdue Closecuts O 104 EARS Requiring Response @ 49 EARS on Schedule 38.8% ' f 41.8 % 29.4 % lllIlllll 61.2 % r ENGINEERING ASSISTANCE REQUEST BREAKDOWN This indicator shows a breakdown of the number of EARS assigned to Design Engineer-ing and System Engineering. The 1994 year-end goal for this indicator is a maximum of 140 outstanding EARS. Total EAR breakdown is as follows: EARS opened during the month 7 l EARS closed during the month 10 Total EARS open as of the end of the month 170 Data Source: Skiles/Mikkelsen (Manager / Source) Accountability: Jaworski/Skiles Adverse Trend: None SEP 62 60

E in DEN - 138 E o-3 Months - 253 4.9% .7 O in System Engineering - 128 g I 5.3 0 3-6 Months - 116 i O in Procurement /Constr. - 154 .j \\27.5 % 22.9 % 0 >6 Months - 190 20.7 Q in Closeout - 139 ECN STATUS - OVERALL BACKLOG 5 ECNs Backlogged O ECNs Received During the Month j @ ECNs Completed During the Month E 0-3 Months - 64 .6.4N O 34 Months - 41 150-O >6 Months - 33 May94 Jun Jul Aug Sep Oct94 (Year-to-Date monthly average of ECNs received was 48.2) ECN STATUS DEN 250-200-g g o.3 Months - 43 150-33.6 100-l 53.1*4 C 3-6 Months - 17 O >6 Months - 68 May94 Jun Jul Aug Sep Oct94 ECN STATUS - SE 250-200-h E 0-3 Months - 71 39.W. 1 6.1 0 3-6 Months - 23 14.9 0 >6 Months - 60 I i I 6 I I May94 Jun Jul Aug Sep Oct94 ECN STATUS - PROC /CONSTR 250-00-0.8% E 0-3 Months - 75 1 E 54 0 34 Months - 35 O >6 Months - 29 0 May94 Jun Jul Aug Sep Oct94 ECN STATUS - CLOSEOUT ENGINEERING CH. JGE NOTICE STATUS Data Source: Skiles/Mikkelsen (Manager / Source) Accountability: Skiles/Jaworski Adverse Trend: None SEP 62 61

E FC Type = 189 E Priority 1 & 2 = 96 [ 21. 3. f 28.6% I @ SRIType = 249 @ Priority 3 & 4 = 303 .5% O DC Type = 121 'g.2%F O Priority 5 & 6 = 160 TOTAL OPEN ECNS BY TYPE (559 TOTAL) TOTAL OPEN ECNs BY PRIORITY (559 TOTAL) D DEN Engineering Not Complete @ System Engineering - Response, Confirmation Not Complete @ Maintenance / Construction / Procurement - Work Not CornpleY E DEN - Closcout or Drafting Not Complete 213 204 1m 25 200 189 20 M W 10f ? Y 150 - gg,gs 100- @ Priority 3 ( 7.g 50- 'x ~ O Priority 5 or G 6 0- -g May94 Jun Jul Aug Sep Oct94 Facility Change ECNs Open S or May94 Jun Jul Aug Sep Oct94 Substitute Replacement item ECNs Open 250 - 188 181 182 188 200 - 150-E Priority 1 or 2 l 100-gj 38 1 @ Priority 3 or 4 53 69.4 % 50 - 30 0--

f -

0 Prionty 5 or 6 A g q May94 J r. Jul Aug Sep Oct94 Document Change ECNs Open ENGINEERING CHANGE NOTICES OPEN Data Source: Skiles/Mikkelsen (Manager / Source) Accountability: Skiles/Jaworski Adverse Trend: None SEP 62 62

O Administrative Control Problem O Licensed Operator Error @ Other Personnel Error @ Maintenance Problem 3-E Design / Construction / installation / Fabrication Problem @ Equipment Failures 2-1- g g l ~ 5 l 5 E E 0 ~ i i i i i i i i i i i i Oct93 Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep94 LICENSEE EVENT REPORT (LER) ROOT CAUSE BREAKDOWN This indicator shows the LERs by event date broken down by Root Cause Code for each of the past twelve months from October 1,1993 through September 30,1994. To be consistent with the Preventable / Personnel Error LERs indicator, this indicator is reported by the LER event date, as opposed to the LER report date. l N 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 were no events in September 1994 that resulted in an LER. Data Source: Trausch/Cavanaugh (Manager / Source) Accountability: Chase Adverse Trend: None 63

l 1 0 Total Requalification Training Hours l O Simulator Training Hours O Non-Requalification Training Hours 50-E Number of Exam Failures 1 32 y 30 30-20-18 37 12 jj 1 7.

10. e l

10-5 m 5 7 f 1 3. 5 ./ 3 /, 3 3 3 /, 2 0 i i i i i i Cycle 93-7 Cycle 94-1 Cycle 94 2 Cycle 94-3 Cycle 94-4 Cycle 94 5 Cycle 94-6

Note 1: The Simulator was out-of-service during Cycle 94-4.
Note 2: Includes 8 hours of General Employee Training.

LICENSED OPERATOR REQUALIFICATION TRAINING This indicator provides information on the total number of hours of training given to each crew during each cycle. The Simulator training hours shown on the graph are a subset of the total training hours. Non-Requalification Training Hours are used for AOP/EOP verification & validation, INPO commitmen's, 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. Rotation 94-6 was the annual Requalification Examination rotation. There were 2 crew simulator failures and 1 written examination failure. The crews that failed the simulator evaluation were remediated without impacting the Operations Department shift sched-i l ule, as was the individual who failed his written examination. Data Source: Gasper /Guliani (Manager / Source) Accountability: Gasper /Guliani l l Adverse Trend: None SEP 68 64

G SRO Exams Administered O SriO Exams Passed E RO Exams Administered O RO Exams Passed 20-15-10- ~ i: ? i: 5-7 0 i i i i i Nov93 Doc Jan Feb Mtr Apr May Jun Jul Aug Sep Oct94 LICENSE CANDIDATE EXAMS This indicator shows the number of Senior Reactor Operator (SRO) and Reactor Opera-tor (RO) quizzes and excms taken and passed each month. These internally adminis-tered quizzes and exams are used to plot the SRO and RO candidates' monthly progress. In October 1994 there were 7 SRO exams administered and all of these exams were passed. In addition, there were 12 RO examinations administered, with 11 passing scores. Data Source: Gasper /Guliani(Manager / Source) Accountability: Gasper /Guliani Adverse Trend: None SEP 68 65

j l I E TotalOpen CARS 8 TotalOpenIRs D Open CARS > Six Months Old E Open irs > Six Months Old 400-400 360- -360 320-280- Re [ [ [ - 320 cyciets 280 240-240 200- -200 160-160 120-l 120 80- - 80 ) I [ 40 ~ ~ 4, 40-g y ,+ O 0 Nov93 Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct94 120-E Open Significant CARS O Open Significant irs 67 69 3 72 73 60-51 45 40-20-5 5 4 6 6 8 7 8 8 7 6 7 0 Nov93 Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct94 OPEN CORRECTIVE ACTION REPORTS AND INCIDENT REPORTS This indicator shows the total number of open Corrective Action Reports (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. At the end of October 1994 there were 62 open CARS.12 of these CARS were greater than 6 months old. There were 7 Open Significant CARS at the end of the month. Also, at the end of October there were 404 open irs. 228 of these irs were greater than 6 months old. There were 73 Open Significant irs at the end of the month. The 1994 monthly goal for the nurnber of CARS greater than 6 months old is less than 30. Data Source: Orr/Gurtis (Mr.aager/ Source) & CHAMPS Accountability: Andrews/Gambhir/ Gates Adverse Trend: Althr:sgh the number of irs has been increasing, an adverse trend is not indicated because the increase is a result of a revision to Standing Order R-4 that lowers the threshold for writing irs and requires completion of all corrective actions prior to closing irs. y

i -+- Engineering Hold -+- Planning Complete -O-Planning Hold -H - Ready Part Hold Tota! / 700 - 650 - 600 - , 550 - .g 500-E 450-( 3$~ -[ 300 - 250 - 200 - 1%- 100 - ~ k-50-I I I I I I I I I I I I I I I I Dec93Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan95 Feb Mar 95 MWO PLANNING STATUS (CYCLE 16 REFUELING OUTAGE) This indicator shows the total number of Maintenance Work Requests (MWRs) and Maintenance Work Orders (MWOs) that have been approved for inclusion in the Cycle 16 Refueling Outage. This graph indicates: Parts Holds (part hold removed when parts are staged and ready for use) Engineering Holds (Engineering hold removed when appropriate engineering paper-work or support is received for the p ackage) Planning Holds (Planning hold remo <ed when planning is completed to the point when package is ready or other support is necessary to continue the planning process) Planning Complete (status given when on?y items keeping the job from being ready to work are parts or engineering support) Ready (status when all planning, supporting documentation, and parts are ready to go) Data Source: Chase /Schmitz (Manager / Source) Accountability: Chase /Faulhaber Adverse Trend: None SEP 31 67

>O 'O "D H % Conplete $ > Q C) Q. 3e7 ho3 k C' b 70 c) A Ut c) N CD e 8 - e -- o o o o o o o o o o ,C m o=3 m I t t t i 1 I I i eao .-. 3 Q: D) C 7OOg 3 N si s sNN sNNNNNNNNNNNNNN's q O All ProI'ects M S' = 0 3 4 -(D e., h m

D

- O O. = - - D) m G CC 7 N N Steam Generator Services = 3 o o (n m F aE o mg m S g O Balance of Plant ECT o

n) oh N

C GO ^ oE O ~ o, m -c on - o N N.~N..N N N N N N N N N N N N N N N ' (D 73 - D) H (J

5-

s g --

to ErosiorVCorrosion O o ew- - H o. r c) 57o H c g c) O co sNNNNNNNNNNNNNNNNNNNNNNNNNNN w pgg ~ @ 5. 5 Snubber Testing l r g e e o e e as a 0 e es- 'u = =m sNNNNNNN w xNNN w sNNx [ OO o g ah h ISI Exams I-pdd a g 'Ur ni m ,e, ga2 S, 8 3 ^ a s weyo s % c% o s s s s s s s s s s s s s s u g 5 dk .E oB 23 System Pressure Tests W T :f. ?^ T: A ' ' " ~ ' ^h ' ".1 o-m E m 33 m 'U--- 9 C g g sxxxxsxxxxxsssssss 8 8 h g,* g Relief Valve Testing M: ?^ ~ ': 9 9 g ag z e '< o O ~ "O 1 ye O N'NNNNNNN'NNN'Ny NNNx 0 i Check Valves W%N < W:3-W - x 3 ) o C o W H ~ 7 y F3 m o ss ssNNsssssssssssssssss, p 8$ m Motor Operated Valves (MOVs) 'U

o. U-ob <D 3

l s.N NNN NNNNNNNNNN N s N N N] l a

m Boric Acid Inspection
==c ~'- *N*eM i

i

i 1995 OUTAGE MODIFICATIONS { Baseline Schedule for PRC Approval Projected / Actual Schedule for PRC Approval l 20-Final Design Package issued l Total Modification Packages (18) (4 added after 1/14/94)

15-8Q ll'llllllllllll'llllllllllll'll':,'

'll': lll S. RQ e, gR10- .g b s E$ E I 5-8 t a a O e A o ~ 1 i 0 6 6 E E 6 6 M M R 8 u 8 m E = = m 8 5 n m o i PROGRESS OF CYCLE 16 OUTAGE MODIFICATION PLANNING (FROZEN SCOPE OF 13 MODIFICATIONS) This indicator shows the status of modifications approved for installation during the Cycle 16 Refueling Outage. The data is represented with respect to the baseline schedule (established 1/14/94) and the current schedule. This information is taken from the Modification Variation Report produced by the Design Enginee ing group. l In October 1994 no modifications were deleted and none were added. { j The goal for this indicator is to have all modification packages identified prior to 1/14/94 and PRC approved by October 15,1994. 4 modifications added after 1/14/94 are not included in this performance indicator. The 4 modifications are scheduled and will not impact the 1995 outage. This performance goal was achieved on 9/12/94. Data Source: Skiles/Ronne (Manager / Source) Accountability: Phelps/Skiles Adverse Trend: None SEP 31 l 69 ) l I

1994 ON-LINE MODIFICATIONS l --+- Baseline Schedule for PRC Approval Projected / Actual Schedule for PRC Approval Final Design Package issued (7 FD DCPs issued prior to 1/14/94) g20-l Total Modification Packages (17) (2 are Close Out Only) (1 Added after 1/14/94) g ;:: a 2 \\ l .$.g 15- ,a .............................,f h}8 E 10 m y yk- _ _ _ _ _ _ _ _ z../ [3 SE 8 g i 5-g E h e ilc. 0 g h h h h k h h h l s s s + a a n s a s s PROGRESS OF 1994 ON-LINE MODIFICATION PLANNING (FROZEN SCOPE OF 14 MODIFICATIONS) This indicator shows Ine status of modifications approved for on line installation during 1994. The data is represented with respect to the baseline schedule (established 1/14/ l

94) and the current schedule. This information is taken from the Modification Variance i

Report produced by the Design Engineering Nuclear group. In October 1994 no modifications were deleted and none were added. The goal for this indicator is to have all modification packages identified prior to 1/14/94 and PRC approved by August 15,1994.1 modification was added after 1/14/94 and is not included in this performance indicator The modification is scheduled and will not j impact 1994 on-line construction. All packages, except 1, met the goal of PRC approval by 8/15/94. The package which did not meet the goal was ready for PRC review on 8/11/94. However, unavoidable l changes to the package were required, and final PRC approval was completed on 8/29/ 94. Data Source: Skiles/Ronne (Manager / Source) Accountability: Phelps/Skiles Adverse Trend: None 70

ACTION PLANS D 9 l I 71

ACTION PLANS This section lists action plans that have been developed for the performance indicators cited as Adverse Trends during the month preceding this report. Also included are n Action Plans forindicators that have been cited in the preceding month's report as Needing increased Management Attention for 3 consecutive months. In accordance with Revision 3 of NOD-OP-37, the fo!!owing performance indicators would require action plans based on 3 consecutive months of performance cited as "Needing Increased Management Attention": Unplanned Automatic Reactor Scrams Per 7,000 Critical Hours Unplanned Safety System Actuations (INPO and NRC) The Plant Manager and Station Engineering Manager have reviewed the daily and ongoing actions being taken to return these performance indicators to meeting the goals. This review indicates appropriate action is being taken and no explicit action plan is required. The action plan for Fuel Reliability Indicator (page 14) follows:

1) The prediction that there is a potental for 1 or 2 defective fuel rods in the core is based on a change in the Xe-133 to I-131 ratio. The power reduction in late October was unable to provide any conclusive data.

2) A specification will be prepared for Ultrasonic Testing / Fuel Sipping during the next refueling outage.

The action plan for Violations Per 1,000 Inspection Hours (page 18) follows:

1) The number of inspections (and thus exposure to potential violations) currently scheduled for the remainder of the year is much less than the first half of 1994 (SALP period ended 7/31/94). Only the SWOPl and Resident inspections are currently scheduled.

2) Pursuit of Resident inspector concems/ problems / issues will be thorough to preclude them from becoming violations.

3) Preparation for scheduled inspections (e.g. SWOPI) will be thorough and comprehensive.

72

ACTION PLANS (continued) The action plan for Thermal Performance (page 32) follows: Actions to improve Thermal Performance are:

1) Backwash durations have been lengthened over the weekends to improve condenser performance.

2) Investigate the possibility of FW flow nozzle fouling. Test equipme,$

should be installed by the end of September.

3) Investigate the effects of adding Ethanolamine to secondary chemistry to clean system and possibly reduce S/G blowdown.

l 73

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-caloperation 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 critical hours for the reporting period rr, ?- the current year. The basis for the budget curve is the plied by the number of trains in the auxiliary feedwa+ approved 1993 budget. The basis for the actual curve is system. the Financial and Operating Report. CHECK VALVE FAILURE RATE CLEAN CONTROLLED AREA CONTAMINATIONS Compares the Fort Calhoun ched valve failure rate to 21,000 DISINTEGRATIONS / MINUTE PER PROBE the industry check valve failure rate (failures per 1 million AREA component hours). The data for the industry failure rate The personnel contamination events in the clean con-is three months behind the PI Report reporting month, trolled area. This indicator tracks personnel perfor-This indicator tracks performance for SEP #43. mance for SEP #15 & 54. COLLECTIVE RADIATION EXPOSURE CONTAMINATED RADIATION CONTROLLED AREA Collective radiation exposure is the total external whole-The percentage of the Radiation Controlled Area, which body dose received by all on site personnel (including includes the auxiliary building, the radwaste building, and mntractors and visrtors) during a time period, as mea-areas of the C/RP building, that is contaminated based sured by the thermoluminescent dosimeter (TLD). Col-on the total square footage. This indicator trads perfor-lective radiation exposure is reported in units of person-mance for SEP # 54. rom. This indicator tracks radiological work performance for SEP #54. DAILY THERMAL OUTPUT This indicator shows the daily core thermal output as COMPONENT FAILURE ANALYSIS REPORT (CFAR) measured from computer point XC105 (in thermal mega-

SUMMARY

watts). The 1500 MW Tech Spec limit, and the unmet The nurnber of INPO categories for Fort Calhoun Station portion of the 1495 MW FCS daily goal for the reporting with significantly higher (1.645 standard deviations) fail-month are also shown, ute rates than the rest of the industry for an eighteen month time parod. Fadures are reported as component DIESEL GENERATOR RELIABILITY (25 DEMANDS) (i.e. pumps, motors, valves, etc.) and application (i.e. This indicator shows the number of failures occurring for charging pumps, main steam stop valves, mntrol ele-each emergency diesel generator during the last 25 start ment drive motors, etc ) categories. demands and the last 25 load-run demands. Failure Cause Categones are: Wear Out/ Aging - a f ailure ttought to be the conse-DISABLING INJURY /lLLNESS FREQUENCY RATE quence of expected wear or aging. (LOST TIME ACCIDENT RATE) Manufacturing Defect - a fadure attributable to inad-This indicator is defined as the number of axidents for equate assembly or insttal qualrty of the responsible com-all utility personnel permanently assigned to the station, ponent or system. involving days away from work per 200,000 man-hours EngineerinWDesign a f adure attributable to the inad-worked (100 man-years). This does not include contrac-equate design of the responsbie component or system. tor personnel. This indicator trads personnel perfor-Other Devices a f adore attrbutable to a failure or mance for SEP #25 & 26. misoperation of another component or system, including associated devees. DOCUMENT REVIEW (BIENNIAL) Maintenanca/ Testing a f adure that is a result of im-The Document Review Indicator shows the number of proper maintenance or testing, lack of maintenance, or documents reviewed, the number of documents sched-personnel errors that occur during maintenance or test-uled for review, and the number of document reviews ing activities performed on the responsible component or that are overdue for the reporting month. A document system, including ladure to fonow procedures. review is considered overdue if the review is not com-Errors - failures attrbutable to inwrrect procedures that plete within 6 months of the assigned due date. This were followed as wntten, improper installation of equip-indicator tracks performance for SEP #46. ment, and personnel errors (including failure to follow procedures property) Also included in this category are EMERGENCY AC POWER SYSTEM SAFETY SYSTEM failures for which the cause is unknown or cannet be as-PERFORMANCE signed to any of the preceding categories. The sum of the known (planned and unplanned) unavail-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. 74

PERFORMANCE INDICATOR DEFINITIONS EMERGENCY DIESEL GENERATOR UNIT RELIABIL-EMERGENCY DIESEL GENERATOR UNRELIABILITY ITY This indicator measures the total unreliability of emer. This indicator rhows 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 sol generator demands at the Fort Calhoun Station. Also the number of valid demands. Total unreliability is a shown are trigger values which correlate to a high level combination of start unreliabi!ty 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 failures are less than the trigger values. ENGINEERING ASSISTANCE REQUEST (EAR)

1) Number of Start Demands: All valid and inadvertent BREAKDOWN start demands, including all startonly 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) STATUS gency generator system that prevents the generator from The number of ECNs that were opened, ECNs that were achieving specified frequency and voltage is classified as completed, and open backlog ECNs awaiting completion a valid start failure. This includes any condition identified by DEN for the reporting month. This indicator tracks in the course of maintenance inspections (with the emer-performance for SEP #62. gency generator in standby mode) that definitely would have resulted in a start failure if a demand had occurred. ENGINEERING CHANGE NOTICES OPEN

3) Number of Load Run Demands: For a valid load-run This indicator breaks down the number of Engineering demand to be counted the load-run attempt must meet Change Notices (ECNs) that are assigned to Design one or more of the following criteria:

Engineering Nuclear (DEN), System Engineering, and A) A load-run of any duration that results from a real au-Maintenance. The graphs provide data on ECN Facihty tomatic or manualinitiation. Changes open, ECN Substitute Replacement Parts B) A load run test to satisfy the plant's load and duration open, and ECN Document Changes open. This indicator as stated in each test's specifications. tracks performance for SEP #62. C) Other special tests in which the emergency generator is expected to be operated for at least one hour while EQUIPMENT FORCED OUTAGES PER 1,000 CRITI-loaded with at least 50% of its design load. CAL HOURS

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

(1,000 hours) divided by the number of forced outages

5) Exceptions: Unsuccessful attempts to start or load-run caused by equipment failures in that period.

should not be counted as valid demands or failures when they can be attributed to any of the folicwing: EQUIVALENT AVAILABILITY FACTOR A) Spurious trips that would be bypassed in the event of This indicator is defined as the ratio of gross available an emergency. generation to gross maximum generation, expressed as B) Malfunction of equipment that is not required during a percentage. Available generation is the energy that an emergency. can be produced if the unit is operated at the maximum C) Intentionaltermination of a test because of abnormal power level permitted by equipment and regulatory limi-conditons that would not have resulted in major diesel tations. Maximum generation is the energy that can be generator damage or repair. produced by a unit in a given period if operated continu-D) Malfunctions or operating errors which would have not ously at maximum capacity, prevented the emergency generator from being restarted and brought to load within a f ew minutes. FORCED OUTAGE RATE E) A failure to start because a portion of the starting sys-This indicator is defined as the percentage of time that tem was disabled for test purpose, if followed by a suc-the unit was unavailable due to forced events compared cessful start with the starting system in its normal abgn-to the time planned for electrical generation. Forced m ent. events are failures or other unplanned conditions that Each emergency generator failure that results in the gen-require removing the unit from service before the end of l erator being declared inoperable should be counted as the next weekend. Forced events include start-up fail-I one demand and one failure. Exploratory tests during ures and events initiated while the unit is in reserve shut-corrective maintenance and the successful test that fol-down (i.e., the unit is available but not in service). lows repair to venfy operability should not be counted as demands or f ailures when the EDG has not been de-clared operable again. 75

PERFORMANCE INDICATOR DEFINITIONS = FUEL REUABluTYINDICATOR UCENSE CANDIDATE EXAMS This indicator is defined as the steady-state primary cool-This indicator shows the number of SRO and/or RO quiz-ant 1-131 activity, corrected for the tramp uranium contri-zes and exams that are administered and passed each bution and normalized to a common purification rate. month. This indicator tracks training performance for Tramp uranium is fuel which has been deposited on re-SEP #68. actor core internals from previous defective fuel or is present on the surface of fuel elements from the manu-UCENSED OPERATOR REQUAUFICATION TRAIN-facturing process. Steady state is defined as continuous ING operation for at least three days at a power level that The total number of hours of training given to each crew does not vary more than + or - 5%. Plants should collect during each cycle. Also provided are the simulator train-data for this indicator at a power level above 85%, when ing hours (which are a subset of the total training hours), possible. Plants that did not oporate at steady-state the number of non-requahfication training hours and the power above 85% should collect data for this indicator at number of exam f ailures. This indicator tracks training the highest steady-state power level attained during the performance for SEP #68. month. The density mrrection fador is the ratio of the specific UCENSEE EVENT REPORT (LER) ROOT CAUSE volume of coolant at the RCS operating temperature BREAKDOWN (540 degrees F., Vf = 0.02146) divided by the specific This indicator shows the number and root cause code for volume of coolant at normalletdown temperature (120 Licensee Event Reports. The root cause codes are as degrees F at outlet of the letdown cooling heat ex. follows: changer. Vf 0.016204), which results in a density cor-

1) Administrative Control Problem - Management and rection factor for FCS equal to 1.32.

supervisory deficiencies that affect plant programs or activities (i.e., poor planning, breakdown or lack of ad-GROSS HEAT RATE equate management or supervisory control, incorrect Gross heat rate is defined as the ratio of total thermal procedures, etc.) energy in British Thermal Units (BTU) produced by the

2) Licensed Operator Error - This cause code captures reactor to the total gross electrical energy produced by errors of omission / commission by licensed reactor opera-the generator in kilowatt-hours (KWH).

tors during plant activities.

3) Other Personnel Error - Errors of omission /commis-HAZARDOUS WASTE PRODUCED sion committed by non-licensed personnelinvolved in The total amount (in Kilograms) of non-halogenated haz-plant activities.

ardous waste, halogenated hazardous waste, and other

4) Maintenance Problem - The intent of this cause hazardous waste produced by FCS each month.

code is to capture the full range of problems which can be attributed in any way to programmatic deficiencies in HIGH PRESSURE SAFETY INJEC110N SYSTEM the maintenance functionalorganization. Activities in-SAFETY SYSTEM PERFORMANCE cluded in this category are maintenance, testing, surveil-The sum of the known (planned and unplanned) unavail-lance, calibration and radiation protection. able hours and the estimated unavailable hours for the

5) DesigrVConstruction/ Installation /Fabtation Problem high pressure safety injection system for the reporting

- This cause mde covers a full range of programmatic period divided by the critical hours for the reporting pe-deficiencies in the areas of design, mnstruction, installa-riod multiplied by the number of trains in the high pres-tion, and f abrication (i.e., loss of control power due to sure safety injection system. underrated fuse, equipment not qualified for the environ-ment, etc.). INDUSTRIAL SAFETY ACCIDENT RATE-INPO

6) Equipment Failures (Electronic Piece-Parts or Envi-This indicator is defined as the number of accidents per ronmental-Related Failures) This code is used for spuri-200,000 man-hours worked for all utility personnel per-ous failures of electronic piece-parts and f ailurer due to manently assigned to the station that result in any of the rneteorological conditions such as lightning, ice, high following: 1) one or more days of restricted work (ex-winds, etc. Generally, it includes spurious or one-time ciuding the day of the accident); 2) one or more days failures. Electric components included in this category away from work (excluding the day of the accident); and are circuit cards, rectifiers, bistables, fuses, capacitors,

3) fatalities. Contractor personnel are not included for diodes, resistors, etc.

this indicator. LOGGAB LE/ REPORTABLE INCIDENTS (SECURITY) IN-UNE CHEMISTRY INSTRUMENTS OUT OF SER-The total number of security incidents for the reporting VICE month depicted in two graphs. This indicator tracks so-Total number of in-line chemistry instruments that are curity performance for SEP #58, out-of-service in the Secondary System and the Post Accident Sampling System (PASS). MAINTENANCE OVERTIME The % of overtime hours compared to norn,al hours for maintenance. This includes OPPD personnel as well as contract personnel. 76 l

PERFORMANCE INDICATOR DEFINITIONS MAINTENANCE WORKLOAD BACKLOGS NUMBER OF CONTROL ROOM EOUiPMENT DEFI-This indicator shows the backlog of non-outage Mainte-CIENCIES nance Work Orders remaining open at the end of the A mntrol room equipment deficiency (CRD) is defined as reporting month. Maintenance classifications are de-any component which is operated or controlled from the fined as: Control Room, provides indication or alarm to the Control Room, provides testing capabihties from the Control Corrective Repair and restoration of equipment or mm-Room, provides automatic actions from or to the Control ponents that have failed or are malfunctioning and are Room, or provides a passive function for the Control not performing their intended function. Room and has been identified as deficient, i.e., does not perform under all conditions as designed. This definition ~ Preventive - Actions taken to maintain a piece of equip-also applies to the Alternate Shutdown Panels Al-179, ment within design operating conditions, prevent equip. Al-185, and Al-212. ment failure, and extend its life and are performed prior A plant component which is deficient or inoperable is to equipment failure. considered an " Operator Work Around (OWA) ltem* if some other action is required by an operator to compen-Non-Corrective / Plant improvements - Maintenance ac-sate forthe condition of the component. Some examples tivities performed to implement station improvements or cf OWAs are: 1) The control room level indicator does to repair non-plant equipment. not work but a local sightglass can be read by an Opera-tot out in the plant; 2) A deficient pump cannot be re-Maintenance Work Priorities are defined as: paired because replacement parts require a long lead l time for purchase / delivery, thus requiring the redundant Emergency - Conditions which significantly degrade sta-pump to be operated continuously; 3) Special actions tion safety or availabikty, are required by an Operator because of equipment de-sign problems. These actions may be described in Op-Immediate Action - Equipment deficiencies which signifi-erations Memorandums, Operator Notes, or may require cantly degrade station reliability. Potential for unit shut-changes to Operating Procedures. 4) Deficient plant down or power reduction. equipment that is required to be used during Emergency Operating Procedures or Abnormal Operating Proce-Operations Concern Equipment deficiencies which dures. 5) System indication that provides critcal infor-hinder station operation, mation during normal or abnormal operations. Essential Routine corrective maintenance on essential NUMBER OF MISSED SURVE1LLANCE TESTS RE-station systems and equipment. SULT1NG IN LICENSEE EVENT REPORTS The number of Surveillance Tests (STs) that result in Non Essential Routine corrective maintenance on non-Licensee Event Reports (LERs) during the reporting essential station systems and equipment. month. This indicator tracks missed STs for SEP #60 & 61. Plant improvement - Non-corrective maintenance and plant improvements. OPEN CORRECTIVE ACTION REPORTS & INCIDENT REPORTS This indicator tracks maintenance performance for SEP This indicator displays the total number of open Correc-

36.

tive Action Reports (CARS), the number of CARS that are { older than six months and the number of open significant I l MAXIMUM INDIVIDUAL RADIATION EXPOSURE CARS. Also displayed are the number of open incident ) l The total maximum amount of radiation received by an Reports (irs), the number of irs that are greater than six ] individual person working at FCS on a monthly, quarterly, months old and the number of open significant irs. ] and annual basis. j OUTSTANDING MODIFICATIONS MWO PLANNING STATUS (CYCLE 16 REFUELING The number of Modification Requests (MRs) in any state OUTAGE) between the issuance of a Modification Number and the The total number of Maintenance Work Orders that have completion of the drawing update. I been approved for inclusion in the Cycle 15 Refueling

1) Form FC-1133 Backlog /in Progress. This number rep-i Outage and the number that are ready to work (parts resents modification requests that have not been plant staged, planning complete, and all other paperwork approved during the reporting month.

ready for field use). Also included is the number of

2) Modification Requests Being Reviewed. This category MWOs that have engineering holds (ECNs, procedures includes:

and other miscellaneous engineering holds), parts hold, A.) Modification Requests that are not yet reviewed. (parts staged, not yet inspected, parts not yet arrived) 8.) Modification Requests being reviewed by the Nuclear and planning hold (job scope not yet completed). Main. Projects Review Committee (NPRC). tenance Work Requests (MWRs) are also shown that C.) Modification Requests being reviewed by the Nuclear have been identified for the Cycle 15 Refueling Outage Projects Committee (NPC) and have not yet been mnverted to MWOs. These Modification Requests may be reviewed several times before they are approved for accomplishment or 77

PEFIFORMANCE INDICATOR DEFINITIONS = cancelled. Some of these Modification Requests are years of the ' Event Date" specified in the LER (e.g., an retumed to Engineering for more information, some ap-event for which the cause is attributed to a problem with proved for evaluation, some approved for study, and the original design of the plant would not be considered some approved for planning. Once planning is com-preventable). pleted and the scope of the work is clearly defined, these For purposes of LER event classification, a " Personnel Moddication Requests may be approved for accomplish-Error" LER is defined as follows: An event for which the ment with a year assigned for construction or they may root cause is inappropriate action on the part of one or be cancelled. All of these drfferent phases roquire re-more individuals (as opposed to being attributed to a de-

view, partment or a general group). Also, the inappropriate

3) Design Engineering Backlog /In Progress. Nuclear action must have occurred within approximately two Planning has assigned a year in which construction will years of the " Event Date" specified in the LER.

be completed and design work may be in progress. Additionally, each event classified as a " Personnel Error"

4) Construction Backlog /In Progress. The Construction should also be classified as ' Preventable." This irdicator Package has been issued or construction has begun but trends personnel performance for SEP ltem #15.

the modification has not been accepted by the System Acceptance Committee (SAC). PRIMARY SYSTEM CHEMISTRY % OF HOURS OUT

5) Design Engineering Update Backlog /in Progress. PED OF UMIT has received the Modification Completion Report but the The % of hours out of limit are for six primary chemistry drawings have not been updated.

parameters divided by the total number of hours possible ~ The above mentioned outstanding modifications do not for the month. The key parameters used are: Lithium, include modifications which are proposed for cancella-Chbride, Hydrogen, Dissolved Oxygen, Fluoride and tion. Suspended Solids. EPRIlimits are used. OVERALL PROJECT STATUS (REFUEUNG OUTAGE) PROCEDURAL NONCOMPLIANCE INCIDENTS This indicator shows the status of the projects which are (MAINTENANCE) in the scope of the Refueling Outage. The number of identified incidents concerning mainte-nance procedural problems, the number of closed irs PERCENTAGE OF TOTAL MWOs COMPLETED PER related to the use of procedures (includes the number of MONTH IDENTIFIED AS REWORK closed irs caused by procedural noncompliance), and The percentage of total MWOs completed per month the number of closed procedural noncompliance irs. identrfied as rework. Rework activities are identified by This indicator trends personnel performance for SEP maintenance planning and craft. Rework is: Any main-

15,41 & 44.

tenance work repeated to mrrect a deficiency which has re-ocx:urred within 60 days following similar work adivi-PROGRESS OF CYCLE 16 OUTAGE MODIFICATION ties. Any additional work required to correct deficiencies PLANNING (FROZEN SCOPE OF 15 MODIFICA-discovered during a fal led Post Maintenance Test to en-TIONS) sure the component / system passes subsequent Post This indicator shows the status of modifications ap-Maintenance Tests. This definition can be found in S. O. proved for completion during the Refueling Outage. M-101. PROGRESS OF 1994 ON-LINE MODIFICAT10N PLAN-PERCENT OF COMPLETED SCHEDULED MAINTE-NING (FROZEN SCOPE OF 14 MODIFICATIONS) NANCE ACTIVITIES This indicator shows the status of modifications ap-The % of the number of completed maintenance activi-proved for completion during 1994. ties as compared to the number of scheduled mainte-nance activities each month. This % is shown for all RADIOLOGICAL WORK PRACTICES PROGRAM maintenance crafts. Also shown are the number of The number of identified poor radiological work practices emergent MWOs. Maintenance adivities include MWRs, (PRWPs) for the reporting month. This indicator tracks MWOs, STs, PMOs, calibrations, and other miscella-radiological work performance for SEP #52. neous activities. This indicator tracks Maintenance per-formance for SEP #33. RATIO OF PREVENTIVE TO TOTAL MAINTENANCE & PREVENTIVE MAINTENANCE ITEMS OVERDUE PREVENTABLE / PERSONNEL ERROR LERs The ratio of preventive maintenance (including surveil-This indicator is a breakdown of LERs. For purposes of lance testing and calibration procedures) to the sum of LER event c'assification, a preventable LER is defined non-outage corrective maintenance and preventive main-as: An event for which the root cause is personnel error tenance completed over the reporting period. The ratio, (i.e., inappropriate action by one or more individuals), expressed as a percentage, is calculated based on man-inadequate administrative controls, a design /construc-hours. Also displayed are the % of preventive mainte-tion / installation /f abrication problem (involving work com-nance items in the month that were not mmpleted or ad-plated by or supervised by OPPD personnel) or a main-ministratively closed by the scheduled date plus a grace tenance problem (attributed to inadequate or improper period equal to 25 % of the scheduled interval. This indi-upkeep / repair of plant equipment). Also, the cause of cator tracks preventive maintenance activities for SEP the event must have occurred within approximately two

41.

78

PERFORMANCE INDICATOR DEFINITIONS RECORDABLE INJURY /lLLNESS CASES FRE-SIGNIFICANT EVENTS QUENCY RATE Significant events are those events identified by NRC The number of injuries requiring more than normal first staff through detailed screening and evaluation of operat-aid per 200,000 man-hours worked. This indicator ing experience. The screening process includes the trends personnel periormance for SEP #15,25 & 26. daily review and discussion of all reported operating re-actor events, as well as other operational data such as REPEAT FAILURES special tests or construction activities. An event identi-The number of Nuclear Plant Reliability Dats System fied from the screening process as a significant event (NPRDS) mmponents with more than 1 failure and the candidate is further evaluated to determine if any actual number of NPRDS components with more than 2 f ailures or potential threat to the health and safety of the public for the eighteen month CFAR period. was involved. Specific examples of the type of criteria ^ are summarized as follows: 1) Degradation of important SAFETY SYSTEM FAILURES safety equipment; 2) Unexpected plant response to a Safety system failures are any events or conditions that transient; 3) Degradation of fuel integrity, primary cool-could prevent the fulfillment of the safety fundions of ant pressure boundary, important associated f eatures; structures or systems. If a system consists of multiple

4) Scram with complication; 5) Unplanned release of redundant subsystems or trains, failure of all trains con-radioactivity; 6) Operation outside the limits of the Tech-statutes a safety system failure. Failure of one of two or nical Specifications; 7) Other.

more trains is not counted as a safety system f ailure. INPO significant events reported in this indicator are The definition for the indicator parallels NRC reporting SERs (Significant Event Reports) which inform utilities of requirements in 10 CFR 50.72 and 10 CFR 50.73. The significant events and lessons learned identified through following is a list of the major safety systems, sub-the SEE-IN screening process. systems, and components monitored for this indicator: Accident Monitoring Instrumentation, Auxiliary (and SPARE PARTS INVENTORY VALUE Emergency) Feedwater System, Combustible Gas Con-The dollar value of the spare parts inventory value for trol, Component Cooling Water System, Containment FCS during the reporting period. and Containment isolation, Containment Coolant Sys-tems, Control Room Emergency Ventilation System, STAFFING LEVEL Emergency Core Cooling Systems, Engineered Safety The actual staffing level and the authorized staffing level Features Instrumentation, Essential Compressed Air for the Nuclear Operations Division, the Production Engi-Systems, Essential or Emergency Service Water, Fire neering Division, and the Nuclear Services Division. This Detection or Suppression Systems, Isolation Condenser, indicator tracks performance for SEP #24. Low Temperature Overpressure Protection, Main Steam Line isolation Valves, Onsite Emergency AC & DC STATION NET GENERATION Power w/ Distribution, Radiation Monitoring instrumenta-The not generation (sum) produced by the FCS during tion, Reactor Coolant System, Reactor Core Isolation the reporting month. Cooling System, Reactor Trip System and instrumenta-tion, Recirculation Pump Trip Actuation Instrumentation, TEMPORARY MODIFICATIONS Residual Heat Removal Systems, Safety Valves, Spent The number of temporary mechanical and electrical con-Fuel Systems, Standby Liquid Control System and Ulti-figurations to the plant's systems. mate Heat Sink.

1) Temporary configurations are defined as electrical jumpers, electrical blocks, mechanical jumpers, or me-SECONDARY SYSTEM CHEMISTRY PERFORMANCE chanical blocks which are installed in the plant operating INDEX systems and are not shown on the latest revision of the The Chemistry Performance index (CPI) is a calculation PalD, schematic, connection, wiring, or flow diagrams, based on the concentration of key impurities in the sec-

2) Jumpers and blocks which are installed for Surveil-ondary side of the plant. These key impurities are the lance Tests, Maintenance Procedures, Calibration Pro-most likely cause of deterioration of the steam genera-cedures, Special Procedures, or Operating Procedures tors. Criteria for calculating the CPI are: 1) The plant is are not considered as temporary modifications unless the at greater than 30 percent power; and 2) The power is jumper or block remains in place after the test or proce-changing less than 5% per day. The CPI is calculated dure is complete. Jumpers and blocks installed in test or using the following equation: CPI. (sodium /0.90) +

lab instruments are not considered as temporary modifi-(Chloride /1.70) + (Sulf ate /1.90) + (Iron /4.40) + (Copper / cations. 0.30)/5. Where: Sodium, sulf ate and chloride are the

3) Scaffolding is not considered a temporary modifica-monthly average blowdown concentrations in ppb, iron tion. Jumpers and blocks which are installed and for and mpper are monthly time weighted average which MRs have been submitted will be considered as l

feedwater concentrations in ppb. The denominator for temporary modifications until final resolution of the MR l each of the 5 f actors is the INPO median value. If the and the jumper or block is removed or is permanently l monthly average for a specific parameter is less than the recorded on the drawings. This indicator tracks tempo-INPO median value, the median value is used in the cal-rary modifications for SEP #62 & 71. culation. l l 79

PERFORMANCE INDICATOR DEFINITIONS THERMAL PERFORMANCE UNPLANNED SAFETY SYSTEM ACTUATIONS -(INPO The ratio of the design gross heat rate (corrected) to the DEFINITION) adjusted actual gross heat rate, expressed as a percent-This indicator is defined as the sum of the following safety system actuations:

age,

1) The number of unplanned Emergency Core Cooling l

UNIT CAPABILITY FACTOR System (ECCS) actuations that result from reaching an The ratio of the available energy generation over a given ECCS actuation setpoint or from a spurious / inadvertent time period to the reference energy generation (the en-ECCS signal. ergy that could be produced if the unit were operated

2) The number of unplanned emergency AC power system continuously at full power under reference ambient con-actuations that result from a loss of power to a safeguards ditions) over the same time period, expressed as a per-bus. An unplanned safety system actuation occurs when an actuation setpoint for a safety system is reached or centage.

when a spurious or inadvertent signal is generated (ECCS UNIT CAPACITY FACTOR only), and major equipment in the system is actuated. The not electrical energy generated (MWH) divided by Unplanned means that the system actuation was not part the product of maximum dependable capacity (not MWe) of a planned test or evolution. The ECCS actuations to be times the gross hours in the reporting period expressed counted are actuations of the high pressure injection sys-as a percent. Het electrical energy generated is the tem, the low pressure injection system, or the safety injec-gross electricaloutput of the unit measured at the output tion tanks. terminals of the turbine generator minus the normal sta-tion service loads during the gross hours of the reporting UNPLANNED SAFETY SYSTEM ACTUATIONS(NRC period, expressed in megawatt hours. DEFINITION) The number of safety system actuations which include UNPLANNED AUTOMATIC REACTOR SCRAMS PER (Q&) the High Pressure Safety injoction System, the Low 7,000 CRITICAL HOURS Pressure Saf ety injection System, the Safety injection This indicator is defined as the number of unplanned au-Tanks, and the Emergency Diesel Generators. The NRC tomatic scrams (reactor protection system logic actua-classification of saf ety system actuations includes actua-tions) that occur per 7,000 hours of critical operation. tions when major equipment is operated gad when the The value for this indicator is calculated by multiplying logic systems for the above safety systems are chal-the total number of unplanned automatic reactor scrams lenged. in a specific time period by 7,000 hours, then dividing that number by the total number of hours critical in the VIOLATIONS PER 1,000 INSPECTION HOURS same time period. The indicator is further defined as This indicator is defined as the number of violations sited follows: in NRC inspection reports for FCS per 1,000 NRC inspec-

1) Unplanned means that the scram was not an antici-tion hours. The violations are reported in the year that the pated part of a planned test.

inspection was actually performed and not based on when

2) Scram means the automatic shutdown of the reactor the inspection report is received. The hours reported for by a rapid insertion of negative reactivity (e.g., by control each inspection report are used as the inspection hours.

rods, liquid injection system, etc.) that is caused by ac-tuation of the reactor protection system. The scram sig-VOLUME OF LOW-LEVEL SOLID RADIOACTIVE nal may have resulted f rom exceeding a setpoint or may WASTE have been spurious. This indicator is defined as the volume of low-level solid

3) Automatic means that the initial signal that caused radioactive waste actually shipped for burial. This indica-actuation of the reactor protection system logic was pro-tor also shows the volume of low-level radioactive waste vided from one of the sensors monitoring plant param-which is in temporary storage, the amount of radioactive eters and mnd.tions, rather than the manual scram oil that has been shipped off-site for processing, and the switches or, in manual turbine trip switches (or push-but-volume of solid dry radioactive waste which has been tons) provided in the main control room.

shipped off-site for processing. Low-level solid radioactive

4) Critical means that during the steady-state condition of waste consists of dry active waste, sludges, resins, and the reactor prior to the scram, the effective multiplication evaporator bottoms generated as a result of nuclear power f actor (k,) was essentially equal to one.

plant operation and maintenance. Dry radioactive waste includes contaminated rags, cleaning materials, dispos-UNPLANNED CAPABluTY LOSS FACTOR able protective clothing, plastic containers, and any other The ratio of the unplanned energy losses during a given material to be disposed of at a low-level radioactive waste period of time, to the reference energy pe 4 ration (the disposal site, except resin, sludge, or evaporator bottoms. energy that could be produced if the ur 4 <re operated Low-level refers to all radioactive waste that is not spent continuously at full power under referene ambient con-fuel or a by-product of spent fuel processing. 'this indica-dltions) over the same time period, expressed as a per-tor tracks radiological work performance for SEP #54. centage. 80

=_+

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 EagA Increase HPES and IR Accountability Through Use of Performance Indicators Procedural Noncomp!!ance incidents (Maintenance)..... .. 50 Clean Controlled Area Contaminations 21,000 Disintegrations / Minute Per Probe Area.. .5 Recordable injury / illness Cases Frequency Rate..... ..4 Preventable / Personnel Error LERs. .6 SEP Reference Number 24 Complete Staff Studies Staffing Level . 43 SEP Reference Number 25 Training Program for Managers and Supervisors implemented Disabling injury /lliness Frequency Rate. .3 Recordable injury /lliness Cases Frequency Rate. .4 SEP Reference Number 26 Evaluate and implement Station Standards for Safe Work Practice Requirements Disabling injury / Illness Frequency Rate... ..3 Recordable injury / Illness Cases Frequency Rate.. .4 SF.C Aeference Number 27 implement Supervisory Enforcement of industrial Safety Standards Disabling injury /lliness Frequency Rate. .3 Recordable Injury / Illness Cases Frequency Rate. .4 SEP Reference Number 31 Develop Outage and Maintenance Planning Manual and Conduct Project Management Training MWO Planning Status (Cycle 16 Refueling Outage).. . 67 Overall Project Status (Cycle 16 Refueling Outage). . 68 Progress of Cycle 16 Outage Modification Planning. . 69 SEP Reference Number 33 Develop On-Line Maintenance and Modification Schedule Percent of Completed Scheduled Maintenance Activities (All Maintenance Crafts). . 51 SEP Reference Number 38 Reduce Corrective Non-Outage Backlog Maintenance Workload Backlogs (Corrective Non-Outage). .. 46 SEP Reference Number 41 Develop and implement a Preventive Maintenance Schedule Ratio of Preventive to Total Maintenance & Preventive Maintenance items Overdue. .. 47 Procedural Noncompliance incidents. . 50 i SEP Reference Number 43 l Implement the Check Valve Test Program Check Valve Failure Rate. .37 81

l SAFETY ENHANCEMENT PROGRAM INDEX (cantinued) SEP Reference Number 44 Eggg Compliance With and Use of Procedures Procedural Noncompliance incidents (Maintenance)............. ... 50 SEP Reference Number 48 l Design a Procedures Control and Administrative Program Document Review. .. 56 i SEP Reference Number 52 Establish Supervisory Accountability for Workers Radiological Practices Radiological Work Practices Program..... . 55 SEP Reference Number 54 Complete implementation of Radiological Enhancement Program Collective Radiation Exposure......... ..... 16 q Volume of Low. Level Solid Radioactive Waste.. .. 38 i Clean Controlled Area Disintegrations 21,000 Counts / Minute Per Probe Area...... ..5 Contaminated Radiation Controlled Area..... . 54 l SEP Reference Number 58 Revise Physical Security Training and Procedure Program i Loggable/ Reportable incidents (Security). .... 57 SEP Reference Number 80 Improve Controls Over Surveillance Test Program Nurnber of Missed Surveillance Tests Resulting in Licensee Event Reports...... ... 20 SEP Reference Number 61 Modify Computer Program to Correctly Schedule Surveillance Tests Number of Missed Surveillance Tests Resulting in Licensee Event Reports..... . 20 SEP Reference Number 62 { Establish interim System Engineers ..... 58 I Temporary Modifications. Engineering Assistance Request (EAR) Breakdown... .... 60 Engineering Change Notice Status........... . 61 l Engineering Change Notices Open.. ......... 62 1 SEP Reference Number 88 Assess Root Cause of Poor Operator Training and Establish Means to Monitor Operator Training Licensed Operator Requalification Training. ...... 64 License Candidate Exams......... . 65 SEP Reference Number 71 Improve Controls over Temporary Modifications Temporary Modifications..... . 58 82

t REPORT DISTRIBUTION LIST R.L. Andrews M. P. Lazar K. L Belek B. R. Livingston B. H. Biome D. L. Lovett C. E. Boughter J. H. MacKinnon C. J. Brunnert J. W. Marcil G. R. Cavanaugh N. L Martice J. W. Chase R. D. Martin A. G. Christensen T. J. Mcivor K. G. Melstad O. J. Clayton ~ R. P. Clemens K. A. Miller R. G. Conner P. A. Mruz J. L. Connolley NuclearLicensing l G. M. Cook & industry Affairs S. R. Crites J. T. O'Connor D. W. Dale ~ W. W. Orr D. C. Dietz T. L Patterson M. L. Ellis R. T. Pearce -l H. J. Faulhaber R. L. Phelps l M. T. Frans W.J.Ponec D. P. Galle C. R. Rice S. K. Gambhir A. W. Richard J. K. Gasper D. G. Ried W. G. Gates G. K. Samide S. W. Gebers M. J. Sandhoefner L V. Gol@erU F. C. Scofield i D. J. Golden H. J. Sefick J. W. Shannon R. H. Guy A. L Hale C. F. Simmons J. B. Herman E. L Skaggs T. L. Herman J. L. Skiles K. C. Holthaus F. K. Smith L P. Hopkins R. L. Sorenson ) C.K. Huang K. E. Steele T. W. Jamieson M. A.Tesar R. L. Jaworski J. J. Tesarek R. A.Johansen J. W. Tills J. W. Johnson D. R. Trausch l W. C. Jones J. M. Waszak J. D. Keppler G. R. Williams i D. D. Kloock S. J. Willrett i L.T.Kusek l t 1 ) i ~ i f l 83

FORT CALHOUN STATION OPERATING CYCLES AND REFUELING OUTAGE DATES Event Date Range Production (MWH) Cumulative (MWH) Cycle 1 09/26/73 -02/01/75 3,299,639 3,299,639 1st Refueling 02/01/75 -05/09/75 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 Cycle 5 12/24/78-01/18/80 3,882,734 16,868,454 5th Refueling 01/18/80 - 06/11/80 Cycle 6 06/11/80 - 09/18/81 3,899,714 20,768,168 6th Refueling 09/18/81 -12/21/81 Cycle 7 12/21/81 -12/06/82 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 8th Refueling 03/03/84 - 07/12/84 Cycle 9 07/12/84 - 09/28/85 4,741,488 32,477,893 9th Refueling 09/28/85 - 01/16/86 Cycle 10 01/16/86 - 03/07/87 4,356,753 36,834,646 101h 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 Refueling 02/01/92 - 05/03/92 Cycle 14 05/03/92 09/25/93 4,981,485 56,022,013 14th Refueling 09/25/93 -11/26/93 Cycle 15 11/26/93 - 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 Achieved Full Power (100%) May 4,1974 Longest Run (477 days) June 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 E-- _}}

ML20080B478

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