ML20095J328

Performance Indicators

ML20095J328
Person / Time
Site:	Fort Calhoun
Issue date:	11/30/1995
From:	OMAHA PUBLIC POWER DISTRICT
To:
Shared Package
ML20095J316	List: LIC-95-0239, Forwards Fort Calhoun Station Performance Indicators Rept ML20095J328
References
NUDOCS 9512270061
Download: ML20095J328 (86)

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4 i I i OMAHA PUBLIC POWER DISTRICT i l FORT CALHOUN STATION i i PERFORMANCE INDICATORS REPORT i i i l XOVKMBER l 1995 i l Prepared By: j Production Engineering Division i System Engineering Test and Performance Group i i l NOVEMBER 1995 a

FORT CALHOUN STATION November 199s MONTHLY OPERATING REPORT OPERATIONS

SUMMARY

Normal plant maintenance, surveillance, equipment rotation activities and scheduled on-line modifications were performed during the month. Monitoring of a Control Element Drive Mechanism (CEDM) mechanical seal leak continued. On November 8,1995, a one-hour non-emergency notification was made to the NRC pursuant to 10CFR50.72(b)(1)(ii)(B) and (C) regarding the potential for the 480VAC breaker trip devices to inadvertently operate due to electrical noise, in the presence of a post-accident harsh environment. Interim guidance for operating the breakers will remain in an Operation Memorandum until the devices are replaced or procedures are revised. During the month of November, Fort Calhoun Station (FCS) operated at a nominal 100% power with the exception of a reduction to 99.3% for two days to allow a Chemical and Volume Control system ion exchanger to be placed in service. i

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4 FORT CALHOUN STATION PERFORMANCE INDICATORS REPORT November 1995 -

SUMMARY

POSITIVE TREND REPORT ADVERSE TREND REPORT A performance indicatot wrth data representing three A performance indicator with data representing three consectt.Ne months of improving performance or three consecutwe months of dechning performance or three consecutive months of performance that is trending consecutue months of performance that is superior to the stated goalis exhibiting a positrve trend per Nuclear toward dech,ning as determined by the Manager - Operations Drvision Quakty Procedure 37 (NOD-QP-Station Engineenng. constrtutes an adverse trend per Nuclear Operations Division Qualrty Procedure 37 37) (NOD-QP-37) A supervisor whose performance indicator exhibits an adverse trend by this definition The followng performance indicators exhibited positive may specify in wntten form (to be published in this trends for the reporting month: report)why the trend is not adverse. The following performance indicators exhibited adverse (Pa e 7) trends for the reporting month: Hiah Pressure Safety injection System Safety System Maintenance Workload Backloas Performance (Page 48) (Page 8) End of Adverse Trend Report. Emeraency A C Power System (Page 10) INDICATORS NEEDING INCREASED Emera v Diesel Generator Unreliabiktv p Diesel Generator Rehability (25 Demands) A performance indicator with data for the reporting (Page 12) period that is inadequate when compared to the OPPD goal is defined as *Needing increased Management Emeroency Diesel Generator Unrehabiktv Attention

• per Nuclear Operations Division Quakty (Page 13)

Procedure 37 (NOD-QP-37) Sionificant Events l'ldustrial Safety Accident Ratt (Page 20) (Page 2) Missed Surveillance Tests Results in Licensec Event Disabkna Iniurv/ Illness Freauency Rate Reports (Page 3) (Page 21) Unnianned Safety System Actuations - INPO Definition (Page 30) Pnmary System Chemistry Percent of Hours Out of LLEl!1 (Page 39) Secondary System Chemistry (Page 40) Hazardous Waste Produced (Page 55) Contaminated Radiation Controlled Area (Page 56) End of Positive Trend Report. V i i

L d FORT CALHOUN STATION PERFORMANCE INDICATORS REPORT November 1995 - SUMM ARY INDICATORS NEEDING INCREASED MANAGEMENT ATTENTION REPORT End of Report Improvements / Changes Report (continued) Fuel Reliability Indicator (Page 14) 4 Number of Control Room Eauioment Deficiencies (Page 15) Number of On-Line and Outaae Control Room Eautoment Deficiencies (Page 16) Collective Radiation Exposure (Page 17) Forced Outaae Rate (Page 24) Unit Caoability Factor (Page 27) Unit Capability Loss Factor (Page 28) Eauipment Forced Outaae Rate (Page 35) Percentaae of Total MWOs Comoleted oer Month Identified as Rework (Page 50) b-Line Chemistry Instruments Out-of-Service (Page 54) RadioloaicalWork Practices Proaram (Page 57) Temocrary Modifications (Page 60) PERFORMANCE INDICATOR REPORT IMPROVEMENTSICHANGES This section lists significant changes made to the report and to specific indicators within the report since the previous month Two new Chemistry Performance Indicators were added to the Noveter Performance Indicator Book See pages 41 and 42. I vi

O-Table of Contents / Summary eaan GOALS.................................................. x SAFE OPERATIONS Industrial Safety Accident Rate - INPO....................... 2 Disabling injury /lliness C,ases Frequency Rate. ...3 4 Recordable injury / Illness Cases Frequency Rate Clean Controlled Area Contaminations >1,000 Disintegrations / Minute per Probe Area .5 Preventable / Personnel Error LERs .6 .7 Safety System Failures Safety System Performance: 8 High Pressure Safety injection System Auxiliary Feedwater System .9 10 Emergency AC Power System Emergency Diesel Generator 11 Unit Reliability 12 Reliability (25 Demands) 13 Unreliability 14 Fuel Reliability Indicator 15 Control Room Equipment Deliciencies On-Line and Outage Control Room Deficiencies .16 Collective Radiation Exposure . 17 Maximum Individual Radiation Exposure 18 Violation Tren 1... 19 . 20 Significant Events.. Missed Surveillance Tests Resulting in LERs 21 PERFORMANCE Station Net Generation 23 Forced Outage Rate.... 24 Unit capacity Factor 25 f Equivalent Availability Factor 26 1 vii i

Table of Contents / Summary PERFORMANCE (continued) PAGE 27 Unit capability Factor.............. 28 Unplanned Capability Loss Factor Unplanned Automatic Reactor ... 29 Scrams per 7,000 Hours Critical Unplanned Safety System Actuations INPO Definition ... 30 NRC DeAnibon ...... 31 Gross Heat Rate. . 32 . 33 Therma' Performance 34 Daily Theimal Output 35 Equipment Forced Outages per 1.000 Critical Hours Component Failure Analysis Report (CFAR) Summary 36 . 37 Repeat Failures Volume of Low-Level Solid Radioactive Waste 38 Primary System Chemistry Percent of Hours Out of Umit. 39 Secondary System Chemistry 40 41 Chemistry. Chemistry. 42 COST Cents Per Kilowatt Hour 44 Staffing Level 45 Spare Parts Inventory Value 46 DIVISION AND DEPARTHENT PERFORMANCE INDICATORS Maintenance Workload Backlogs (Corrective Non Outage) 48 Ratio of Freventive to Total Maintenance & Preventive Maintenance items C.**rdue 49 Percentage of Total lW0s Completed per month identified as Rework 50 Overtime 51 Procedural Noncompliance Incidents 52 Oaily Schedule Performance. Percent of Completed Scheduled Activities 53 viii

Table of Contents / Summary DMSION AND DEPARTMENT PERFORMANCE INDICATORS PAfdi In-Une Chemistry instruments Out-of-Service..... 54 Hazardous Waste Produced . 55 Contarninated Radiation Controlled Area. 56 Radiological Work Practices Program 57 Document Review 58 Loggable/ Reportable tncidents (Security) 59 Modifications Temporary 60 Outstanding 61 Engineering Assistance Request (EAR) Breakdown 62 Engineering Change Notices Status 63 Open 64 Ucensee Event Report (LER) Root Cause Breakdown 65 Licensed Operator Requalification Training 66 License Candidate Exams 67 Open incident Reports 68 Cycle 17 Refueling Outage MWO Planning Status 69 Overall Project Status 70 Outage Modification Planning 71 On-Une Modification Planning 72 Progress of 1995 On-Une Modification Planning 73 ACBON PLANS. DEFINITIONS. SEP INDEX & DISTRIBUTION LIST Actior. Plans 74 j Performance Indicator Definitions 76 Safety Enhancement Program Index 85 Report Distribution Ust . 87 ix

OPPD NUCLEAR ORGANIZATION GOALS Vice President-1995 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 Supports: April 1994 Corporate Strategic Plan Goal 3, Obj: 3 & 4 A proactive, self-critical and safety conscious culture is exhibited throughout the nuclear organization. Individuals demonstrate professionalism through self-ownership and personal initiative and open comrnunication. 1995 Priorities: Improve SALP ratings. Improve INPO rating. Reduce NRC violations with no violations more severe than level 4. No unplanned automatic reactor scrams or safety system actuations. Objectives to support SAFE OPERATIONS. OBJECTIVE 1-1: No challenges to a nuclear safety system. OBJECTIVE 1-2: Conduct activities in accordance with applicable policies, technical specifications, procedures, standing orders and work instructions. Less than 1.4 NRC violations per 1,000 inspection hours. Fewer significant Corrective Action Documents (CADS) originating from activities. OBJECTIVE 1-3: Identify conditions BEFORE they affect plant safety and reliability. OBJECTIVE 1-4: Achieve all safety related 1995 performance indicator goals in the Performance Indicator Report. OBJECTIVE 1-5: Zero Lost Time Injuries and recordable injuries rate BELOW 1.5 percent. X

_ _. = I i OPPD NUCLEAR ORGANIZATION GOALS Vice President-1995 Priorities Goal 2: PERFORMANCE Supports: April 1994 Corporate Strategic Plan Goal 3, Obj: 2 and Goal 4, Obj: 1 j Achieve high standards of performance at Fort Calhoun Station resulting in safe, reliable and cost effective power production. 1995 PRIORITIES: Improve Quality, Professionalism 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. Objectives to support PERFORMANCE: OBJECTIVE 2-1: ) Achieve an annual plant capacity factor of 70% and a unit capability factor of 81%. OBJECTIVE 2-2: Execute the 1995 refueling outage in 49 days; emphasize shutdown plant safety. l OBJECTIVE 2-3: Achieve all performance related 1995 performance indicator goals in the Performance Indicator Report. OBJECTIVE 2-4: All projects and programs are planned, scheduled, and accomplished according to schedules, resource constraints, and requirements. OBJECTIVE 2-5: Team //ndividualownership, accountability, performance and teamwork is evident by improved plant i reliability; improved ratings for both INPO and NRC; reduced number of human performance errors and identification of performance problems by effective self assessment and for individuals as measured by the successful completion of department goals & objectives and other specific measures. xi --a

l OPPD NUCLEAR ORGANIZATION GOALS Vice President - 1995 Priorities Goal 3: COSTS Supports: April 1994 Corporate Strategic Plan Goal 2, Obj: 1,2 and 3, and Goal 6, Obj: 1 Operate Fort Calhoun in a manner that cost effectively maintains nuclear generation as an economically viable contribution to OPPD's " bottom line". Cost consciousness is exhibited at alllevels of the organization. 1995 Priorities: Maintain total O&M and Capital Expenditures within budget. Streamline work process to improve cost effectiveness. Objectives to support COSTS: OBJECTIVE 3-1: Conduct the nuclear programs, projects, and activities within the approved Capital and O&M 1 budgets. OBJECTIVE 3-2: Implement nuclear related Opportunity Review recommendations according to approved schedules ) and attain the estimated cost savings. 4 Goals Source: Scofield (Manager) xii

t 4 i i 1 i i l 1 i ? SAFE OPERAT ONS i i i Goal: A proactive, self-critical and safety conscious culture is I exhibited throughout the nuclear organization. Individuals demonstrate professionalism through self-ownership and per-sonal initiative and open communication. i l 1 l l l

1 Year-to-caWFCFindusHIi15afeti AcMTd Rife-{lNPO~DifinHIon) - FCS Average Rate (Last 12 Months) + FCS Year-End Goal (<0.50) b _.o_. Industry Current Best Quartile (.24) -.o 1995 INPO Industry Goal (<0.50) V 2. 13 3 1 0.5 e - = --'I e e c c c c c c c c c o 0[ Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec P*l INDUSTRIAL SAFETY ACCIDENT RATE As stated in INPO's December 1993 publication ' Detailed Descriptions of World Association of Nuclear Operators (WANO) Performance Indicators and Other Indicators for Use at U.S. Nuclear Power Plant': "The purpose of this indicator is to monitor progress in improving industrial safety j performance for utility personnel permanently assigned to the station." The INPO industrial safety accident rate value year-to-date was 1.33 at the end of November 1995. The value for the 12 months from December 1,1994, through November 30,1995, was 1.35. There were no restricted-time and 2ero lost-time accidents in November 1995. The values for this indicator are determined as follows: (number of restricted-time accidents + lost-time accidents + fatalities) x 200.000 (number of station person-hours worked) The 1995 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 Trend: Needs increased Management Attention 2 )

1 _,_. 1995Disi5li5g inTurynliness Frequency -x 1994 Disabling injurydliness Frequency Average Rate (Last 12 Months) [ GOOD] o_ 1995 Goal (0.50) V 1.8 1.6 _ ^ 1.4 j..._.- 1.2 ,e' ...s.-.-.....s' ,s.. O.8 / ,a / 0.6 k -Xw/ ~K w., N 0.4 / ~ N' ~ N ~ ~ o x%*%x%x/x d 0.2 0x l l + l Jan Feb Mar /pr May Jun Jul Aug Sep Oct Nov Dec DISABLING lNJURYllLLNESS FREQUENCY RATE (LOST-TIME ACCIDENT RATE) This indicator shows the 1995 disabling injury / illness frequency rate. The 1994 disabling injury / illness frequency rate is also shown. The disabling injury / illness frequency rate year-to-date was 1.33 at the end of November 1995. There were zero disabling injury / illness cases reported for the month. The disabling injury / illness frequency rate for the 12 months from December 1,1994, through November 30,1995, was 1.36. The 1995 Fort Calhoun year-end goal for this indicator is a maximum value of 0.5. Data Source: Sorensen/Skaggs (Manager / Source) Accountability: Chase / Conner Trend: Need increased Management Attention SEP 25,26 & 27 3

. = _ - i 1995 Recordable injurydHness Frequency 1994 Recordable injuryAliness Frequency I0000i u Average Rate (Last 12 Months) I I A ...o... Fort Calhoun coal 2.25 21 1.75 _ .......a....... G.<;....e..... Q...... f....... o 1.5 e...... s............ .......o...... ...,.. ~

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a I ,/ ~ g-l 0.75 "_ 0.5 _ 0.25 - 0 Jan Feb Mar Apr May Jun Jul Aug sep Oct Nov Dec l1995l RECORDABLE INJURY / ILLNESS FREQUENCY RATE i This indicator shows the 1995 recordable injury / illness frequency rate. The 1994 record-able injury / illness cases frequency rate is also shown. A recordable injury / illness case is reported if personnel from any of the Nuclear Divisions are injured on the job and require corrective medical treatment beyond first aid. The ) recordable injury / illness cases frequency rate is computed on a year-to-date basis. There have been eleven recordable injury / illness cases in 1995. The recordable injury / illness cases frequency rate year-to-date was 1.63 at the end of November 1995. There was one recordable injury / illness case reported for the month of November. The recordable injury / illness cases frequency rate for the 12 months from December 1, 1994, through November 30,1995, was 1.63. The 1995 Fort Calhoun year-end goal for this indicator is a maximum value of 1.5. Data Source: Sorensen/Skaggs (Manager / Source) Accountability: Conner Trend: None SEP 15, 25,26 & 27 4

. =. -. m Contamination Events (Monthly) + Contamination Events (YrD) 60 V 't 54 1 50 __ 4e 4s 42 40 __ ss i 31 2e 30 i 20 10 __ o O__ __ g i _g _g Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec ] l1995l i CLEAN CONTROLLED AREA CONTAMINATIONS 21,000 DISINTEGRATIONS / MINUTE PER PROBE AREA This indicator shows the Personnel Contamination Events in the Clean Controlled Area for contaminations 21,000 disintegrations / minute per probe area for the reporting month. There were 3 contamination events in November 1995. There has been a total of 54 contamination events in 1995 through the end of November. This compares to 42 at this time last year. Data Source: Chase /Cartwright (Manager / Source) Accountability: Chase /Lovett 4 Trend: None SEP 15 & 54 5

m PersonnelErrors(Each Month) e Preventable (18 MonthTotals) PersonnelError(18 Month Totals) 20 15 __ 10._ m c c c c 0 N-S. c May Jun Jul Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct 1995 1994l 1 PREVENTABLE / PERSONNEL ERROR LERs This indicator depicts 18-month totals for numbers of " Preventable" and " Personnel Error" LERs. The graph shows the 18-month totals for preventable LERs, the 18-month totals for Per-sonnel Error LERs and the Personnel Error totals for each month. The LERs are trended based on the LER event date as opposed to the LER report date. In October 1995, there were no events which were subsequently reported as an LER. No LERs were categorized as Preventable and as Personnel Error for the month of Oc-tober. The total LERs for the year 1995 (through October 31,1995) is six. The total Personnel Error LERs for the year 1995 is two. The total Preventable LERs for the year is three. The 1995 goal for this indicator is that the year-end values for the 18-month totals be no more than 12 Preventable and 5 Personnel Error LERs. Data Source: Trausch/Cavanaugh (Manager / Source) Accountability: Chase Trend: None SEP 15 6 i

Startup i Shutdown I e Operations l GOOD ...n... Industry Average Trend 2_ V E .5! E LA. 't; 1 .a l -..a......a......o. ,,,y ,,,y,,,, ,,,,y,,,,,y,,,,,o ,,,y 50 1 1 92-2 92 3 92-4 93-1 93-2 93-3 93-4 94-1 94-2 94 3 94-4 95-1 Year-Quarter SAFETY SYSTEM FAILURES This indicator illustrates the number of NRC Safety System Failures as reported by the Nuclear Regulatory Commission's Office for Analysis and Evaluation of Operational Data in the biannual" Performance indica-tors for Operating Commercial Nuclear Power Reactors" report. The following safety system failures occurred between the 2nd quarter of 1992 and the 1st quarter of 1995: 1st Quarter 1993: The SG low pressure scram signal block reset values, for all 4 channels of both SGs, were greater than the allowed limits, rendering this scram input inoperable during certain operating condi-tions. 2nd Quarter 1993: A section of the piping configuration for the borated water source of the safety injection system was not seismically qualified. This could have resulted in a failure of the system to meet design requirements during a seismic event. 4th Quarter 1993: 1) During surveillance testing, both PORVs for the LTOP system failed to open during multiple attempts. The failures were a result of differential expansion caused by a loop seal, excessive venting line back pressure, and cracked valve disks; 2) Calibration errors of the offsite power low signal relays could have prevented offsite power from tripping and the EDGs from starting in the required amount of time during a degraded voltage condition: 3) Both AFW pumps were inoperable when one was removed from service for testing and the control switch for the other pump's steam supply valve was out of the auto posdion; 4) Only one train of control room ventilation was placed in recirc when both toxic gas monitors became inoperable. Later during surveillance, the other train auto-started and brought outside air into the control room for a six-minute period. 1st Quarter 1994: A design basis review determined that an ESF relay could result in loss of safety injection and spray flow, due to premature actuation of recirculation flow. 4th Quarter 1994: An accident scenario was identified that could result in the inoperability of both control room air conditioning units. Following certain accident condrtions, CCW temperature could rise causing compressor rupture disc failure and a release of freon. There were no safety system failures in the 1st quarter of 1995. Data Source: Nuclear Regulatory Commission Accountability: Chase Trend: Positive 7

j M5EtfiliHigliPressure Sifitil6]ircti6n System UnavailibilityVilue ..%... Year-to-Date High Pressure Safetyinjection System Unavailability Value e_ Fort Camoun Goal (0.004) MD] + INPO hulustryGoal(0.02) _m IndustryUpper10%(0.0011) 1 I O 02 -- A L 0.015 __ 0.01 0.005 __ c = = = = = = = = = a i dy-U : 1 ;-

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0__ 1994 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 1995] l HIGH PRESSURE SAFETY lNJECTION SYSTEM SAFETY SYSTEM PERFORMANCE l This indicator shows the High Pressure Safety injection System unavailability value, as defined by INPO in the Safety System Performance Indicator Definitions, for the reporting month. The High Pressure Safety System unavailability value for the month of November 1995 was 0. There were 0 hours of planned unavailability, and 0 hours of unplanned unavail-i ability, during the month. The 1995 year-to-date HPSI unavailability value was 0.0006 at the end of the month. The unavailability value for the last 12 months was 0.0006. There has been a total of 13.39 hours of planned unavailability and 0.0 hours of un-planned unavailability for the high pressure safety injection system in 1995. The 1995 Fort Calhoun year-end goalfor this indicator is a maximum value of 0.004. The i 1995 INPO industry goalis 0.02 and the industry upper ten percentile value (for the three-year period from 1/92 through 12/94) is approximately 0.001. Data Source: Jaworski/Schaffer (Manager / Source) Accountability: Jaworski/Schaffer Trend: Positive 8 1 -a

l m Miiiillili Aliillrary FeedWileTSyifim~Unavalliblily + Ye ar to Date Em e rge nc y AC P ow e r Unavaila bility + Fort Calhoun Goal (0.01) r~o6~o-D) ~~ + 19 9 6 INP O Industry Goal (0.0 2 6) e_. In d u s tr y U p p e r 10% (0.0021) 0.03 0.026 -- i 0.02 0.016 0.01 c 3 0.006 e = = = = r r a 0 _4 Jan Fe b Mar Apr May Jun J ul Aug Sep Oct Nov Dec [iTiir] 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 Novernber 1995 was 0.00. There l were 0 hours of planned and 0 hours of unplanned unavailability during the month. The year-to-date unavailability value was 0.0034 and the value for the last 12 months was l 0.00396 at the end of the month. 1 There has been a total of 44.61 hours of planned unavailability and 12.92 hours of un-planned unavailability for the auxiliary feedwater system in 1995. 4 The 1995 Fort Calhoun year-end goal for this indicator is a maximum value of 0.01. The 1995 INPO industry goal is 0.025 and the industry upper ten percentile value is ap-proximately 0.002. i Data Source: Jaworski/Nay (Manager / Source) Accountability: Jaworski/Nay Trend: None 9

i M&ittilf Eirnergency AC Power unavaila~NiitFWIue x Year-to4ete Emergency AC Power thavailabilityValue e, Fort Cahoun Goal (0.024) l GOOD l _o 1995lPPOlndustryGoal(0.025) -e-. Industryupper10%(0.0035) y 0.14 _ 0.12 0.1 i 0.08 0.06 0.04 i 0.02 _ 1 0 0 0 0 0 0 0 0 _, _ _:W r---zH::- p-un 0 _sL _A, a 4 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 1995 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 Emergenc> %C Power System unavailability value for November 1995 was 0.008. During the motc.s here were 11.4 hours of planned unavailability, and 0.0 hours of un-planned unavailability for testing and repairs. The Emergency AC Power System un-availability value year-to-date was 0.007 and the value for the last 12 months was 0.009 at the end of the month. There has been a total of 103.6 hours of planned unavailability and 4.3 hours of un-planned unavailability for the emergency AC power system in 1995. The 1995 Fort Calhoun year-end goal for this indicator is a maximum value of 0.024. The 1995 INPO industry goal is 0.025 and the industry upper ten percentile value is ap-proximately 0.0035. Data Source: Jaworski/Ronning (Manager / Source) Accountability: Jaworski/Ronning Trend: Positive due to performance better than goal. 10 a i

m failures /26 Demands a Failures /50 Demands e Failuresitoo Demands G000) -... Trigger Values /20 Demands + TriggerValues/50 Demands II Trigger Values 100 Demands S -- : 7 6._ 5 4 m 2 _g, ,,9 93 j, ,9 gj j3 gj jg j j 39 o Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov {1994 (1995 EMERGENCY DIESEL GENERATOR UNIT RELIABILITY This bar graph shows three monthly indicators pertaining to the number of failures that were reported during the last 20,50, and 100 emergency diesel generator demands at the Fort Calhoun Station. Also shown are trigger values which correspond to a high level of confidence that a unit's diesel generators have obtained a reliability of greater than or equal to 95% when the failure values are below the corresponding trigger values. The Fort Calhoun 1995 goal is to have fewer failures than these trigger values. The demands counted for this indicator include the respective number of starts and the respective number of load-runs for both Diesel Generators combined. The number of start demands includes all valid and inadvertent starts, including all start-only demands and all start demands that are followed by load-run demands, whether by automatic or 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 minimum of one hour and to be loaded with at least 50% of design load (see exceptions and other demand criteria in the Definition Section of this report). Data Source: Jaworski/Ronning (Manager / Source) Accountability: Jaworski/Ronning Trend: Positive due to performance better than goal. 11 d

DG1 Failures /26 Demands i i e DG-2 Failures /25 Demands l0000l 5~ V 4-c r-o 3_ 2 1 1 1 1 1 1 1 1 1 1 i 1 q q 0 0 0 0 0 0 0 0 0 0 0 ' O O O Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov {1994l l1995 DIESEL GENERATOR RELIABILITY (25 DEMANDS) This indicator shows the number of failures experienced by each emergency diesel gen-erator during the last 25 start demands and the last 25 load-run demands. A trigger value of 4 failures within the last 25 demands is also 't ~vn. This trigger value of 4 failures within 25 demands is the Fort Calhoun goal for G ;3. 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 fail-ures within the last 25 demands on the unit. These actions are described in the Defini-tions Section of this report. A System Engineering Instruction has been approved for the Fort Calhoun Station to institutionalize and formally approve / adopt the required NUMARC actions. Diesel Generator DG-1 has experienced one failure during the last year, and zero fail-ures during the last 25 demands on the unit. Diesel Generator DG-2 has experienced one failure during the last 25 demands on the unit. Special diesel testing during hot weather took place during July. This testing enabled the diesel high temperature operability limits to be raised. Data Source: Jaworski/Ronning (Manager / Source) Accountability: Jaworski/Ronning Trend: Positive due to performance better than goal. 12

DGTUnreliabilifiValue . DG 2 UnreliabilityValue + StationUnreliabilityValue [gg 1995 Goal I i e Industry Upper 10%(0.002 for a 3-Year Awrage) Y 0.07 0.06 _0.05 0.05 -- c e c 0 0.04 [ o.028 0.03 0.02 0.01 O O O O 0 0 0 0 0 0 0 0 0 0 0 0 0 0', -q 0' 0.00 4_-- 9 9 9 9 9 9 9 s Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov {1997 91iS] EMERGENCY Diesel GENERATOR UNRELIABILITY The purpose of this indicator is to monitor the likelihood that emergency AC power generators will respond to off-normal events or accidents. It also provides an indication of the effec'iveness of maintenance, opera-tion and test practices in controlling generator unreliability. The last event occured on September 1,1995 when the Field Flash Relay on DG-2 failed. The year-to-date station EDG unreliability at the end of November 1995 was 0.028. The 1995 goal for this indicator is a maximum value of 0.05. For DG-1: There was 1 start demand for the reporting month with 0 failures. In addition, there were 0 load-run demands without a failure. For DG-2: There were 2 start demands for the reporting month with 0 failures. In addition, there were 0 load-run demands without a failure. Emergency diesel generator unreliability is calculated as follows: value per DG = SU + LU - (SU x LU) = number of unsuccessful starts where SU = Start Unreliability number of valid start demands LU = Load-run Unreliability = number of unsuccessfulload-runs number of valid load-run demands Station Value = average of DG 1 and DG-2 values Data Source: Jaworski/Ronning (Manager / Source) Accountability: Jaworski/Ronning Trend: Positive due to performance better than goal. 13

Fuel ReliabiUty l0000l 1995 INPO Industry Fuel Defect Reference (5 x 10-4 Microcuries/ Gram) .,1995 Goal q y 65 601 E 551 2 50 ' 3 451 .2 40 1 5 354 8 30 A cyc. is 0 251 n e=*me 5 201 o """ y '15 1 e UE B~ ~ ~ M IM, IE O W = Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov [fg l1995l FUEL RELIABILITY lNDICATOR The FUEL RELIABILITY INDICATOR (FRI) for November 1995 was 62.46 X 104 microcuries/ gram. The purpose of the FRI is to monitor industry progress in achieving and maintaining a high level of fuelintegnty. An effective fuelintegnty and performance monitoring program provides a means to detect fuel failures and assess the fuel failure number, physical condition, exposure, mechanism, and location. The November FRI value is based on data from November 1through 30* The days selected are when the plant chemistry values were at equihbrium for steady-state full power operation. Cycle 16 plant operation started on April 13* and attained 100% on April 23* During the months of June and July the plant operated at 100% power. The plant tripped at the end of August but has operated at 100% during the months of September, October and November. The November FRI value of 62.46 X 10d microcuries/ gram indicated an increase from the October FRl value of 51.2 X 104 microcuries/ gram. No new fuel failures were determined to have occurred during the month based on changes in the equilibrium Xenon and lodine data. This is consistent with the normal increase of fission products dunng a cycle and the increased power production of the peripheral assemblies due to shim bumout and the subsequent power distribution changes with power shifting from the center of the core to the periphery. Recent analysis through November 30,1995, performed by nuclear engineering, indicated four to six failed rods at core average power. The Cosium isotopic analysis indicated failures in several different bumup levels. OPPD personnel estimate that 15 to 25 rods are failed based on the results from the Cycle 15 and 16 RCS chemistry data and the end of Cycle 15 fuelinspection project. The INPO July 1995 report "WANO Performance Indicator Program Utility Data Coordinator Reference Notebook" (INPO No. 94-009, Rev.1) states the Industry 1995 Goal for fuel reliability is: " units should strive to operate with zero fuel defects". The 1995 Fort Calhoun Station FRl Performance Indicator goalis to maintain a monthly FRI below 5.0 x 10d microcuries/ gram. A value larger than 5.0 x 10d microcuries/ gram indicates a high probability of reactor core operation with one or more fuel defects. Data Source: Hotthaus/ Weber Accountability: Chase /Spilker Trend: Needs increased Management Attention 14

m ContrdlbomDeficienmes AkFd i contrd Fbom Deficiencies completed i m Con 1pistedwitHnTargetCuuWuDate ~* 50. . 100.0 % 87.6% 41 Cod OtwpHe80%f CR DdLarum by Tage CbnpidonOde C4.6% 4 4 87.0% 8 60.0% k I 30. 8 ^ ' '  % b G ~CL 24 24 -Q 23 y 21 o 20 - 40.0% s 5 m a w w 28 o% .a j 0 io 10. 20.0% # 4 0.0% 0 _ p + May Jun Jul Aug Sep od Pbv the 96 canard RxmDerciencies l l NuusER OF CONTROL Room EQUIPMENT DEFICIENCIES i This indicator measures the timeliness of closing Control Room Deficiencies. 1 Target Completion Dates are established by the Emergent Work Committee. The goalis to close at least 80% of all CRDs within the Target Due Date. i There were 21 Control Room Deficiencies completed during November 1995, and 14 I were completed within the target completion date. A Scheduling Coordinator has been assigned to track performance on a weekly basis and identify problem areas. Revisions have been made to the scheduling process to allow for more timely completion of CRDs. 1 Data Source: Chase / Walling (Manager / Source) Accountability: Chase /Faulhaber Trend: Needs increased Management Attention - Performance Below Goal 15

Oardue Number of On-Line Control Room Deficiencies + 35 33 8' 30 2e 25 28 e 2s 20 '8 15 10 7...,,,, g._ _ i i i 4 May-95 Jun Jul Aug sep Oct Nov Dec-95 [NuTnber of On-Line CRDii~l . Overdue Number of Outage Control Room Deficiencies + 25 2a 21 2J 0 :: 0 22 20 15 Note: Overdue items are those older than 18 months 10 5 2 2 2 2 2 2 2

0. __M M

M M "" "

• 4 i

i j May-95 Jun Jul Aug sep Oct Nov Dec-95 (Number of Outage CRDs l NUMBER OF ON-LINE AND OUTAGE CONTROL ROOM EQUIPMENT DEFICIENCIES This indicator shows the total number of On-Line;snd Outage Control Room Deficiencies, and the number of overdue Control Room Deficiencies. There were 25 on-line (13 were overdue) and 22 outage (2 were overdue) Control Room Deficiencies at the end of November 1995. i { The 1995 Fort Calhoun goal for these indicators are less than 8 overdue on-line and no overdue outage Control Room Deficiencies. i Data Source: Chase / Walling (Manager / Source) Accountability: Chase /Faulhaber/ Herman Trend: Needs increased Management Attention - Number of On-Line CRDs <8 Overdue exceeds goal 16

m M6rithly PersonnelRidiilion Exposure + Cumulative Personnel Radiation Exposure l Good] ...o. FCS Goal (143.1 Person-Rem) 150 _ o-4 o- _ o.. ..-..o. O o o 9 c. g 130 120 110 100 E $ 80 k 70 E o. 60 50 40 30 20 10 0h_ E_M Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec FI COtteCrive RADIATION EXPOSURE The 1995 Fort Calhoun goal for collective radiation exposure is less than 143.1 person-Rem. The exposure for November 1995 was 0.66 person-Rem (ALNOR), down from 0.684 Rem for October. The year-to-date exposure through the end of November was 138.094 person-Rem (TLD). The 1995 INPO industry goal for collective radiation exposure is 185 person-rem per year. The current industry best quartile is 145 person-rem per year. The yearly average for Fort Calhoun Station for the three years from 12/92 through 11/95 was 106.77 person-rem per year. 1 Data Source: Chase /Cartwright (Manager / Source) Accountability: Chase /Lovett Trend: Needs increased Management Attention SEP 54 17 I

O Highest Exposure (Month) g Highest Exposure (Year) 5000.. OPPD 4500 mrem /yr. Limit 4000 _ 3000 _ 2000 4 I f 1,266 FCS Goal 1000 4. l l 80 0 i i l November 9$~ MAXIMUM lNDIVIDUAL RADIATION EXPOSURE During November 1995, an individual accumulated 80 mrem, which was the highest individual exposure for the month. The maximum individual exposure for the year of 1,000 mrem was exceeded dunng March 1995 when an individual received 1,266 mrem (875 mrem of this was received during orifice plate repair in a steam generator). However, the OPPD 4500 mrem /yr limit is not expected to be exceeded. The OPPD limit for the maximum yearly individual radiation exposure is 4,500 mrem / year. The 1995 Fort Calhoun year-end goal is a maximum of 1,000 mrem. l Data Source: Chase /Cartwright (Manager / Source) Accountability: Chase /Lovett Trend: None 18

l m FCSCIfedVisisti6ns(M6nthly) , FCS Non-cited Violations (Monthly) __GOOO._ ... o... FCS Cited Violations (12-Month Average) FCS Non Cited Violations (12-Month Average) + Region IV Cited Violations (12-Month Awrage for Region IV top quartile) l I N~' W 10 r. -u )\\ c'2

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,i i a E P i F S t E m z z = m o z ~19Nj ~ 59i 1 VIOLATION TREND This indicator illustrates a 12-month trend for Fort Calhoun Station Cited Violations, Non-Cited Violations and Cited \\,iolations for the Top Quartile plants in Region IV. Additionally, the Fort Calhoun Station cited and non-cited violations for the past 12 months will be illustrated monthly. The 12-month trend for the Region IV top quartile lags 2-3 months behind the Fort Calhoun Station trend. This lag is necessary to compile information on other Region IV plants. The following inspections were completed during November 1995: IER No. Title 95-15 Emergency Planning Graded Exercise 95-18 Integrated Performance Assessment Process 95-19 Monthly Resident inspection To date, OPPD has received thirteen violations for inspections conducted in 1995. i Level 111 Violations 0 Level IV Violations 8 Level V Violations 0 Non-Cited Violations 5 Total 13 The 1995 Fort Calhoun Station Goal for this performance indicator is to be at or below the cited violation trend for the top quartile plant in Region IV. Data Source: Trausch/Cavanaugh (Manager / Source) Accountability: Trausch Trend: None 19

m NRC SliiilficihiEv~e~nts e_ Industry Average Trend {ob~6D] 1 1 f 0.5 _ 0 m r-e-r-e, am 92-2 92-3 92-4 93-1 93-2 93-3 93 4 94-1 94-2 94-3 94 4 95 1 l Year. Quarter l INPO Significant Events (SERs) [00iUlfl 7" 2-3 3 3 3 3 y 1 ~ 0 + 4_ g + + 4 + 92-2 92-3 92-4 93 1 93-2 93-3 93-4 94 1 94 2 94-3 94-4 95 1 { Year-Quarter l $IGNIFICANT EVENTS This indicator illustrates the number of NRC and INPO Significant Events for Fort Calhoun Station as re-ported by the Nuclear Regulatory Commission's Office for Analysis and Evaluation of Operational Data in the biannual ' Performance Indicators for Operating Commercial Nuclear Power Reactors" report and INPO's Nuclear Network. The following NRC significant events occurred between the 2nd quarter of 1992 and the 1st quarter of 1995: 3rd Quarter 1992: The failure of a Pressurizer Code safety valve to reseat initiated a LOCA with the potential to degrade the reactor coolant pressure boundary. 4th Quarter 1994: A potential accident scenario involving a large break loss of coolant accident or a main steam line break inside containment could result in the inoperability of both control room A.C. units. l The following INPO significant events, as reported in Significant Event Reports (SERs), occurred between ( the 2nd quarter of 1992 and the 1st Quarter of 1995: 2nd Quarter 1992: Intake of Transuranics during Letdown Filter Change-out. 3rd Quarter 1992: 1) RC-142 LOCA; and 2) Premature Lift of RC-142. 1st Quarter 1993: Inoperability of Power Range Nuclear instrumentation Safety Channel D. 2nd Quarter 1993: SBFU Breaker Relay (Switchyard) Plant Trip 4th Quarter 1993: Unexpected CEA Withdrawal. 1st Quarter 1994: Unplanned dilution of Boron concentration in the RCS. Data Source: Nuclear Regulatory Commission & INPO Accountability: Chase Trend: Positive 20 t l

Mased STs 1%stitingin LIRs l [GOCIT 3_ l V i 2 l 1 l 0 0 0 0 0 0 0 0 0 0 0 0 0 F l l l i 93 94 Jan Feb Mar Apr May Jun Jul Aug Sep Oct it w Dec 1995 ) NUMBER OF MISSED SURVEILLANCE TESTS RESULTING IN LICENSEE EVENT REPORTS This indicator shows the number of missed Surveillance Tests (STs) that result in Lic-ensee Event Reports (LERs) during the reporting month. The graph on the left shows the yearly totals for the indicated years. There were no missed surveillance tests resulting in LERs during November 1995. 4 On December 28,1994, during the per'ormance of OP-ST-SHIFT-0001, data was not entered for Steam Generator level per Surveillance Requirements. The 1995 Fort Calhoun monthly goal for this indicator is 0. Data Source: Monthly Operating Report & Plant Licensee Event Reports (LERs) Accountability: Chase /Jaworski Trend Positive SEP 60 & 61 21

PERFORMANCE j Goal: To strive for Excellence in Operations utilizing the high-i ) est standards of performance at Fort Calhoun Station that l result in safe, reliable plant operation in power production. i l i l 22 I

1 1 i 4 j Not Generation (10,000 MWh) l 40 35.08 34.75 34.29 1 l 30.46 i g! 22.82 } 21.19 l 15.29 g ai 4 !.0", j ow. 1 0 j 0_ +_. i _+. i __4_ i j i Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov l l l l STATION NET GENERATION During the month of November 1995, a net total of 350871.3 MWh was generated by the j Fort Calhoun Station. Cumulative net generation for Cycle 16 was 2,282,052.7 MWh at i the end of the month. Energy losses for August 1995 were attributable to a plant trip during a test of a backup automatic shutdown system, which began on August 24th. The generator was brought back on-line at 3:43 p.m. on Saturday, August 26th, after a two-day outage. l l Energy losses for May 1995 were attributable to: (1) the component cooling water, which was leaking into the lube oil system of RC-3D reactor coolant pump motor; and (2) the generator and reactor were again manually tripped because of a similar leak. The gen-erator was put on-line after replacement of all of the reactor coolant pump lube oil cooler i heat exchangers. i l Data Source: Station Generation Report i Accountability: Chase e Trend: None 23 j l

Forced Outage Rate (Monthly) i i + Forced Outage Rate (12 Months) GidO6-o _ Rut Calhoun Goal (24*4 40%. y 35%. 30%_ i 25%. 20%_ 15%. 10.f4 10%. 5%. o.e7% c c c 7 a a 0%

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^ c[= o j + 92 93 94 Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov 95 FORCED OUTAGE RATE The forced outage rate (FOR) was reported as 3.7% for the twelve months from Decem-ber 1,1994, through November 30,1995. The 1995 year-to-date FOR was 4.1% at the end of the month. Energy losses for August 1995 were attributable to a plant trip during a test of a backup automatic shutdown system, which began on August 24th. The generator was brought back on-line at 3:43 p.m. on Saturday, August 26th, after a two-day outage. Energy losses for May 1995 were attributable to two separate shutdowns to repair com-ponent cooling water leaks in the lube oil system of RC-3D reactor coolant pump motor oil leaks. The generator was put on-line after replacement of all four of the reactor coolant pump lube oil cooler heat exchangers. The 1995 Fort Calhoun year-end goal for this indicator is a maximum value of 2.4%. Date Source: Monthly Operating Report Accountability: Chase Trend: Needs increased Management Attention 24 l

~ l , M6httdyUHifCapacityFactor ...s.., Year-to Date Unit Capacity Factor g e LM CapacityFactor for Cycles 15 & 16 ._.._ 36-Month Amrage Unit CapacityFactor ._N. _ ] 110%, Fcs Goal (79.65%) 100 % 90%. o -G- - '*-.% " I g.. . j,,. 2_ = 70% g .a. 60%_ 8 ' " ' ' -8

• * ' # [

8 s 50% _ 40%._ 30'/. _ cyci is Ref ushre 20%. out eo. 10% 0% e y 1 Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov p99T ~i995] UNIT CAPACIW FACTOR This indicator shows the plant monthly Unit Capacity Factor, the Unit Capacity Factor for the current fuel cycle, year-to-date and the 36-month average Unit Capacity Factor. At the end of the month, the Cycle 16 Unit Capacity factor was 101.95%, and the Unit Capacity Factor for the last 36 months was 81.8%. The 1995 Fort Calhoun annual goal for this indicator is 79.65%. The Fort Calhoun 3-year average capacity factor goal for 1995 is 84.05%. The year-to-date value is 78.37% Energy losses for May and August 1995 are discussed on the previous page. The Unit Capacity Factor is computed as follows: Net Electrical Enerov Generated (MWH) Maximum Dependable Capacity (Mwe) X Gross Hours in the Reporting Period Data Source: Monthly Operating Report Accountability: Chase Trend: Neees increased management Attention (Below 1995 Goal) 25

Monthly EAF i i Year-to.oate Average Monthly EAF 12-Month Average EAF + w__ industry Median Value (76.7%for a 3 Year Average) 100 % e f.:s p. t ^ se a( E---5 ~ 80% _ ,. 3 g u n n n n ' t =

x. ---

m -._ / 60%- ~ ~ 40%. cycie is l O utag e 20%._ 0% 1 92 94 Jan Mar May Jul Sep Nov-95 EQUlVALENT AVAILABILITY FACTOR This indicator shows the plant monthly Equivalent Availability Factor (EAF), the year-to-l date average monthly EAF, and the year-end average monthly EAF for the previous three years. The EAF for November 1995 was reported as 98.92%. The year-to-date monthly aver-age EAF was 83.9% at the end of the month. Energy losses for May and August 1995 are explained on page 24. The Fort Calhoun average monthly EAF for the three years prior to this report was 88.80%. The industry median EAF value for the three-year period from 7/90 through 6/93 was 76.7%. I l l Data Source: Dietz/Kulisek (Manager / Source) l Accountability: Chase ( Trend: None l 26

i Monthly Unit Capability Factor A

• - Year-to-cate Unit Capability Factor S 36-Month Unit Capability Factor 100001 x

Fort Calhoun Goals O INPO Industry Goals 100 % y ...-er, m 5 ~ E f .h -N~ ~' 80% E

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60 % m....a.....e..- 40 % cyc= ss wueano 20% outae* 0% Dec Jan Feb Mar Apr May Jun Jul Aug sep Oct Nov l1994l (1995 l 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 continuously at full power under reference ambient conditions) over the same time period, expressed as a percentage (refueling periods excluded). The UCF for Novernber 1995 was reported as 100.0%. The year-to-date UCF was 79.4%, the UCF for the last 12 months was 81.2%, and the 36-month average UCF was reported as 89.3% at the end of the month. Energy losses for May and August 1995 are explained on page 24. The 1995 INPO industry goal is 80% and the industry current best quartile value (for the three-year period ending 12/94) is approximately 85%. The 1995 Fort Calhoun annual goal for this indicator is a minimum of 81.64%. The 3-year average capability factor goal for 1995 is 85.5%. Data Source: Generation Totals Report & Monthly Operating Report Accountability: Chase Trend: Needs increased Management Attention 27

Monthly thplanned Capability Loss Factor l GOOD l Year-To Date lhplanned Capability L. css Factor 4. 12-Month Awrage unplanned CapabilityLoss Fector y Fort CalhounGoal(3.97Y4 + IPPOlndustryGoal(4.5Y4 + IndustryCurrentBestChartile 40% _ l 30 % 1 20 % 1 [.' ~' L .- 7 ::~Z. y ..y.- -_g 10% i j 0% ! wr:7-t y- 'r c c c c c c c c c c c c Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct f4w 1995 1994l UNPLANNED (APABILITY BOSS 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. j The UCLF for the month of November 1995 was reported as 0.00%. Unplanned energy loss is defined as the energy that was not produced during the period of unscheduled shutdowns, outage extensions, or load reductions due to causes under plant manage-ment control. Energy losses are considered to be unplanned if they are not scheduled at least four weeks in advance. The year-to-date UCLF was 9.32%, the UCLF for the last 12 i months was 7.48%, and the 36-month average UCLF was reported as 4.5% at the end of the month. Energy losses for May and August 1995 are explained on page 24. The 1995 INPO industry goal is 4.5% and the industry current best quartile value is ap-proximately 3.2% or lower. The 1995 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 i Trend: Needs increased Management Attention. 28 l

) I ._.__ FCS REssio75 crams Pe77,000 Hours CritidaTYear-to-Dite _ _. FCS Reactor Scrams Per 7,000 Hours Critical for last 36 months ... Fort Calhoun Goal (0.0) ...... INPO Industry Goal (1) o - o_. Industry Upper 10%(1 per 7,000 hours critical) 3 2 = = + c N e s 6 4 6~ -6~ ~6 5 /e o F 1 0, Dec Jan Feb Mar Apr May Jun Jul Aug sep Oct Nov HTl f$95) FCS Reactor scrams 4 3 2 1 1 1 0 0 0 0 0 0 0 0 0 0 0 0 _u _+_ iB q 0 2 91 92 93 94 Dec Jan Feb Mar Apr May Jun Jul Aug sep Oct Nov 95 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 Calhoun Station. The lower graph shows the number of unplanned automatic reactor scrams that occurred during each month for the last twelve months. The year-to-date station value was 1.1 at the end of November 1995. The value for the 12 months from December 1,1994, through November 31,1995, was 1.0. The value for the last 36 months was 1.21. The 1995 Fort Calhoun goal for this indicator is 0. The 1995 INPO industry goal is a maximum of one unplanned automatic reactor scram per 7,000 hours critical. The indus-try upper ten percentile value is approximately 0.48 scrams per 7,000 hours critical. Data Source: Monthly Operating Report & Plant Licensee Event Reports (LERs) Accountability: Chase Trend: Needs increased Management Attention (Above FCS Goal) 29

m SafetySystem Actuations(iW6 Definition) ... FCS Goal (0) + Industry Upper 10 Percentile (0) 3-2. 1 1 1 s. 0 0 0 0 0 0 0 0 0 0 0 0 O _ - ; e e

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

There were no INPO unplanned safety system actuations during the month of November 1995. There was one INPO unplanned safety system actuation during the month of August 1995, it occurred on August 24,1995, when the plant was tripped during a test of a backup automati; shutdown system. The generator was brought back on-line at 3:43 p.m. on August 26th, after a two-day outage. An INPO unplanned safety sytem actuation also occurred during the month of July 1992 due to the loss of an inverter and the subsequent reactor trip on 7/3/92. The 1995 Fort Calhoun goal for this indicator is 0. Data Source: Monthly Operating Report & Plant Licensee Event Reports Accountability: Jaworski/Foley/Ronning Trend: Positive 30

g SafeW5ystem Actuati6ns (P5tCDiif"Esti66) , R:S Goal (0) + CriticalHours _,__ 12-Month Running Total SSAs (MtC Definition) 10 - _ 800 cyo. s __700 8_ 600 .9 f 2 6_ 4 a 400( l t 1 y 4 .g g4- ~ _300h ? ) l 200 2, a-i m-a-e-e-e-a-f __100 } ... g... p.g \\ i 04,, A> 0 --1 g ; 92 93 94 ONDJFMAMJJASONDJFMAMJJASON 59i 155il 99sj 1 l UNPLANNED SAFETY SYSTEM ACTUATIONS -(NRC DEFINITION) 4 This indicator shows the number of unplanned safety system actuations (SSAs), which includes the High and Low Pressure Safety injection Systems, the Safety injection Tanks, i and the Emergency Diesel Generators. The NRC classification of SSAs includes actua-3 tions when major equipment is operated and when the logic systems for these safety systems are challenged. An unplanned safety system actuation occurred in December 1993 when the main turbine and reactor tripped during Electro-Hydraulic Control pump start testing. Also, there was an unplanned SSA during the month of February 1994 when supervisory relay 86B/CPHSS failed, which resulted in a concurrent turbine and reactor trip. There have been no unplanned safety system actuations in the last 12 months. The 1995 Fort Calhoun goal for this indicator is 0. Data Source: Monthly Operating Report & Plant Licensee Event Reports (LERs) Accountability: Jaworski/Foley/Ronning Trend: None 31 4

g Gross Heat Rate . w Year-to-Date Gross Heat Rate f6l ...o.. Fort Calhoun Goal 10.75 y 1 10.5 l 1o.2s =2n A 7.__% _.y q 4 .__,s g so l 1 M = 3 1 g ) i 1 9.75 l ] y i n j s J erI. [o I l h I ) j 9.51 3 7 i l I 9 I k i i 3 1 h h 1 'q j d 9.25 1_ j _. 92 93 94 Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov 95 i Gross HEAT RATE This indicaier shows the Gross Heat Rate (GHR) for the reporting month, the year-to-date GHR, the goas and the year-end GHR for the previous three years. The gross heat rate for Fort Calhoun Station was 10,028 for the month of November 1995. The 1995 year-to-date GHR was 10,219 at the end of the month.

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

The 1995 Fort Calhoun year-end goal for this indicator is $10,157. Data Source: Holthaus/Willett (Manager / Source) Accountability: Chase /Jaworski Trend: None' 32

I 4 l e M6nthlyThermaTFsiformance g ,12-Month Average + Year-to-Date Average MonthlyThermalPerformance ..... Fort Calhoun Goal (99.6%) INPO industry Goal (99.5%) I- -) _.o _ industry Upper 10%(99.7%) i 100 % _ E c c c c c c c c c c 3.. g... ... g....... + + 99%_ cycae es ee 98%... -. y. _4_ p _4 i I Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov pisT) [Tsis] 4 THERMAL PERFORMANCE This indicator shows the Thermal Performance Value for the reporting month, the year-to-l date average monthly thermal performance value, the Fort Calhoun goals, the 1995 INPO industry goal and the approximate upper ten percentile value. The thermal performance value for November 1995 was 99.72. The year-to-date aver-1 age monthly thermal performance value was 99.5, at the end of the month. The average monthly value for the 12 months from December 1,1994, through November 30,1995, was 99.4%. The 1995 Fort Calhoun year-end goal for this indicator is a minimum of 99.6%. The 1994 4 Fort Calhoun goal was a minimum of 99.5%. The 1995 INPO industry goalis 99.5% and the industry upper 10 percentile value is approximately 99.9%. Data Source: Jaworski/Shubert (Manager / Source) i Accountability: Jaworski/Gorence Trend: None 33

+ M C@nt ._e FortOlham1495MWGbad TedSpec1500MWUmt 1500.- 12 1 l 1 16 1 ls=====

= = = = = = = = a-a = = = = = = = = = - 1494 h ji492 i s 1490 1 16 1 l 16 1 1484i 1 234 56 78 9 101112131415161718192021222324252627282930 DAILY THERMAL D'JTPUT The thermal output graph displays the daily operating power level during November 1995, the 1500 thermal megawatt average technical specification limit, and the 1495 thermal megawatt Fort Calhoun goal. Data Source: Holthaus/Willett (Manager / Source) Accountability: Chase / Tills Trend: None 34

m Number of Equipment Forced Outages (Monthly) GooDj %.._ Equipment Forced outage Rate /1,000 Critical Hrs. (12-Month Interval) l e_ Fort calhoun Year-End Goals (0.2) y 2-l l i l I 1.i. x x a c g O j 0t ID 92 93 94 Dec Jan Feb Mar Apr M ay Jun Jul Aug sep oct Nov EQUIPMENT FORCED OUTAGES PER 1,000 CRITICAL HOURS The equipment forced outage rate per 1,000 critical hours for the 12 months from Decem-ber 1,1994, through November 30,1995, was 0.41. The year-to-date rate per 1,000 critical hours for the months from January through November 1995 was 0.459. An equipment forced outage also occurred on February 20,1995, when the plant experi-enced a problem with a control element assembly motor drive and a related small leak of reactor coolant. Two equipment forced outages also occurred during May 1995, which were attributable to the component cooling water, which was leaking into the lube oil system of RC-3D reactor coolant pump motor, The 1995 Fort Calhoun year-end goal for this indicator is a maximum value of 0.20. Data Source: Monthly Operating Report & Plant Licensee Event Reports (LERs) Accentability: Chasc/Jaworski Trend. Neecs increased Management Attention 35

m _ _. e 1 o -+. Curip un 2 M ~*~ 18. 16. ei.14. f 12. I 10 8. 4 '?, ?, ?, N,_ /. s 1/ 2 0 J. A 4 0 N D J. F M A M J J A S O N. 94 95 96 i A gelN o rm al Us e 66% 1 7 s ten s ti n

• ", g g",*,

M a a uf as turlag g O th e r D e vic e s D efect 10 % 8% 4% ) E n gin e e tin gl D e s ig n 2% COMPONENT FAILURE ANALYSIS REPORT (CFAR)

SUMMARY

The top chart illustrates the number of component categories, application categories and total categories in which the Fort Calhoun Station has significantly higher (1.645 standard deviations) failure rates than the industry failure rates during the past 18-month Component Failure Analysis Report (CFAR) reporting period (from Feburary 1994 through July 1995). Fort Calhoun Station reported a higher failure rate in 6 of the 87 component categories (valves, pumps, motors, etc.) during the past 18-month CFAR period. The station reported a higher failure rate in 7 of the 173 application categories (main steam stop valves, auxiliary / emergency feedwater pumps, control element drive motors, etc.) during the past 18-month CFAR period. The pie chart depicts the breakdown by INPO cause categories (see the " Definitions" section of this report for descriptions of these categories) for the 50 failure reports (failure discovery dates within the 18-month CFAR period) with known failure causes that were submitted to INPO by Fort Calhoun Station. A total of 75 failure reports were submitted to INPO with discovery dates within the 18-month CFAR period. Data Source: Jaworski/ Frank (Manager / Source) Accountability: Jaworski/ Dowdy Trend: None 36

+ Components with more than One Failure x. Components with more than Two Failures 15 _ y 10 _ 8 6 0 4 4 4 4 3 3 3 3 3 3 ^ 1 1 1 0 0 Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov f99] lT555l REPEAT FAILURES The Repeat Failures Indicator (formerly called the " Maintenance Effectiveness Performance 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 discontinued, but station management considers it useful to continue to track repetitive component failures using the Nuclear Plant Reliability Data System (NPRDS). This indicator shows the number of NPRDS reportable components with more than one failure during the 18-month Component Failure Analysis Report (CFAR) period (failure discovery dates from February 1994 through July 1995) and the number of NPRDS reportable components with more than two failures during the 18-month CFAR period. During the last 18-month CFAR period, there were 6 NPRDS components with more than one failure. None of these 6 NPRDS reportable components had more than two failures. Recommendations and actions to correct these repeat failures are listed in the Biannual CFAR. The description and tag numbers of the NPRDS reportable components with more than one failure are listed below: Raw Water Pumps AC-10A, AC-108, and AC-10C Reactor Protection System Channel'A' Axial Power Distribution Trip Calculator Multiplier /Dider + Module Al-31 A-AW15-B4,5 Reactor Coolant Pump Motor RC-3D-M + Containment Cooling Coil VA-88, CCW Outlet Valve V/P-403C + Data Source: Jaworski/ Frank (Manager / Source) Accountability: Chase Trend: None 37

Ridiosclive Waste Buried ThisTonthlcTtft.) -ei.- Year-toCate Cumulatin Radioactiw Waste Buried GOOD -.o_. Fort Calhoun Goal (900 cu.ft.) Y 900 p_ __o ._c 3 o cp o _o 3_.__o _ c 800__ / / i i 700- / l / 600 3500. J u. 400 0 300 200 100 0. _ __+_ _+_ Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov ~i994j 1995j VOLuuE OF LOW LEVEL SOLID RADIOACTIVE WASTE This indicator shows the volume of the monthly radioactive waste buried, the cumula-tive year-to-aate radioactive waste buried, the Fort Calhoun and INPO goals, and the approximate industry upper 10%. Cu.Ft. Amount of solid radwaste shipped off-site for processing during current month 0 Volume of solid radwaste buried during current month 0 Cumulative volume of solid radioactive waste buried in 1995 266.6 Amount of solid radwaste in temporary storage 0 The 1995 Fort Calhoun goal for the volume of solid radioactive waste (buried) is 900 cubic feet. The 1995 INPO industry goalis 110 cubic meters (3,884 cubic feet) per year. The industry upper ten percentile value is approximately 27.33 cubic meters (965.3 cubic feet) per year. Data Source: Chase /Breuer (Manager / Source) Accountability: Chase /Lovett Trend: None SEP54 38

m Primarysystem Chemistry Percentof Hours Outof Limit {Gdoi] D __e Fort Calhoun Goal (0.02) V 2% -- c ^ o 1% ) ~Cicle75-j Refueling outage d j I 0%._' i i i i

Mg 1

Dec Jan Feb Mar Apr May Jun Jul Aug sep Oct Nov [i994] {fp53] PRIMARY SYSTEM CHEMISTRY l PERCENT OF HOURS OUT OF LIMIT i The Primary System Chemistry Percent of Hours Out of Limit indicator tracks the pnmary i system chemistry performance by monitoring 6 key chemistry parameters. The key pa-rameters are: lithium, dissolved oxygen, chlorides, flouride, hydrogen and suspended solids.100% equates to all 6 parameters being out of limit for the month. The Primary System Chemistry Percent of Hours Out of Specification was 0.25% for the month of November 1995. The 1995 Fort Calhoun monthly goal for this indicator is a maximum of 2% hours out of limit. i 4 Data Source: Smith / Spires (Manager / Source) Accountability: Chase / Smith i Trend: Positive due to performance better than goal. 39

.._ _.._______ ___=- m EarySystemm af._. 12-Morth Average GOO ._a FortCalhounGoal(1A) I f 1.6 1.5 - l 1A a a a a l 1.3._ .....-c.- ..e- ~ l -...4...- 1 + i e i i I + i + l 1 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec T9V5 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 November 1995 was 1.22. The 12-month average CPI value was 1.28 at the end of the month. The Chemistry Performance Index (CPI) was above the goal in July due to slightly higher than average sodium and chloride values Also the values provided as industry averages by INPO for 1995 are considerably lower than FCS historically has been able to achieve for secondary chemistry values. Iron, the one industry average that we are below, almost by half, does not assist in lowering the CPI because of the way the CPI is calculated. Data Source: Smith / Spires (Manager / Source) Accountability: Chase / Smith Trend Positive due to performance better than goal 40

t CHEMISTRY ACTION LEVELS EXCEEDED l l lmEvent Days + Average Event Days +Lwna j \\ 4 3.5 3 2.5 O !ii $]D==E=== E I i ( 8 k 5 i 0 f t 8 8 8 8 s 8 8 s 8 8 s M ONTH CHEMISTRY ACTION LEVELS EXCEEDED - EVENT DAYS The Chemistry Action Levels Exceeded indicator tracks the number of days in which chemistry parameters exceeded a corresponding action level for the reporting month, as well as a 12 month average of days an action levelis exceeded. The parameter action levels are delineated in Chem-istry procedure CH-AD-0003, Plant System Chemical Limits and Corrective Actions. An action level is considered to have been exceeded for the purpose of this indicator, whenever the parameter exceeds the CH-AD-0003 action level for the current system mode, with the excep-tion of the Steam Generators during Mode 1. The Steam Generators are considered to have exceeded an action levelin Mode 1 when the plant poweris greater than 30% and the power is changing less than 5% per day. The number of event days can exceed the number of days in a month since each event is counted separately and there can be multiple events per day. The 1995 Fort Calhoun goal for this indicator is the 12 month average of two event days per month. There is no goal established for the number of event days per individual month. l Historical data is used to calculate the monthly average event days. The 12 month average was calculated by dividing the number of event days by the number of preceding months, until twelve months were reached. Data Source: Chase / Spires Accountability: Spires Trend: None 41

.A. Goal 5.00 4.00 3.00 g J Ex at 2.00 n 1.00 Il W .: i l 0.00 y Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec l Month j PRIMARY SYSTEM LITHlUM % HOURS OUT OF LIMIT The Primary System Lithium Percent Hours Out of Limit indicator tracks the hours per month that the primary system lithium is out of specification. The Primary System Lithium Percent Hours Out of Limit was 1.5% for the month of No-vember 1995. 4 The 1995 Fort Calhoun monthly goal for this indicator is a maximin of 5% hours out of limit J Data Source: Chase / Spires (Manager / Source) Accountability: Spires Trend: None i 42

4 i i i I ) COST e i i l Goal: Operate Fort Calhoun Station in a manner that cost effectively maintains nuclear generation as an economi-l cally viable contribution to OPPD's bottom line. Cost con-sciousness is exhibited at all levels of the organization. i l d i l 1 i 1 43 i i

+ Actual Revised Budget OrigmalBudget ..... Plan 4.. 3.75 _. 3.5 __ 3.25 _ l / ,,,n 5 i O 2.75._ >n 2.5.. 2.25 2 D91 D92 D93 D94 J95 F M A M J J A S O N D95 D96 D97 D98 D99 Months CENTS PER KILOWATT HOUR 1 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 1994 and 1995 revised budgets. The basis for the actual curve is the Financial and Operating Report. The December 31 amounts are also shown for the prior years 1991 through 1994. In addition, the report shows the plan amounts for the years 1996 through 1999 for refer-ence. The basis for the dollars are the Nuclear Long Range Financial Plan and the 1995 Corporate Planning and Budget Review. The basis for the generation is provided by Nuclear Fuels. The 12-month average unit price (3.13 cents per kilowatt hour for October 1995) aver-aged above the budget due to 12-month generation not meeting the budget expectations, and 12-month expenses exceeding the budget. The Unit Price for the current month (November 1995) is not available at this time. Data Source: Scofield/Jamies on (Manager / Source) Accountability: Scofield Trend: None 44

l g NuclearServices DiWsion O Production Engineering Division i g Nuclear Operations Division g TotalNuclear 7'd 800. ns no ns 74, 700 600 l f T SM 487 4 42 4a 4,, 4a 400 i l 300_ 1' 2 1'i 18 8 18 7 iss seo 578 37, l 200_ f su 117 118 su su tis tu its its 100 O _ + i i _p + + i i ) Jan-93 JarF94 Apr-94 Jul-94 Oct-94 Dec-94 Mar-95 Jun-95 Sep-95 t5fS6ffing Level l STAFFING LEVEL The actual staffing levels for the three Nuclear Divisions are shown on the graph above. The authorized staffing levels for 1995 and 1996 are: i l Authorized Staffing l 1995 1996 j 439 432 Nuclear Operations Division j 185 175 Production Engineering Division j 115 113 Nuclear Services Division 739 720 Total l j Data Source: Ponec/Kobunski (Manager / Source) Accountability: Ponec j Trend: None SEP 24 4 1

Spare Parts inventoryValue ($ Million) 16.6, 'l 6.5 16.4 16.3 , 16.2 Q o 16.1 1 E \\ 5 16 i l 15.9 L i 15.8 15.7 15.6 i Dec Jan Feb Mar Apr May Jun Jul Aug sep Oct Nov T99Tg [iq Spare Parts Inventory Vaiue The spare parts inventory value at the Fort Calhoun Station at the end of November 1995 was reported as $16,103,345.

• Parts being resupplied and replenished following last outage.

Data Source: Steele/Huliska (Manager / Source) Accountability: Willrett/McCormick Trend: None* 46 ]

i } 4 i I I 1 i DIVISION AND DEPARTMENT PERFORMANCE i 1 l INDICATORS i i i Goal: Achieve high standards at Fort Calhoun Station j resulting in safe, reliable and cost effective power pro-duction. a i 4 l i i 1 47 )

1 CorrectiWMiiiintenance e Preventive Maintenance Non-Corre ctive/Pla nt im prove me nts ._o_ Fort Calhoun Goal 1000 33 t Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Non-Outage Maintenance Work Order Backlog l 1995l e NNl % Owrdue = 38% e 3 11 ,E o. i , namn, I Ruty Ruty Ruty Ruty R uty 1 2 3 4 5 Total MWOs = 776 MAINTENANCE WORKLOAD BACKLOGS This indicator shows the backlog of non-outage Maintenance Work Orders remaining open at the end of the reporting month. It also includes a breakdown by maintenance classification and priority. The 1995 goal for this indicator is 400 non-outage corrective maintenance MWOs. The current backlog of corrective MWOs is 483. To ensure that the MWO backlog is worked in a timely manner, non-outage maintenance completion goals have been established as follows: Goal Priority 1 Immediate Action 2 days Priority 2 Urgent 5 days Priority 3 Operational Concems 21 days Priority 4 Routine Corrective 90 days Priority 5 Non-Essential 180 days Contriued management attention is required. Data Source: Chase /Schmitz (Manager / Source) Accountability: Chase /Faulhaber Trend: Adverse SEP 36 48 i I

_ _ ~ _ _ _. _ i Ratio of PreventNe to Total Maintenance I 100%__ 90%._ 80% _ l 70%- 60% __ ll llll llIL Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov l1994l l1995l j i l \\ g Preventive Maintenance items Overdue i _o Fort Calhoun Goal 2%. lf l l l 1% 1 c c = = c = 3 0% N Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov yeTl j1995l l l RATIO OF PREVENTIVE TO TOTAL MAINTENANCE & j PREVENTIVE MAINTENANCE ITEMS OvERouE The top graph shows the ratio of completed non-outage preventive maintenance to total com-i pleted non-outage maintenance. The ratio was 58.15% for the month of November 1995. The lower graph shows the percentage of scheduled preventive maintenance items that are overdue. During November 1995,522 PM items were completed. All PMs were completed 5 within the allowable grace penod or were administratively closed. The 1995 Fort Calhoun monthly goal for the percentage of preventive maintenance items over-i due is a maximum of 0.5%. Data Source: Chase /Schmitz/Meistad (Manager / Sources) Accountability: Chase /Faulhaber Trend: None SEP 41 & 44 49 l

m Rework as identified by craft o-Fort Calhoun Goal (<3%) 6% -- s.a % ^ ~ 4.7% i h 4% __ s.s % s.2 % 3.2 % l y, g i "5 j 2% iss 1% i. i i i i i. i 0% Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov pV9T) l1995l PERCENTAGE OF TOTAL MWOs COuetETED PER MONTH IDENTIFIED AS REWORK This graph indicates the percentage of total MWOs completed per month identified as rework. Rework activities are identified by maintenance planning and craft. This indicator is calculated from the 15th October to the 15th of November, due to the delay in closing open MWOs at the end of each month. The Fort Calhoun monthly goal for this indicator is <3%. A detailed review is conducted of rework items each month to identify generic concerns. Data Source: Faulhaber/Schmitz (Manager / Source) Accountability: Chase /Faulhaber Trend: Improving 50

1 m Maintenance Owrtime __g._1244onth Awrage Maintenance Owrtime goog .o.. Fort Calhoun "On-Une" GoaI(10%) l 45%__ V 40%. ] j 35%_ 1 \\ 30%. 25%. 20%. 1 5 f 15%. p i x x x M 10%. o o 5%. x 0% = Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov 1995 l1994l i l MAINTENANCE Ovearine The Maintenance Overtime Indicator monitors the ability to perform the desired rnainte-l nance activities with the allotted resources. i l The percent of overtime hours with respect to normal hours was reported as 5.0% for the f month of November 1995. The 12-month average percentage of overtime hours with l respect to normal hours was reported as 13.0 % at the end of the month. The 1995 Fort Calhoun monthly "on line" goal for this indicator is a maximum value of j 10%. i i j Data Source: Chase /Schmitz (Manager / Source) i Accountability: Chase /Faulhaber i Trend: None i i l l

Human Performance CRs(Maintenance) i-20 _. 18 3 I i 16 i is i 14 i l f $ 12 __ i ? 10 _ 5 1 a 8_- j l 4 6._ f No information Available for the j 4-Months of Sept. and Oct. 2-i 0 i-t.....-------- p ............--_--_p__. .. l. l j l Jul Aug Sep Oct Nov Dec l FROCEDURAL NONCOMPLIANCE INCIDENTS (MAINTENANCE) This indicator shows the number of Condition Reports related to procedural noncompli-ance incidents assigned to the Maintenance Department. Data Source: Faulhaber Accountability: Chase /Faulhaber Trend: None SEP 15,41 & 44 52 a--a1- - - m -m

A g% Scheduled Activities Completed '^ 0% Emergent Activities 100.0 % - 90.0% __ 84.8 % 86.5 % 85.1% 80.0%. 70.0% _ 60.0%. 50.0% - 40.0% - 30.0% - 24.7% 24.7% 20.0% - = 10.0% 0.0% -_ i i i i Sep.95 Oct Nov Dec-95 DAILY SCHEDULE PERFORMANCE PERCENT OF SCHEDULED ACTIVITIES COMPLETED i This indicator shows the percent of Integrated Plant Schedule activities completed on l schedule. All work groups and activities are included. The percent of emergent work is calculated as a percentage of the total number of sched-uled and emergent activities. ) The 1995 Fort Calhoun monthly goal for completed scheduled maintenance activities is l 85%. Data Source: Chase /Schmitz (Manager / Source) i Accountability: Chase /Faulhaber Trend: None SEP 33 i 53

m %ofiturstheinUneOurristryinstnertsarvinoperable N~ _o_.1996 RrtOdumm(bal(17/4 I Y wa w4l 2F4. 2r4. 18 % 194._ 14 % 1T4. 1 MM i i i i i i i --+- t H a Dec Jan Rib Nhr Apr Mry Jui Jd Aug Sep Oct Nw isbi istir l l lN-l,1NE CHEMISTRY INSTRUMENTS OUT-OF-SERVICE This indicator shows the percentage of hours the in-line chemistry system instruments are inoperable for the reporting month. The chemistry systems involved in this indicator include the Secondary System and the Post Accident Sampling System (PASS). l At the end of November 1995, the percentage of hours the in-line chemistry system instruments were inoperable was 10.28%. The following instruments were out of service during the month: CE-6770A-A Steam Generator Blowdown Specific Conductivity Three PASS System sequences were out of service most of the month while maintenance was being performed. The entire instrument channel is considered inoperative if: 1) the instrument is inopera-tive, 2) the chart recorder associated with the instrument is inoperative, or 3) the alarm function associated with the instrument is inoperative. If any of the functions listed above are not operational, then the instrument is not performing its intended function. Data Source: Chase /Reneaud (Manager / Source) Accountability: Chase /Jaworski l Trend: Needs increased Management Attention 54

II m WaeliPrEdisidEiicNM5 nth-(Kilograms) e Monthly Average Waste Produced During the last 12 Months (Kilograrns) _o-Fort caihoun Monthly Average Goal (150 kilograms) ._e Federal & State Monthly Lirnit (Max.of1,000 kg) 1000 : x x x x x x x x x x x 800 , 600 E 2 400 200 _ n- - --.-o----o o o e o o o e o 0l i l t i j l l i i Dec Jan Feb Mar Apr May Jun Jul Aug Sep oct Nov 1 ggy l1995l HAZARDOUS WASTE Paooucso This indicator shows the total amount of hazardous waste produced by the Fort Calhoun Station each month, the monthly average goal and the monthly average total for hazard-ous wast produced during the last 12 months. This hazardous waste consists of non-halogenated hazardous waste, halogenated hazardous waste, and other hazardous waste produced. During the month of November 1995,0.0 kilograms of non-halogenated,0.0 kilograms of halogenated and 0.0 kilograms of other hazardous waste was produced. The total haz-ardous waste produced during the last 12 months is 470.6 kilograms. Hazardous waste is counted based upon a full drum of waste. The 1995 Fort Calhoun monthly average goal for hazardous waste produced is a maxi-mum of 150 kilograms. Data Source: Chase /Carlson (Manager / Source) Accountability: Chase / Smith Trend: Positive 55

=. l l ~ dD] GO l m Contaminated Radatkm ControNed Ama _e_ Fort Calhoun Gael(10*A) l V i 10*4. _ o e c e c e o o o e e o ( l i I l 9%__ l e I l 8%. + 4 _4 Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov T98J4] ~ 1995 CONTAMINATED RADIATION CONTROLLED AREA This indicator shows the percentage of the Radiologically Controlled Area that is contami-nated based on the total square footage. The 1995 monthly non-outage goal is a maxi-mum of 9.5% contaminated RCA. At the end of November 1995, 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 Trend: Positive SEP 54 56

Identiheii~PRWPs (Year to Date) g + Fort Calhoun Goal (<20) - 0 20 20 : 18 16 15 15 15 14 _ 15 E 14 13 f 12 E 12 1 ! 10. D 8 1 6 4 4 2 1 0f 1 Jan Feb Mar Apr May Jun Jul Aug sep oct Nov Dec [YssT] [199!ij RADIOLOGICAL WORK PRACTICES PROGRAM The Radiological Work Practices Program Indicator shows the number of Poor Radiologi-4 cal Work Practices (PRWPs) which were identified during the reporting month. The number of PRWPs which are identified each month should indirectly provide a means to qualitatively assess supervisor accountability for their workers' radiological performance. During the month of Ncvember 1995, there were O PRWPs identified. There have been 20 PRWPs in 1995. The 1995 year-end goal for PRWPs is a maximum of 20. Data Source: Chase /Cartwright (Manager / Source) Accountability: Chase /Lovett Trend: Needs increased Management Attention Currently meeting 9 aal, attention needed not to exceed SEP 52 57

.~. O Documents Scheduled for Review g Documents Reviewed g Documents Overdue 200 ) l 180__ 160 4 140 120__ 100. 80 60 40. 20 _ l 0 +, + +_ + +_ un+ _ 3: + + q Dec Jan Feb Mar Apr May Jun Jul Aug sep Oct Nov {i994j l1995l DOCUMENT Review This indicator shows the number of completed, scheduled, and overdue (greater than 6 months past the scheduled due date) biennial reviews for the reporting month. These document reviews are performed in-house and include Special Procedures, the Site Se-curity Plan, Maintenance Procedures, Preventive Maintenance Procedures, and the Op-erating Manual. During November 1995, there were 81 document reviews scheduled, while 44 reviews were completed. At the end of the month, there were 14 document reviews more than 6 months overdue. There were 4 new documents initiated during November. Beginning in September, these figures include PED and NOD procedures. Data Source: Chase /Plath Accountability: Chase /Jaworski Trend: None SEP 46 58

g Syst:m Fcitures GOOD l l O Non-System Failures 40 Y 35. 30 j 1 25 f 22 + i Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov l [iisT) [iis5] l OGGABLE/ REPORTABLE INCIDENTS (SECURITY) l This graph shows the Loggable/Reportablo incidents (Security) Indicator and depicts (1) the total number of loggable/ reportable incidents concerning system failures which oc-I curred during the reporting month, and (2) the total number of loggable/ reportable inci-l dents non-system failures concerning Security Badges, Access Control and Authoriza-tion, Security Force Error, and Unsecured Doors. During the month of November 1995, there were 25 loggable/ reportable incidents iden-tified. System failures accounted for 21 (84%) of the loggable/ reportable incidents. The ECN on Microwave Zone 17 has been completed and to date there have been no further environmental failures. The four (4) non-system errors involved a lost / unattended secu-i rity badge, a security badge removed from the Protected Area, and two security force j errors. This indicator provides information en security performance for Safety Enhancement Pro-l gram (SEP) Item No. 58. 4 Data Source: Sefick/Woerner (Manager / Source) i Accountability: Sefick j Trend: None SEP 58 f 59 ) i i 1

TempxariModificati ns >1-cyclii3idlRPo requMfor removan-~~ o i Temporary Modifications >6 months old (Removable on-line) + Fort Catioun Goals for >1-cycle and >6 months old o u 6 6 x--i Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 1995l TEMPORARY MODIFICATIONS This indicator provides information on the number of temporary modifications greater than one fuel cycle old requiring a refueling outage (RFO) for removal and the number of temporary modi-fications removable on-line that are greater than six months old. The 1995 Fort Calhoun monthiy goals for this indicator are zero. However, one temporary modification (BAST level indication) has been approved by management to exceed these goals due to cost effectiveness consider-ations (reference PED-STE-94-042). There is currently 1 temporary modification that is greater than one-fuel cycle old requiring a refueling outage to remove: RC-3D cover gasket pressure indicator, which is awaiting comple-tion of MWO 941450, which is scheduled for a future refueling outage whenever cover gaskets are replaced. In addition, at the end of November 1995, there were 6 temporary modifications installed that were greater than six months old that can be removed on-line. These were: 1) Local indication for BAST CH-11 A and CH-118, in which Licensing sent FLC 94-001 to the NRC 6/27/ 95 for approval; 2) Control system for intensifier on HCV-2987, which is awaiting completion of ECN 94-280, scheduled for completion 12/95; 3) brace to instrument air (IA) header "T" to water plant, which is awaiting completion of ECN 94-482, scheduled for completion 12/95; 4) braces on main IA header, which is awaiting completion of ECN 94-482, scheduled for completion 12/95; 5) HE-3 Crane safety line, which is awaiting completion of ECN 95-054, scheduled for issue from DEN-Mechanical 1/12/96;. 6) "A" Channel RPS VHPT capacitor, which is awaiting completion of MR-FC-95-010, DEN-Electrical to issue a 1996 on-line mod. These scheduled completion dates have been set based upon priority for use of modification and design resources and approved by the NPRC. At the end of November 1995, there was a total of 24 TMs installed in the Fort Calhoun Station. 8 of the 24 installed TMs require an outage for removal and 16 are removable on-line. In 1995, a total of 40 temporary modifications have been installed. Data Source: Jaworski/ Turner (Manager / Source) Accountability: Jaworski/Gorence Trend: ContinuedManagement Attention is Needed SEP 62 & 71 60

e Total Modification Packages open ._o FortCalhounYear-EndGoal j i# ur 120 100. 80 H 60 _ so s 40 20 O__ i + + q _.s a_ + ,G 92 93 94 Dec Jan Feb Mar Apr May Jun Jul Aug sep Oct Nov 95 OUTSTANDING MODIFICATIONS 4 This indicator shows the total number of outstanding modifications (excludina outstandina modifications which are proposed to be cancelled). 4 Reporting I Cateaory '93 '94 '95 '96 '97 '98 Month l Form FC-1133 Backlog /in Progress 0 0 1 0 0 0 1 Mod. Requests Being Reviewed 0 0 3 0 0 0 3 Design Engr. Backlog /In Progress 0 0 0 19 2 11 32 Construction Backlog!!n Progress 5 0 13 5 0 0 23 1 Design Engr. Update Backlog /In Progress 1 5 10 0 0 0 16 i Totals 6 5 27 24 2 11 75 (outage + OnLine) (3+3) (0+5) (13+14) (17+7) (0+2) (11+0) (44+31) l At the end of November 1995,22 additional modification requests had been issued this year and 9 modification requests have been cancelled. The Nuclear Projects Review Committee (NPRC) has conducted 58 backlog modification request reviews this year. 4 The Nuclear Projects Committee (NPC) has completed 21 backlog modification request j reviews this year. i

• A review of the reports used to determine the total number of outstanding modifications and their various stages of accomplishment was undertaken at the request of the Nuclear Planning Department. The results of the review determined that the reports were not providing complete / accurate data. The reports have been corrected. The revised totals beginning with the March 1995 data are reflected in the current graph.

The 1995 year-end Fort Calhoun goal for this indicator is a maximum of 63 outstanding modifications. Data Source: Skiles/Ronne (Manager / Source) Scofield/Lounsberry (Manager / Source) Accountability: Scofield/Skiles Trend: None* g,

80 -- EARS Requiring Engineering Closeout - Not in Closeout 60 g sE O DEN ~ 40 20

_ E, M ; M _4 0.

.+ _s _e.C~3a m r, r sep Oct Nov sep Oct Nov Sep Oct Nov sep Oct Nov 0-3 Months 3-6 Months 6-12 Months >12 Months NOVEMBER 1995 Overdue EARS 0 bgineering Response g Nseout(sE 30 20 M p_ f'"""'i i Priority 0 Priority 1 Priority 2 Priority 3 Priority 4 Priority 5 Priority 6 li , PrTo~rltpTa 2 Priority 3 ...o.. TotaTOpen EARS ~g ~ 200 "" ~ ~ ~ " " '"'#~ ~"'# ~~ 150 ' o.. .a.

c.....a i

+ - _ _ + + q Dec Jan Feb Mar Apr May Jun Jul Aug sep Oct Nov 1994 199s l 82 E ARs 7s EAms en 2 7 Overdue i;g ~ ~###. s,., .'."oi ENGINEERING ASSISTANCE REauEST BREAK 00WN This indicator shows a breakdown of the number of EARS assigned to Design Engineer-ing and System Engineering. The 1995 year-end goal for this indicator is a maximum of 140 outstanding EARS. Total EAR breakdown is as follows: j EARS opened during the month 6 EARS closed during the month 10 Total EARS open at the end of the month 122 Data Source: Skiles/ Parsons (Manager / Source) Accountability: Jaworski/Skiles Trend: None SEP 62 62

l 13 e is4 997 CLOSEOUT DEN 0 3 Months 59 3 8 Months ECN Status -Overall Backlog 1m Received a Completed a Backlogged O j 83 i 250. 0-3 Months 57 t er er ze sm 150 -h 4 f

• 0 2 43

, 3e j 50. d 27 a 22 m 83 22 22 2 N+ I 3mt+ 0 ]us 4

== + a 87 3 -50. 24 June Jul Aug Sep Oct Nov-

• s Month:

3.. uonen, 88 % 95 15 % Design Engineering 250 { 200. o.3 N 8 150. Months A. 38 so as er e3 78 72 3% M o nths $0. 3 b 2t I m 22 I p as as tr 2s s3 u 20 eu 0. . $ 3B + l' N N+~N: a June Jul Aug Sep Od Nov. 95 System Engineering i A - 12 2 200 ise is, iss iss 18' .s Months 12. [ 77% 100. 6 50 - 20 " I-'8 2' 154 e e is "8' d e { 0 ... d + I N-+. .2 2 + 2 h 2+ A 3,', 2 l June Jul Aug Sep Od Nov. ,,3 [,,,,, M o nths l Procurement /Conslr*uction I til 250.

3. u.ne n.

200.,it4 oss 150. E [ 1' tie $is i 100. = r 5 '85 50. l 5 se o as vie ,s 'd, l 0 + i $_.- 8 0-8 M *"t h' w ) June Jul Aug Se p Oct Nov. 95 Drafting / Closeout ENGINEERING CHANGE Norice STATUS 1 Data Source: Skiles/ Parsons (Manager / Source) Accountability: Skiles/Jaworski Trend: None SEP 62 i 63

l 1s2 es 7e 10 3 l PC TYPE P rio rity DC TYPE Proit 2 a.[ Total Open ECNs = 539 sa Total Open ECNs = 539 0 uSN. Closeout or Drafting Nr.t Cornplete 32 28 E Maintenance /ConstructiorVProcurement. Work Not Cortplete P riority P ilo rity 0 System Engineering. Response. Confirmatio n Not Cornplete S&g ta2 17 % 14 % E DEN. Engineer 6ng Not Complete ad we

1. 2 2M - as er me s

+ 3 l l P rio rit y 384 Oct Nov95 g g Jun Jul 29 71 350. 3,, 297 P rionty P rionty 8 Jun Jul Aug Sep Oct 2v.95 3a4 Substdute Replacement item ED&, Open ss% 00. P riority r. 37 Jun Jul Aug Sep Oct Nov-95 P riority P riority ,,'f 8 Document Change ECNs open 474 ENGINEERING CHANGE Notices OPEN Data Source: Skites/ Parsons (Manager Source) Accountability: Skiles/Jaworski Trend: None j 64

0 Ailiaisistrative C661TRProblem g Licensed Operator Error N Other Personnelbror 5 Maintenance Problem O Design /Constructionlinstallation/ Fabrication Problem E Equipment Failures 1 2 1 0 4.. Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct {199i {i955l blCENSEE 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 November 1,1994, through October 31,1995. To be consistent with the Preventable / Personnel Error LERs indicator, this indicator is reported by the LER event date, as opposed to the LER report date. The cause codes are intended to identify possible programmatic deficiencies. For de-tailed descriptions of these codes, see the " Performance Indicator Definitions" section of this report. There were no events in October 1995 that resulted in an LER. Data Source: Trausch/Cavanaugh (Manager / Source) Accountability: Chase Trend: None 65

d O Total Requalificat60n Training Hours a Simulator Training Hours g Non-Requalification Training Hours a Number of Exam Failures 40 37 35.5 34,3 35 35 32 30 26 25 20 _ 37 16 2 1.5 8 10 .5 5 .5 5 4 .5 3 5 3 2.5 2 I 0 O o 0 0000 n I1 i i i 0. i-Cycle Cycle Cycle Cycle Cycle Cycle Cycle Cycle 94 7 95 1 95-2 95-3 95 4 95-5 95-6 95 7

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

" Note 2: Includes 8 hours of GeneralEmployee Training. blCENSED OPERATOR REQUALIFICATION TRAINING This indicator provides information on the total number of hours of training given to each crew during each cycle. The simulator training hours shown on the graph are a subset of the total training hours. Non-Requalification Training Hours are used for APO/EOP verification & validation, INPO commitments, GET, Fire Brigade, Safety Meetings, and Division Manager lunches. Exam failures are defined as failures in the written, simulator, and Job Performance Measures (JPMs) segments of the Licensed Operator Requalification Training. Requalification Training Rotation 95-7 was not completed during November. There-fore, no data is available. Data Source: Gasper /Guliani(Manager / Source) Accountability: Gasper /Guliani Trend: None SEP 68 68

l ) g SRCTExams AiihiinTstered O sROExams Passed O RO Exams Administered g ROExams Passed 15 _ 4 I 10 ~ i 1 i 51 s I 3 1 ~] 1 1 4 j i i i 1 0 Dec Jan Feb Mar Apr May Jun Jul Aug sep Oct Nov FIDDT ysq I,1 CENSE CANDIDATE EXAMS This indicator shows the number of Senior Reactor Operator (SRO) and Reactor Opera-tor (RO) quizzes and exams taken and passed each month. These internally adminis-tered quizzes and exams are used to plot the SRO and RO candidates' monthly progress. During the month of November 1995, there were O RO and 0 SRO exams given, due to Requalification Training Rotation 95-7 not being completed during the month of Novem-ber. Data Source: Gasper /Guliani(Manager / Source) Accountability: Gasper /Guliani Trend: None SEP 68 67

m OjiiiHRii4M6atfiifold OpenSigfacartIRs i i _+_ TotalOpenIRs 600. i 500 300 249 228 29 _r _p + + p Dec Jan Feb Mar Apr May Jim Jul Aug Sep Oct Nov ~i9N] 1995] OPEN lNCIDENT REPORTS This indicator shows the total number of Open irs, irs greater than 6 months old, and the number of open significant irs. Also, at the end of November 1995, there were 396 open irs. 249 of these irs were greater than 6 months old. There were 99 Open Significant irs at the end of the month. These numbers have been restated to reflect the elimination of CARS from the system. As of April 21,1995, CARS are no longer being issued. As of September 21,1995 Inci-dent Reports are no longer issued. All future corrective actions will be documented on Condition Reports. Data Source: Conner /Plott (Manager / Source) Accountability: Andrews/Phelps/Patterson Trend : None 68

1 I i 1 0 TctalOutage MNos j g MWos AnadybWork l 700. 622

i 800.

MWOHolds S stem / 500-Ranna &gneemg 194 124 200. ED4 23 38 100. O_ . i i Sep05 Oct Nw Dec-95 l ) i MWO PLANNING STATUS (CYCLE 17 REFUELING OUTAGE) This indicator shows the total number of Maintenance Work Requests (MWRs) and Main-1 tenance Work Orders (MWOs) that have been approved for inclusion in the Cycle 16 j Refueling Outage. This graph indicates: i - Parts Holds - Planning Complete, Awaiting Parts l l - System Engineering Holds - Awaiting System Engineering Input to Planning - Planner Holds - Maintenance Planner has not completed planning the work package. - ECN Hold - Awaiting Substitute Replacement items ECN from DEN. Data Source: Chase /Schmitz (Manager / Source) i Accountability: Chase /Faulhaber Trend: None SEP 31 i 69

b 1996 Outage Projects Status Report P 1 I g Last Month g This Month 100 O For Schedule l' 90 80 i 70 i 60 __ $ 50 8 }

1. 40 n

l u 3, 30 n n 4 22 tt a a 20 aa, u, 4 s 1 0__ + i 8 s. 5 -8 F E E 17 38 8 = < =l = m w> E = i [ 3E E E S EE e $E 8 8 y o! EE E e = sa E 2 i e B* 4 i E E ]5 3 i Special Services Engineering Department i OVERALL PROJECT STATUS l (Cycle 17 Refueling Outage) i This performance indicator shows the status of projects which are in the scope of the Cycle 17 Refueling Outage. SSED's goalis to have all projects completed by August 23, j 1996, 30 days prior to the Refueling Outage start date. Data Source: Jaworski/Swearngin (Manager / Source) Accountability: Jaworski/Boughter Trend: None SEP 31 70 4

-+-- Baselsre Schedule for PRC Approval -G-Projected / Actual Schedule for PRC Approval - - Futal Design Pkg issued (2 FD DCP lasued Pno t to 05/0795) - + - Total M odif caten Packages (V)(6 Added After 05/0795) 9...++.++++4.4..+.+.+++.+.++++.++.+.++...+++4.+.+.+++++. .+++4..+.+.+.. W8 S57 18

ie n.

h35 =e dR4 15ga 8 / 2 x ,j' ~ o $$$$$hfffhh!!$h$ff$f$f$ l 5 8ES5M 8 5 65N 5 N M 5 m - PROGRESS OF CYCLE 17 OUTAGE (1996 MODIFICATION PLANNING) (FROZEN SCOPE OF 9 OUTAGE MODIFICATIONS) This indicator shows the status of Modifications approved for installation during the Cycle i 17 Refueling Outage. Modifications added to the outage list after May 1,1995, are not part of this indicator. The data is represented with respect to the baseline schedule (es-tablished June 16,1995) and the current schedule. This information is taken from the modification variation report produced by Design Engineering Nuclear. The goal for this indicator is to have all modification packages which were identified prior to May 1,1995, PRC approved by March 22,1996. 6 Modifications added after May 1, 1995, not included. November 1995 Modifications added: 0 Deleted = 0 Graph corrected to represent the baseline schedule. ) Data Source: Skiles/Ronne (Manager / Source) Accountability: Phelps/Skiles Trend: None SEP 31 71

+ BareliiW5she~dUlif6fPRCApproval ... Projected / Actual Schedule for PRc Approal 10 _ Enb9 f 2 2o I ?. E / f8 i t ra ii e "e

./

o a 7 e .8 e SI =8 8 6 g m a 5_u % .m. _p.py .y 1 .1 1/6/95 2/10S5 3/17/95 4/21/95 5/26/95 6/30S5 8/4/95 9/8/95 10/13/95 PROGRESS OF 1995 ON l,INE MODIFICATION PLANNING (FROZEN SCOPE OF 9 MODIFICATIONS) This indicator shows the status of modifications approved for on-line installation during 1995. The data is represented with respect to the baseline schedule (established 1/13/

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

The goal for this indicator is to have all modification packages which were identified prior to January 13,1995, PRC approved by October 30,1995.1 modification added after January 13,1995, not included. This goal was met 09/21/95. November 1995 Modifications Added: 0 Deleted = 0 Data Source: Skiles/Ronne (Manager / Source) Accountability: Phelps/Skiles Trend: None SEP 31 72

+ BaseliHsSchTduTif5r PRC~ Approval _,_ Projected / Actual Schedule for PRC Approval Finafoesian Package issue Total Moalfication Packages (7)(1 Added After 05S185) . x.. 6,u....+..n..,..,...,...,..n..,..,..s....y..,..,..,...,..,.s..,...a..n. . s...s.. n.. y..,.. s...,. y.. w.s...,... y 4...s..,...s.. y. 4..., 5 1 t E 23 o} !2 z 4 1 o _m. 4 : : : >: s 4, 3 4 1 1 1 6/16S 5 7/2185 8/25SS 9/29S5 11/3S5 12/885 1/12S6 2/16S6 3/22S6 PROGRESS OF 1996 ON LINE MODIFICATION PLANNING 4 (FROZEN SCOPE OF 6 MODIFICATIONS) This indicator shows the status of modifications approved for on-line installation during 1996. Modifications added to the on-line list after May 1,1995, are not part of this indica-tor. The data is represented with respect to the baseline schedule (established June 16, 1995) and the current schedule. This information is taken from the Modification Variation Report produced by Design Engineering Nuclear. The goal for this indicator is to have all modification packages which were identified prior to May 1,1995, PRC approved by March 25,1996.1 Modification added after May 1, 1995, not included. November 1995 Modifications Added: 0 Deleted = 0 Graph corrected to represent the baseline schedule. Data Source: Skiles/Ronne (Manager / Source) Accountability: Phelps/Skiles Trend: None SEP 31 73

.ew,. 4 .mlA ..Jaa- -.---*es. -e w

• w--

-ae--m (_m.--dwa-w-, ara.--_m_w_s._m,s_ m_du. es_,Am. m.a.mM_w-A4h-ad. a 3-aa mm 4 Ar-awm--.-44 -e p. _= __AAMa. maul _ O a l l ACT ON PLANS 1 i i s i l l l l i 74 l

i ACTION PLANS This section lists action plans that have been developed for the performance indicators cited as Adverse Trends during the month preceding this report. Also included are Action Plans for indicators that have been cited in the preceding month's report as Needing increased Management Attention for three (3) consecutive months. 4 In accordance with Revision 3 of NOD-QP-37, the following performance indicators would require action plans based on three (3) consecutive months of performance cited as "Needing increased Management Attention": . Industrial Safety Accident Rate (page 2) . Maintenance Workload Backlogs (page 48) The action plan for Industrial Safety Accident Rate (page 2) is as follows: REVERSING THE INDUSTRIAL SAFETY ADVERSE TREND Even though the goal of zero lost-time accidents will not be met in 1995, the emphasis on safety and the reporting of potential safety hazards are still high priorities. The standards for safety will be raised by making the following items part of the station's daily operations: Promptly resolve safety problems. Promptly follow-up safety training to supervisors / crew leaders. Use the Near Miss forms to resolve potential safety concerns. The action plan for Maintenance Workload Backlogs (page 48) is as follows: A detailed review is being conducted to determine which stage of the maintenance process has a higher than expected backlog. Areas being reviewed are: Planning Scheduled Maintenance Bulk Work 75

1. o 1

1 PERFORMANCE lNDICATOR DEFINITIONS I + AUKILIARY FEEDWATER SYSTEM SAFETY SYSTEM CLEAN CONTROLLED AREA CONTAMINATIONS t i,000 PERFORMANCE DISINTEGRATIONS / MINUTE PER PROBE AREA The sum of the known (planned and unplanned) unavailable The personnel contamnation events in the clean controlled area, hours and the estmated unavailable hours for the auxdiary Thesindicator tracks personnel performance for SEP #15 8 54. medwater system for the reporting period divided by the crReal hours for the reportog pened muniplied by the number of trains CONTAhENATED RADIATION CONTROLLED AREA in the auxiliary feedwater system. The percentage of the Radiation Controlled Area, whch includes COLLECTIVE RADIATION EXPOSURE the auxiliary budding, the redweste building, and areas of the C/RP buildmg, that is comaminated based on the total square Collectrve radstion exposure is the total extemal whole-body footage. Thrs indcator tracks performance for SEP #54. dose received by al on-sRe personnel (meluding contractors and visRors) durmg a time period, as measured by the DAILY THERMAL OUTPUT thermoluminescent dosimeter (TLD). Collective radiation exposure is reported in units of person-rem. This indcator This indcator shows the dady core thermal output as measured tracks radiologmal work performance for SEP #54 from computer point XC105 (in thermal megawatts). The 1500 MW Tech Spec hrnet, and the unmet portion of the 1495 MW COMPONENT FAILURE ANALYSIS REPORT (CFAR) FCS daily goal for the reporting month are lso shown.

SUMMARY

DIESEL GENERATOR RELIABILITY (26 Demands) The summary of INPO categones for Fort Calhoun Station with j sagndicarWy higher (1.645 standard deviations) fadure rates than This indcator shows the number of failures occurring for each ( the rest of the industry for an eighteen-month time period. emergency diesel generator dunng the last 25 start demands Fadures are reported as component (i e., pumps, motors, main and the last 25 load-run demands. steam stop vanes, control element motors, etc.) categones. DISABLING INJURY /lLLNESS FREQUENCY RATE Fadure Cause Categones are: (LOSS TIME ACCIDENT RATE) Age / Normal Use -thought to be the consequence of Thisindcatoris defined as the number of accidents for all utdtty expected wear, aging, end-of-life, or normal use. personnel permanently assigned to the station, involving days away from work per 200,000 man-hours worked (100 man-Manufacturing Defect - a faiiure attnbutable to inadequate years). This does not include contractor personnel. This assembly or initial quakty of the responsible component or indicator tracks personnel performance for SEP #25,26 & 27. system DOCUMENT REVIEW (BIENNIAL) Engineenng/Desagn a failure attnbutable to the inadequate design of the responsible component or system. The Document Review Indicator shows the number of documents reviewed, the number of documents scheduled for Other Devices a fadure attnbutable to a failute or review, and the number of document reviews that are overdue misoperation of another conponent or system, including for the reporting month A document review is considered associated devces. overdue if the review is not complete within six months of the assigned due date. This indicator tracks performance for SEP Mamtenance/ Action resuRing from improper mamtenance,

1. 46.

lack of maintenance, or personnel errors that occur dunng maintenance activitieson the component., EMERGENCY AC POWER SYSTEfA SAFETY SYSTEM PERFORMANCE Testmg Action resuRing from improper testing or personnel errors that occur durmg testing activities. The sum of the known (planned and unplanned) unavailable and the estimated unavailable hours for the emergency AC power Initial Installation Error caused by improper initial system for the reporting period divided by the number of hours installation of equipment in the reporting penod muniplied by the number of trains in the emergency AC power system. CENTS PER KILOWATT HOUR EMERGENCY DIESEL GENERATOR UNIT RELIABILITY The purpose of this indcator is to quantify the economical operation of Fort Calhoun Station. The cents per kilowatt The rulicator show the nunter of failures that were reported during the hour indicator represents the budget and actual cents per last 20,50, and 100 ernergency diesel generator dernands at the Fort ktowett hour on a tweNo-month average for the current year. Cdan Malion. Aho shove are trigger values which correlate to a high el fcn ence at a un(s danel generators haw Wained a The bases for the budget curve is the approved yearly budget. The basis for the actual curve is the Financial and Operating [e n the alum Report. 76

~. - - - - I s PERFORMANCE INDICATOR DEFINITIONS I and the successful test that follows repair to venty operabdsty

1) Number of Start Demands: All valid and inadvertent start should not be counted as demands or failures when the EDG a

demands, including all start only demands and all start has not been declared operable again. demands that are followed by load-run demands, whether by automate or manual indiahort A start-only demand is EMERGENCY DIESEL GENERATOR UNRELIABILITY j a demand in which the emergency generator is started, but j 1 no attempt is made to load the generator. This indicator measures the total unrehabihty of emergency diesel generators. In general, unreliability is the rabo of

2) Number of Start Failures: Any fadure within the unsuccessful operabons (starts or load-runs) to the number of emergency generator system that prevents the generator valid demands. Total unreliabildy is a combination of start from achieving speedled kequency and voRage is classified unrehabildy and load-run unrehabihty.

I as a valid start failure. This inc;udes any conddion identafled in the course of maintenance inspections (with ENGINEERING ASSISTANCE REQUEST (EAR) 1 the emergency generator in standby mode) that defindely BREAKDOWN would have resulted in a start failure if a demand had occurred. This indcator shows a breakdown, by age and pnonty of the l EAR, of the number of EARS assigned to Design Engineenng

3) Number of Load 4 tun Demands: For a vahd load-run Nuclear and System Engineering This indicator tracks demand to be counted, the load-run attempt must meet performance for SEP #62.

one or more of the following cntena: ENGINEERING CHANGE NOTICE (ECN) STATUS A) A load-run of any duration that results from a real automatic or manualinatiahon. The number of ECNs that were openeo, ECNs that were i completed, and open backlog ECNs awaiting complebon by B) A load-run test to satisfy the plant's load and durabon DEN for the reporting month This indcator tracks performance as stated in each test's specifications. for SEP #62. C) Other specsal tests in which the emergency generator ENGINEERING CHANGE NOTICES OPEN is expected to be operated for at least one hour while .j loaded with at least 50% of its design load. This indcator breaks down the number of Engineering Change i Notices (ECNs) that are assigned to Design Engineering

4) Ntenberof Load 4 tun Failures: A load-run failure should Nuclear (DEN), System Engineenng, and Maintenance. The i

b* counted for any reason in whch the emergency graphs provide data on ECN Facihty Changes open, ECN generator does not pick up load and run as predeted. Substitute Replacement items open, and ECN Document e Failures are counted dunng any valid load-run demands. Changes opert This indicator tracks performance for SEP #62.

5) Exceptions: Unsuccessful attempts to start or load-run EQUIPMENT FORCED OUTAGES PER 1,000 CRITICAL should not be counted as vahd demands or failures when HOURS they can be attnbuted to any of the following-Equipment forced outages per 1,000 entcal hours is the inverse A) Spunous tnpa that would be bypassed in the event of of the mean time between forced outages caused by equipment en emergency.

failures. The mean hme is equal to the number of hours the reactor is enhcalin a penod (1,000 hours) divided by the number B) Malfunction of equipment that is not required during of forced outages caused by equiprnent failures in that period. an emergency. 4 EQUlVALENT AVAILABILITY FACTOR C) Intenbonalterminahon of a test because of abnormal conditions that would not have resulted in major This indcator is denned as the ratio of gross available l diesel generator damage or repair. generahon to gross maximum generation, expressed as a percentage. Available generation is the energy that can be a D) Malfunctions or operahng errors which would not produced if the unit is operated at the maximum power level have prevented the emergency generator from being permitted by equipment and regulatory limdations. Maximum restarted and brought to load within a few minutes. generation is the energy that can be produced by a unit in a geven penod if operated continuously at maximum capacity. E) A failure to start because a porhon of the starting system was disabled for test purpose,if followed by FORCED OUTAGE RATE a successful start wdh the starting system b its normal alignment. This indicator is defined as the percentage of time that the unit was unavailable due to forced events compared to the time Each emergency generator failure that results in the generator planned for electrical generation. Forced events are failures or being declared inoperable should be counted as one demand other unplanned condthons that require removing the unit from i and one fadure. Exploratory tests dunng corrective maintenance service before the end of the next weekend. Forced events 77

PERFORMANCE lNDICATOR DEFINITIONS include start up failures and events initiated while the und is in Contractor personnel are not included for this indicator. i reserve shutdown (i e, the unit is availatne but not in sannce) ) IN-LINE CHEMISTRY INSTRUMENTS OUT OF SERVICE FUEL RELIABILITY INDICATOR Total number of in-line chemistry instruments that are out-of-This Indcator is deAned as the steady state pnmary coolant l-service in the Secondary System and the Post Accident 131 activity, corrected for the tramp uranium contnbution and Sampling System (PASS) normalized to a common punAcation rate. Tramp uranium is fuel which has been deposited on reactor core internals from LICENSE CANDIDATE EXAMS previous defective fuel or is present on the surface of fuel elements from the manufactunng process. Steady state is Thisindicator shows the number of SRO and/or RO quizzes and defined as continuous operabon for at least three days at a exams that are administered and passed each month. This power level that does not vary more than + or 5% Plants indicator tracks training performance for SEP#68. should collect data for the indcator at a power level above 85%, when possible. Ptarts that did not operate at steady-state power LICENSED OPERATOR REQUALIFICATION TRAINING above 85% should collect data for this indicator at the highest steady state power level attained during the month. The total number of hours of training given to each crew during each cycle. Also provided are the simulator training hours The density correction factor is the ratio of the specinc volume (which are a subset of the total trainmg hours), the number of of coolart at the RCS operating temperature (540 degrees F., Vf non-REQUALIFICATION tranng hours and the number of exam = 0 02146) divided by the specific volume of coolant at normal failures. This indicator tracks training performarme for letdown temperature (120* F at outlet of the letdown cooling heat SEP # 68 exchanger, Vf a 0 016204), which results in a density correction factor for FCS equal to 1.32. LICENSEE EVENT REPORT (LER) ROOT C AUSE BREAKDOWN l GROSS HEAT FATE This indcator shows the number and root cause code for Gross heat rate is defined as the ratto of total thermal energy in Ucensee Event Reports. The root cause codes are as follows' Brtish Thermal Units (BTU) produend by the reactor to the total gross electncal energy produced by the generator in kdowatt.

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

supervisory deficiencies that affect plant programs or j activities (i e., poor planning, breakdown or lack of HAZARDOUS WASTE PRODUCED adequate management or supervisory control, incorrect procedures, etc). The total amount (in Kilograms) of non-halogenated hazardous waste, halogenated hazardous waste, and other hazardous

2) Licensed Operator Error - This cause code captures j

waste produced by FCS each month. errors of omission / commission by hcenseo reactor 1 operators dunng plant activities j HIGH PRESSURE SAFETY INJECTION SYSTE*4 SAFETY SYSTEM PERFORMANCE

3) Other Personnel Errnt - Errors of omis1, ion /comrnission J

committed by non-licensed personnel involved in plant The sum of the known (planned and unplanned) unavailable activities hours and the estimated unavailable hours for the high pressure safety injection system for the reporting penod divided by the

4) Maintenance Problem The intent of this cause code is to crtcal hours br the reporting penod multiphed by the number of capture the full range of problems which can be attnbuted trains in the high pressure safety injection system.

in any way to programmatic deficiencies in the maintenance Ibnctional organization. Activities included in INDUSTRIAL SAFETY ACCIDENT RATE. lNPO this category are maintenance, testing, surveillance, calibration and radiation protection. The indcator is deAned as the number of accidents per 200,000 man-hours worked for all utility personnel permanently assigned

5) Design / Construct 6onlinstallation/ Fabrication Problem -

to the staten that result in any of the following-This cause code covers a full range of programmatic deficiencies in the areas of design, construction,

1) One or more days of restncted work (excluding the day of installation, and fabrication (i.e, loss of enntrol power due the accident);

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

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

6) Equipment Failures (Electronic Piece-Parts or Environmental-Related Failures) This code is used for

3) Fatahties spunous failures of electronic piece-parts and failures due j

to meteorological conditions such as hghtning, ice, high l 78

PERFORMANCE lNDICATOR DEFINITIONS winds, etc. Generally, it includes spunous or one-trne MAXIMUM INDIVIDUAL RADIATION EXPOSURE failures. Electnc components included in tNs category are circut cards, rect 6ers, bestables, fuses, capacitors, diodes, The total maximum amourt of radiation received by an individual resistors, etc. person working at FCS on a monthly, quarterly, and annual basis. LOGGABLE#tEPORTABLE INCIDENTS (SECURITY) MWO PLANNING STATUS (CYCLE 17 REFUELING The total number of secunty incidents for the reporting month OUTAGE) depicted in two graphs. This indicator tracks secunty performance for SEP #58. The total number of Maintenance Work Orders that have been approved br hclusen in the Cycle 17 Refuehng Outage and the MAINTENANCE OVERTIME number that are ready to work (parts staged, planning complete, and al other paperwork ready for field use). Also included is the The percent of overtime hours compared to normal hours for number of MWOs that have been engineenng holds (ECNs, maintenance. This includes OPPD personnet as well as procedures and other miscellaneous engineering holds), parts contract personnel. hold,(perts staged, not yet inspected, parts not yet arnved) and planning hold (pb scope not yet completed). Maintenance Work MAINTENANCE WORKLOAD BACKLOGS Requests (MWRs) are also shown that have been identined for the Cycle 17 Refuenng Outage and have not yet been converted This indicator shows the backlog of non-outage Maintenance to MWOs Wbrk Orders remaining open at the end of the reporting month. Maintenance classifications are de Aned as follows: NUMER OF CONTROL ROOM EQUIPENT DEFICIENCIES Corrective Repair and restoraton of equipment or A controi rocin equipment deficiency (CRD) ls denned as any components that have failed or are malfunctioning and are not component which is operated or controlled from the Control performing their intended function. Room, provides indication or alarm to the Control Room, provides testing capabihties from the Control Room, provides Preventive Actions taken to maintain a piece of equipment automatic actons from or to the Control Room, or provides a witNn design operating conditions, prevent equipment failure, passive A,inction tbr the Control Room and has been identined as and extend its hfe and are performed pnor to equipment deAcient,l e., cbes not perform under all eonditions as designed failure. This deAnibon also apphes to the Altemate Shutdown Panels Al-179, Al-185, and Al-212. Non4orrective/ Plant improvements - Maintenance activtes performed to implement station improvements or to A plant component whch is de Acient or inoperable es considered repair non-plant equipment an" Operator Wbrk Around (OWA)ltem"if some other action is required by an operator to compensate for the condition of the Maintenance Work Priorities are deAned as: component. Some examples of OWAs are: Emergency - Conditions which significantly degrade station

1) The control room levelindicator doss not work but a local safety or availabihty.

sight glass can be read by an Operator out in the plant; immediate Action - Equipment deficiencies which

2) A dencient pump cannot be repaired because replacement signincantly degrade station reliabihty. Potential for unit parts require a long lead time for purchase /denvery, thus shutdown or power reduction.

requnng the redundant pump to be operated continuously; 5 Operations Concern - Equipment deficiencies which hinder

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

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

4) Deficient piart equipment that is required to be used during Non. Essential Routine corrective maintenance on non-Emergency Operating Procedures or Abnormal Operating essential station systems and equipment.

Procedures; Plant improvement Non-corrective maintenance and plant

5) System Indication that provides entical information dunng rnprovements normal or abnormal operations.

This indicator tracks maintenance performance for SEP #36, 79 4

s J i I PERFORMANCE INDICATOR DEFINITIONS NUhSER OF MSSED SURVEILLANCE TESTS RESULTING This indicator shows the status of the project-Mn ar-a the IN LICENSEE EVENT REPORTS scope of the Refueling Outage. The number of Surveillance Tests (STs) that result in Licensee PERCENTAGE OF TOTAL MWOs COMPLETED PER Event Repons (LERs) during the reporting month. This indcator MONTH IDENTIFIED AS REWORK 1 tracks missed STs for SEP #60 & 61. The percentage of total MWOs completed per month identified j OPEN INCIDENT REPORTS as rework. Rework activities are ident'fied by maintenance plannir g and craft. Rework is: Any adattional work required to j Thss indicator deplays the total number of open incident Reports correct deAcaencies discovered dr.ng a failed Post Maintenance (IRS), the number of irs that are greater than six months old and Testto ensure the component / system passes subsequent Post the number of open signrficant irs. Maintenance Test. OUTSTANDING MODIFICATIONS PERCENT OF COMPLETED SCHEDULED MAINTENANCE ACTIVITIES The number of Modi 6caten Requests (MRs) in any state between the issuance of a Modification Number and the The percent of the number of completed maintenance activities completon of the drawing update. as compared to the number of scheduled maintenance activities each month. This percentage is shown for all maintenance

1) Form FC.1133 Backlog /in Progress. This number cra fts. Also shown are the number of emergent MWOs.

represents modification requests that have not been plant Maintenance activities include MWRs MWOs, STs, PMOs, approved dunng the reponing month. cahbrations, and other miscellaneous activities This indcator tracks Maintenance performance for SEP #33

2) Modmcation Requests Being Rev6ewed. This category includes:

PERFORMANCE INDICATOR INDEX A) Modification Requests that are not yet reviewed This indicator index is calculated from a weighted combination of ten overperformance indcator values, which include Unit B) ModiAcation Requests being reviewed by the Nuclear Capability Factor, Unit Capabihty Loss Factor, HPSI, AFW, Projects Review Committee (NPRC). Emergency AC Power System, Unplanned Automatic Scrams, Collective Radiation Exposure, Fuel Rehaiblity, Thermal C) Modsfication Requests being rev'ewed by the Nuclear Performance, Secondary System Chernistry, Radiation Waste, Projects Committee (NPC). and industnal Safety Accident Rate. These Modification Requests may be reviewed several times PREVENTABLE / PERSONNEL ERROR LERs before they are approved for accomphshment or canceled. Some of these Modification Requests are retumed to This indcator is a breakdown of LERs. For purposes of LER 7 Engineenng for more information, some approved for evaluation, event classification, a " Preventable LER"is defined as: some approved for study, and some approved for planning Once planning a completed and the scope of the work is clearly An event for which the root cause is personnel error (i e., defined, these Modification Requests may be approved for inappropnate action by one or more individuals), inadequate accomplishment with a year assigned for construction or they administrative controls, a design construction, installation, may be canceled All of these different phases require review. Instalation, fabncaten problem (involving work completed by or supervised by OPPD personnel) or a maintenance problem I

3) Design Engineering Backlog!!n Progress. Nuclear (attributed to inadequate or irnproper upkeepNepair of plant Planning has assigned a year in which construct on will be equipment) Also, the cause of the event must have occurred completed and design work may be in progress.

wthin approximately two years of the " Event Date" specified in the LER (e g, an event for which the cause is attributed to

4) Construction Backlogiln Progress. The Construction a problem with the original design of the plant would not be Package has been issued or construction has begun but considered preventable).

the modification has not been accepted by the System Acceptance Commsttee (SAC) For purposes of LER event classification, a " Personnel Error" LER is defined as follows-i

5) Design Engmeenng Update Backloglin Progress. PED has received the Modificaten Completon Report but the An event for which the foot cause is inappropnate action on drawings have not beeri updated.

the part of one or more individuals (as opposed to being attnbuted to a department or a general group). Also, the The above mentened outstanding modificatens do not include inappropnate action must have occurred within approximately modifcatons whch are proposed for cancellation. two years of the " Event Date" specified in the LER. OVERALL PROJECT STATUS (REFUELING OUTAGE) 80

l 1 l PERFORMANCE INDICATOR DEFINITIONS Addtonely, each everr classtned as a " Personnel Error" should The number of Nuclear Plant Rehabikty Data System (NPRDS) also be classified as " Preventable." This indicator trends components with more than one failure and the number of l personnel performanco for SEP item #15 NPRDS components with more than two failures for the i eighteen-rnonth CFAR penod PRIMARY SYSTEM CHEMISTRY % OF HOURS OUT OF LIMIT SAFETY SYSTEM FAILURES The percent of hours out of limit are for six primary chemistry Safety system failures are any events or conditions that could pe.ameters divided by the total number of hours possible for the prevent the fulfillment of the safety functions of structures or month. The key parameters used are: Lithium, Chlonde, systems. If a system consists of multiple redundant subsystems Hydrogen, Dissolved Oxygen, Fluonde and Suspended Solds. or trains, failure of all trains constitutes a safety system failure. i EPRllimits are used. Failure of one of two or more trains is not counted as a safety system failure. The definiten for the indicator parallels NRC PROCEDURAL NONCOMPLIANCE INCIDENTS reporting requirementsin 10 CFR 50 72 and 10 CFR 50.73. The (MAINTENANCE) following is a hst of the rnaJor safety systems, sub-systems, and components monitored for this indicator: The number of identified incidents concerning maintenance procedural problems, the number of closed irs related to the Accident Monitonng Instrumentation, Auxiliary (and use of procedures tincludes the number of closed irs caused by Emergency) Feedwater System, Combustible Gas Control, j procedural noncompliance), and the number of closed Component Coohng Water System, Containment and procedurel noncomphance irs This indicator trends personnel Containmert isolation, Containment Coolant Systems, Control performance for SEP #15,41 and 44. Room Emergency Ventilaten System, Emergency Core Coohng

Systems, Engineered Safety Features i

PROGRESS OF CYCLE 17 OUTAGE MODIFICATION instrumentation, Essential Compressed Air Systems. PLANNING Essential or Emergency Service Water, Fire Detection or Suppression Systems, Isolaton Condenser, Low This indicator shows the status of modifications approved for Temperature Overpressure Protection, Main Steam Line completion dunng the Refuehng Outage. Isolation Valves, Onsite Emergency AC & DC Power w/Dtstnbution, Radiation Monitonng Instrumentation, Reactor PROGRESS OF 1996 ON-LINE MODIFICATION PLANNING Coolant System, Reactor Core isolation Cooling System, J Reactor Trip System and Instrumentaten, Recirculation Pump This indicator shows the status of modifications approved for Tnp Actuation Instrumentation, Residual Heat Removal i completion dunng 1995. Systems Safety Valves, Spent Fuel Systems, Standby Liquid Control System and Ultimate Heat Sink. RADIOLOGIC AL WORK PRACTICES PROGRAM SECONDARY SYSTEM CHEMISTRY PERFORMANCE The number of identified poor radiological work practices INDEX (PRWPs) for the reporting month. This indicator tracks radiological work performance for SEP #52. The Chemistry Performance Index (CPI)is a calculation based on the concentration of key impurities in the secondary side of RADIO OF PREVENTIVE TO TOTAL MAINTENANCE & the plant. These key impunties are the most hkely cause of PREVENTIVE MAINTENANCE ITEMS OVERDUE detenorationof the steam generators. Cntena for calculating the C PI are-The rate of preventNe maintenance (including surveillance testing and cahbration procedures) to the sum of non-outage

1) The plant is at greater than 30 percent power; and correctwe maritenance and preventwo maintenance completed over the reporting penod The ratio, expressed as a percentage,

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

is calculated based on man-hours. Also displayed are the percent of preventNe maintenance items in the month that were The CPI is calculated using the following equation: not completed or administratwely closed by the scheduled date plus a grace penod equalto 25% of the scheduled interval. This CPI = (sodium /0 90) + (Chloride /1.70) + (Sulfate /1.90) + indicator tracks preventive maintenance activities for SEP #41. (Iron /4 40) + (Copper /0 30)/5. RECORDABLE INJURY /lLLNESS CASES FREQUENCY Where: Sodium, sulfate and chlonde are the monthly average RATE biowdown concentrations in ppb, iron and copper are monthly time weighted average feedwater concentrations in ppb. The The number of injunes requinng more than normal first aid per denominator for each of the five factors is the INPO median 200,000 man-hours worked. This indicator trends personnel value. If the monthly average for a specific parameter is less performance for SEP #15,25 and 26. than the INPO median value, the median value is used in the calculation. REPEAT FAILURES 81 1

PERFORMANCE INDICATOR DEFINITIONS SIGNIFICANT EVENTS Tests, Maintenance Procedures, Calibration Procedures, Special Procedures or Operating Procedures are not SigniAcant events are the events ioentified by NRC staff through considered as temporary rnodshcations unless the jumper or detailed screenmg and evaluation of operating experience. The block remains in place after the test or procedure is screening process includes the daily review and discussion of complete. Jumpers and blocks installed in test or lab all reported operating reactor events, as well as other instruments are not considered as temporary modifications. opershonal data such as special tests or construction actuites. An event 6 dent:6ed fram the scree ung process as a signincant

3) Scaffold is not considered a temporary rnodification.

event candidate is Orther evaluated to do rmine if any actual or Jumpers and blocks which are installed and for whch MRs potential threat to the health 13d safety i f the public was have been submitted will be considered as temporary involved. Specific examples of the type of cntena are modifications until final resolution of the MR and the jumper summarized as follows: or block is rernoved or is permanentty recorded on the drawings. This indicator tracks temporary modificatens for

1) Degradation of important safey equipment; SEP #62 and 71.

2) Unexpected plant response to a transient; THERMAL PERFORMANCE

3) Degradation of fuel mtegnty, primary coolant pressure The ratio of the design gross heat rate (corrected) to the boundary, important associated features; adjusted actual gross heat rate, expressed as a percentage.

4) Scram with compication; UNIT CAPABILITY FACTOR

5) Unplanned release of radioactivity; The eatio of the available energy generation over a given time period to the reference energy generation (the energy that could

6) Operaton outside the limits of the Techncal Specifications; beproducedif the unit were operated continuously at full power under reference ambient conditions) over the same time penod,

7) Other, expressed as a percentage.

INPO significant events reported in this indicator are SERs UNIT CAPACITY FACTOR (signifcant Event Reports) which inform utilities of signancant events and lessons teamed identified through the SEE-IN The net electncal energy generated (MWH) duided by the product of manmum dependable capacity (net MWe) times the screerwng process. gross hours in the reporting penod expressed as a percent. Net SPARE PARTS INVENTORY VALUE electncal energy generated is the gross electrical output of the unit measured at the output terminals of the turbine generator The dotar value of the spare parts inventory for FCS dunng the minus the nomial station service loads dunng the gross hours of reporting penod. the reporting penod, expressed in megawatt hours. STAFFING LEVEL UNPLANNED AUTOMATIC REACTOR SCRAMS PER 7,000 CRITICAL HOURS The actual stamng level and the authortzed stafhng level for the Nuclear Operations Duisson, The Producten Engineenng Thisindcator is defined as the number of unplanned automatic Divison, and the Nuclear Services Duision. Tnis indicator scrams (reactor protection system logic actuations) that occur tracks performance for SEP #24 per 7,000 hours of cntical operation. STATION NET GENERAT10N The value for this mdcator is calculated by multiplying the total number of unplanned automate reactor serams in a specific time The not generation (sum) produced by the FCS dunng the period by 7,000 hours, then dividing that number by the total reporting month. number of hours entcalin the same time penod. The indicator is further deAned as follows: TEMPORARY MODIFICATIONS

1) Unplanned means that the scram was not an anticipated The number of temporary mechancal and electncal part of a planned test configurations to the plant's systems.

2) Scram means the automatic shutdown of the reactor by a

1) Temporary configurations are defined as electncaljumpers, rapid insertion of negatue reactivity (e g, by control rods, electncal blocks, mechanical Jumpers, or mechanical blocks liquid injection system, etc.) that rs caused by actuation of which are installed m the plant operating systems and are the reactor protection system. The scram signal may have not shown on the latest revision of the P&lD, schemate, resulted from exceeding a set point or may have been connection, winng, or flow diagrams.

spunous.

2) Jumpers and blocks whch are installed for Surveillance i

82 i i l

e PERFORMANCE INDICATOR DEFINITIONS l

3) Automate rneans thut the indial signal that eaused actuation This indicator is defined as the volume of low-level solid 1

of the reactor protecten system logic was provided from one radcactwe waste actually shipped for burial. This indicator also of the sensor's monotonng plant parameters and conditions, shows the volume of low-level radioactNe waste which is in rather than the manual scram switches or, manual turbine temporary storage, the amount of radioactrve oil that has been trip switches (or push-buttons) provided in the main control shipped off-site for processing, and the volume of solid dry

room, radioactNo Waste WhiCh has been shipped off-site for processing Low 4evel solid radioactwe waste consists of dry

4) Critca! means that during the steady-state condition of the active waste, sludges, resans, and evaporator bottoms generated reactor pnor to the scram, the effectNe multiplication (k,,)

as a result of nuclear power plant operation and maintenance. was essentially squalto one. Dry radcactue waste includes contaminated rags, cleaning matennis, disposable protectue clothing, plastic containers, and UNPLANNED CAPABILITY LOSS FACTOR any other material to be disposed of at a low-level radcactive waste deposal site, except resin, sludge, or evaporator bottoms. The rate of the unplanned energy losses dunng a given penod Lowlevel refers to all radioactwe waste that is not spent fuel or of time, to the reference energy generation (tM energy that a by-product of spent fuel processing This indicator tracks could be produced if the unit were operated continuously at full radiological work performance for SEP #54 power under reference ambient conditions) over the same time penod, expressed as a percentage. UNPLANNED SAFETY SYSTEM ACTUATIONS. (INPO + DEFINITION) This indicator is defined as the sum of the following safety system actuatons:

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

2) The number of unplanned emergency AC power system actuatioits that result from a loss of power to a safeguards bus An unplanned safety system actuation occurs when an actuaton set point for a safety system is reached of when a spunous or inadvertent signal is generated (ECCS only),

and major equipment in the system is actuated. Unplanned means that the system actuation was not part of a planned test or evoluten. The ECCS actuations to be counted are actuations of the high pressure injecten system, the low pressure injection system, of the safety injecten tanks. j UNPLANNED SAFETY SYSTEM ACTIONS -(NRC DEFINITION) The number of safety system actuations which include (gnl ) the j X High Pressure Safety injecten System, the Low Pressure Safety Infecton System, the Safety injection Tanks, and the lmergency Diesel Generators The NRC classification of safety system actuations includes actuations when major equipment is operated gns when the logic systems for the above safety systems are challenged VIOLATION TREND This indcator a defined as Fort Calhoun Stattun Cited Violations and Non-Cated Vlotatens trended over 12 months. Additionally, Cited Votations for the top quartile Region IV plant is trended over 12 months (lagging the Fort Calhoun Station trend by 2-3 months) It is the Fort Calhoun Station goal to be at or below the cited violation trend for the top quartile Region IV plant. VOLUME OF LOW-LEVEL SOLID RADIOACTIVE WASTE 83

SAFETY ENHANCEMENT PROGRAM lNDEX The purpose of the Safety Enhancement Program (SEP) Performance Indicators Index is to list performance indicators related to SEP items with parameters that can be trended. SEP Reference Number 15 Egga . Increase HPES and IR Accountability through use of Performance Indicators Procedural Noncompliance incidents (Maintenance) 52 Recordable injury / Illness Cases Frequency Rate.. .4 Clean Controlled Area Contarninations >1,000 Disintegrations /Minuto Per Probe Area .5 Preventable / Personnel Error LERs.,. 6 SEP Reference Number 24 . Complete Staff Studies Staffing level...... 45 SEP Reference Numbers 25. 26. & 27 . Training Program for Managers and Supervisors implemented . Evaluate and Implement Station Standards for Safe Work Practice Requirements . Implement Supervisory Enforcement of industrial Safety Standards Disabling injury / Illness Frequency Rate ... 3 Recordable lnjuryllliness Cases Frequency Rate .4 l SEP Reference Number 31 . Develop Outage and Maintenance Planning Manual and Conduct Project Management Training MWO Planning Status (Cycle 17 Refueling Outage) 69 Overall Project Status (Cycle 17 Refueling Outage).. 70 Progress of Cycle 17 Outage Modification Planning ....... 71 l I SEP Reference Number 33 . Develop On-Line Maintenance and Modification Schedule Percent of Completed Scheduled Maintenance Activities (All Maintenance Crafts) 53 SEP Reference Number 36 . Reduce Corrective Non-Outage Backlog Maintenance Workload Backlogs (Corrective Non-Outage) . 48 SEP Reference Numbers 41 & 44 . Develop and implement a Preventive Maintenance Schedule . Compliance With and Use of Procedures Ratio of Preventive to Total Maintenance & Preventive Maintenance items Overdue .....49 Procedural Noncompliance incidents (Maintenance). 52 SEP Reference Number 46 . Design a Procedures Control and Administrative Program 84

SAFETY ENHANCEMENT PROGRAM INDEX Document Review 58 SEP Reference Number 52 Eggt . Establish Supervisory Accountability for Workers Radiological Practices Radiological Work Practices Program. 57 SEP Reference Number 54 . Complete implementation of Radiological Enhancement Program Clean Controlled Area Disintegrations >1,000 Counts / Minute Per Probe Area 5 Collective Radiation Exposure. . 17 Volume of Low-Level Solid Radioactive Waste.... . 38 Contaminated Radiation Controlled Area 56 SEP Reference Number 58 . Revise Physical Security Training and Procedure Program Loggable/ Reportable incidents (Security) 59 SEP Reference Numbers 60 & 61 . Improve Controls Over Surveillance Test Program . Modify Computer Program to Correctly Schedule Surveillance Tests Number of Missed Surveillance Tests resulting in Licensee Event Reports 21 SEP Reference Number 62 . Establish interim System Engineers Temporary Modifications 60 Engineering Assistance Request (EAR) Breakdown 62 Engineering Change Notice Status 63 Engineering Change Notices Ooen . 64 SEP Reference Number 68 . Assess Root Cause of Poor Operator Training and establish means to monitor Operator Training License Operator Requalification Training 66 License Candidate Exams.. 67 SEP Reference Number 71 . Improve Controls over Temporary Modifications Temporary Modifications 60 85

REPORT DisTRisuriow I.isr R. L. Andrews P. A. Mruz K. L. Belek Nuclear Licensing B. H. Biome & Industry Affairs (8) C. E. Boughter J. T. O'Connor C. J. Brunnert W. W. Orr C. A. Carlson T. L. Patterson G. R. Cavanaugh R. J. Phelps J. W. Chase W.J.Ponec A. G. Christensen C. R. Rice O. J. Clayton A. W. Richard R. G. Conner D. G. Ried J. L. Connolley T.G.Ronne G. M. Cook M. J. Sandhoefner S. R. Crites F. C. Scofield D. W. Dale H. J. Sefick D.C.Dietz C. F. Simmons T. R. Dukarski E.L.Skaggs M. L. Ellis J. L. Skiles H. J. Faulhaber F. K. Smith M. T. Frans R. D. Spies (2) S. K. Gambhir D. E. Spires J. K. Gasper R. L. Sorenson W. G. Gates K. E. Steele S. W. Gebers M. A. Tesar L. V. Goldberg J.J.Tesarek D. J. Golden J. W. Tills D. C. Gorence D. R. Trausch R. H. Guy J. M. Waszak A. L. Hale G. R. Williams K. R. Henry S. J. Willrett J. B. Herman T. L. Herman K. C. Holthaus L. P. Hopkins l C.K. Huang R. L. Jaworski R. A. Johansen J. W. Johnson W. C. Jones D. D. Kloock J. B. Kuhr (5) L.T.Kusek M. P. Lazar B. R. Livingston D. L. Lovett N. L. Marfice T. J. Mcivor K. G. Melstad K. A. Miller 86

l a 1 FORT CALHOUN STATION OPERATING CYCLES AND REFUELING OUTAGE DATES EVENT DATE RANGE PRODUCTION (MWH) CUMULATIVE (MWH) Cycle 1 09/26/73 -02/08/75 3,299,639 3,299,639 1st Refueling 02/08/75-05/1165 Cycle 2 05/11/75 -10/01/76 3,853,322 7,152,961 2nd Refueling 10/01/76-12/13/76 Cycle 3 12/13/76 -09/30/77 2,805,927 9,958,888 3rd Refueling 09/30/77-12/09/77 Cycle 4 12/09/77-10/13/78 3,026,832 12,985,720 4th Refueling 10/13/78-12/24/78 Cycle 5 12/24/78 -01/18180 3,882,734 16,868,454 5th Refueling 01/18180 - 06/11/80 Cycle 6 06/11/80 -09/18181 3,899,714 20,768,168 6th Refueling 09/18/81 -12/21/81 Cycle 7 12/21/81 -12/03/82 3,561,866 24,330,034 7th Refueling 12/03/82-04/06/83 Cycle 8 04/06/83 -03/03/84 3,406,371 27,736,405 8th Refueling 03/03/84-07/12/84 Cycle 9 07/12/84 -09 28I85 4,741,488 32,477,893 9th Refueling 09/28/85 - 01116/86 Cycle 10 01/16/86-03'07/87 4,356,753 36,834,646 10th Refueling 03/07/87-06/38/87 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 l Cycle 14 05/03/92-09/25/93 4,981,485 56,022,013 14th Refueling 09/25/93 -11/26/93 Cycle 15 11/26/93-02/20/95 5,043,887 61,065,900 15th Refueling 02/20/95-04/14/95 I FORT CALHOUN STATION CURRENT PRODUCBON AND OPERAVONS " 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 Shortest Refueling Outage (52 days) Feb. 20,1995-April 14,1995 OPCYCLES. TEM M95 _ _ _ _ - _ _ _ _ _ - _ _ _ _ _ _ _ _ _ _.}}