Text

Performance Indicators,Nov 1994
	ML20079A822
Person / Time
Site:	Fort Calhoun
Issue date:	11/30/1994
From:	; OMAHA PUBLIC POWER DISTRICT
To:	;
Shared Package
ML20079A813	List: LIC-94-0256, Forwards Fort Calhoun Station Performance Indicators for Nov 1994; ML20079A822;
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	NUDOCS 9501040092
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{{#Wiki_filter:._ i ~ OMAHA PUBLIC POWER DISTRICT FORT CALHOUN STATION PERFORMANCE INDICATORS REPORT 4 4 C i Prepared By: Production Engineering Division System Engineering Test and Performance Group i s NOVEMBER 1994 B

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FORT CALHOUN STATION NOVEMBER 1994 MONTHLY OPERATING REPORT OPERATIONS

SUMMARY

i During the month of November 1994, Fort Calhoun Station (FCS) operated at a nominal 100% power with the exception of the three short term downpower evolutions described later in this summary. Normal plant maintenance, surveillance, and equipment rotation activities occurred during the month, in addition to scheduled online modification activities. Radiation Monitor RM-043 (noble gas ratemeter) was declared inoperable on November 1,1994, for modification work. Daily grab sampics were taken to compensate for the out-of-service monitor. RM-043 was declared operable on November 29 and returned to service. On October 25, Emergency Diesel Genera:or No. 2 base and day tank oil was determined to have particulate concentrations above specifications above the FCS administrative limits. Filters were installed under Temporary Modification 94448. Particulate levels returned to normal and on November 4, the temporary modification was removed. On November 5, power was reduced to 95% for performance of Moderator Temperature Coeffi-cient (MTC) testing. l On November 8, a four-hour report was made to the NRC pursuant to 10 CFR 50.72, due to de-termination of a design basis weakness associated with the ability to move a heavy load over the Raw Water Pump Vault. On November 14, Channels A r.nd B Offsite Power low Signal (OPLS) relays were declared in-operable due to a Component Cooling Water (CCW) system design basis concem with a postu- ) lated large-break Loss of Coolant Accident or Main Steam Line Break inside containment. Evaluation indicates that under certain conditions post-accident CCW temperature could rise to a ~ point at which the Control Room Air Conditioning (CR/AC) unit Freon compressors would shut-down, possibly followed by failure of rupture discs and release of the Freon from the units. Ris-ing Contml Room temperatures could subsequently hinder Operations personnel and possibly re-sult in design temperaures being exceeded for safety-related electrical equipment in the Control Room cabinets. Based on declaring the OPLS relays inoperable, Technical Specification (TS) 2.15(3) was entered, which requires the plant to be in Hot Shutdown within 12 hours. At 1455 hours, the Shift Supervisor declared a Notice of Unusual Event (NOUE) based on entry into a TS Limiting Condition for Operation (LCO) requiring plant shutdown. The technical content of a draft Safety Analysis for Operability (SAO) was accepted. Based on compensatory actions iden-tified in Operations Memorandum 94-07, CCW to one of the CR/AC units was isolated and both [ channels of OPLS were declared operable. The NOUE was terminated at 1950 hours, and the ( plant was retumed to 100% power. Following motor cleaning on November 21, Condensate Pump FW-2A was run for approxi-mately three minutes It was noted that the mechanical seal was overheating and the pump was immediately shutdown. An investigation has concluded that alignment problems caused the pump seal bushing to overheat. Repairs were in progress at the end of the month. i

FORT CALHOUN STATION NOVEMBER 1994 MONTHLY OPERATING REPORT i OPERATIONS

SUMMARY

(enntinneA) On November 29, a ground on 480 VAC Motor Control Center MCC-4A3 caused the Feeder Breater to MCC-4A1 to trip open. De ground was isolated to cutting equipment being used for the disassembly of discarded Spent Fuel Pool reracks. His event caused entry into several TS LCOs. MCC-4A1 was re-energized and the LCOs were cleared after the ground was isolated. On November 29 at 2116 hours, the "B" 120 VAC Instrument Inverter swapped power supply to the bypass transformer. Due to the failure of the instrument inverter, TS 2.7.2 (h) was entered with an 8-hour time limit. At 0501 hours on November 30, a NOUE was declared due to a TS required shutdown since the inverter could not be returned from the bypassed condition within the 8-hour LCO limit. Repairs were completed and the instrument bus and inverter were declared operable at 0650 hours, clearing TS 2.7.2 (h). At 0730 hours, the NOUE was terminated and the plant was later returned to 100% power. The following Licensee Event Report (LER) was submitted during this reporting period: I FR No. LER Date Description ) 94-007 11/07/94 Raw Water Pump Seal Water Supply Outside of Design Basis Source: Nuclear Licensing & Industry Affairs t W ll

l Year-To-Date Valra Performance Catecories 1 . lMlGlMlk ys b MlWl1 d a Performance in Industry Unplanned WN h Thermalgk Upper 10% and better Unit l I WA* Automatic ~~~.d M than 1994 OPPD goal Capability ,,II . (SciamerTJ)OOL :/% -[p W ^ tids Factor MQ L. ! THours~CrtIIce lf 3s iri ] Performance Better Than lI _l ! 9~h $ 39 @ _II --,e u w au.== .WlW M 1, ~: 1994 OPPD Goal l ll lllll I II I!

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W Se EDC :Saiety ~"' Performance Not Meeting th1tep l th1steeg , ; RollabillNP-1994 OPPD Goal 4 N himmer IWkerrusrce L, Indicator a ' Pe o ir. pg -a ~ 7 Ss 'hh{-- -- % } l _ - (( r August September October -.< l' l l _l ' ( 94 34 94 + l l! i Cie str~y Collective Velurneof ?' I 8g h n Radiation LOUPL8Wel ' l M November Exposure ' Hedoective:' <' q , J' m ". ~ ' h6 Year-To-Date 3994 e Nst Possp + ~- Value 1994 Year-End Performance INPO PERFORMANCE INDICATORS (Performance for the months of January through November 1994) =

i n 7 w w: Scremst critical Year-To-Date Value Performance Cateaories ] l l l llll 3 Performance Better Than Industry Average Trend Selety SignMicant System Events Actuatkms b Performance Better Than 1994 OPPD Goal I ,fas, ) du . +- !) ] Performance Not Meeting 1994 OPPD Goal or ( %glMl1dl??l ;d 5 %_, J Industry Average Trend g jg Forced J#ii; $ h f - Outage - 1]Fallures 9 Rete ~ m g s {w a m t+rsar~"b MQpj*gg C August September October

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y y 94 November 1994 Equipment Year-To-Date Forced Collective Value Best Poss% Outages /1,000 Radletion Performance 1994 Year-End } Crit. Hrs. Exposure Performance NRC PERFORMANCE INDICATORS (Safety System Failures and Significant Events ratings are averages for April 1991 through March 1994. Predictor blocks cannot be generated for these performance indicators because they are based on NRC biannual reports. All other indicator values are for the months of January through November 1994.) a -.~

FORT CALHOUN ' STATION PERFSRMANCE INDICATORS REPORT NOVEMBER 1994 -

SUMMARY

POSITIVE TREND REPORT A pedormance indicator with data representing three Primary Svalam Chamstry Parcant of Hours Out of Umit consecutsve months of improving periormance or three (Page 39) consecutwo months of performance that is supenor to the stated goalis exhibihng a positwo trend per Nuclear Secondant Swatam Chamistry Operations Division QuaHey Procedure 37 (NOO-OP 37). (Page 40) The following performance indicators exhbited positive Canta Per Kilowatt Hour trends for the reportin0 month: (Page 42) Ratan of Preventive to Total Maintenance & Preventive Daabhng iniurv/lunana Fraouancy Rata (Lost Time Acci. Maintenanca llama overdue dont Rata) (Page 47) (Page 3) in-Line Chamistry Instruments Out of Servica Recordable iniurv/llinana Canas Frequency Rata (Page 52) (Pa0*4) Hazardous Wanta Produced 1 Hmh Preasure Safety inWn Swatam Safety Swatam (Page 53) Performance (Pa0e8) Contaminated Radiahon Controlled Area .l (Page 54) Auxlharv Feedwater Syntam Safety Swatam Performance (Page 9) J End of Positive Trend Report. Emergency AC Power Svatam Safety Svatam Perfor-El80GR I (Page 10) Emerpancy Damal Ganarator Una Rahabdtv ADVERSE TREND REPORT (Page 11) l A Performance indicator with data representing 3 con-Donal Generator Rahabilmv (25 Demanda) secutive months of declining performance; or four or. (Page 12) more consecutive months of performance that is trending towards declining as determined by the Manager - Sta-Emerpancy Dannel Generator Unrahabday tion Engineering, constitutes an adverse trend per NOD-(Page 13) op.37. A supervisor whose performance indicator ex-hbits an adverse trend by this definition may specify in Number of Mamed Surveillance Tanta Resulting in Lic-written form (to be published in this report) why the trend i annan Event Ranorts is not adverse. (Page 20) The followng performance indicator exhibited an ad-t Forced Outana Rata verse trend for the reporting month: (Page 23) Unit Canacity Factor Fuel Rahabiktv Indacator (Pa0e24) (Pa0* 14) An adverse trend is indicated based on the FRI value for Unit Canabihty Factor the reporting month exceeding the 1994 Fort Calhoun (Page 26) monthly goal of less than 5.0 X 10*, and the potential for 1 or 2 defective fuel rods in the core. Unolannad Canabilty Loan Factor (Page 27) Thermal Padormance (Page 32) Enumment Forced Outanen Per 1.000 Critu:a! Hours An adverse trend is indicated based on declining perfor-(Pa0e 34) mance in recent months. d End of Adverse Trend Report. V j

FORT CALHOUN STATION PERFORMANCE INDICATORS REPORT NOVEMBER 1994 -

SUMMARY

INDICATORS NEEDING INCREASED MANAGEMENT ATTENTION REPORT u ' A performance indumtor with data for the reporting period Tamancarv Modifestens that is inadequate when compared to the OPPD goal is (Page 58) -J defined as "Needing increased Management Attention

The temporary modificaten associated with the surface per NOOCP-37.

sluice line (which is removable on-line) is greater than 6 months old and, therefore, exceeds the 1994 goal. The following performance indicators are cited as need- - ing increased management attention for the reporting month: End of :.hr+;..st Attention Report. Number of Control Room Eauiomant Dahciencima (Page 15) ) The total number of control room equpment dehciences at the end of the reporting month has exceeded the 1994 Fort Calhoun monthly goal of $46 since July 1994. PERFORMANCE INDICATOR REPORT IMPROVEMENTS / CHANGES Valations Per 1.000 Inanschon Hours (Page 18) The number of NRC violations per 1,000 inspection This section lists significant changes made to the report hours has exceeded the Fort Calhoun goal of 51.4 since and to specific indicators within the report since the pre. Merch 1994 vious month Unolanned Automahc Randor Scrams Per 7.000 Hours NRC Annunciator Window ] g (Page 28) (Page iv) i The number of unplanned automatic reactor scrams por The block representing equpment forced outages per 7,000 hours critical has exceeded the Fort Calhoun goal 1,000 critical hours has been revised to show that perfor-of 0 since February 1994. There have been no mance has been better than the induerry average trend for the lost 4 months. unplanned automatic reactor scrams since February i 1994. Unolanned Safety Syntam Actuabona -(NPO Definiten) Repo (Page 29) The number of INPO unplanned safety system actua-tions has exceeded the Fort Calhoun goal of 0 since February 1994. There have been no INPO unplanned safety system aduations since February 1994. Unolanned Safety Swatam Actuations -(NRC Defmition) (Page 30) The nurnber of NRC unplanned safety system actuations has exceeded the Fort Cdhoun goal of 0 since February 1994. There have been no NRC unplanned safety sys-tem actuations since February 1994. Maintenance Worldnad Baddons (Page 46) t The backlog of non outage MWOs for corrective mainte-i nance has exceeded the 1994 monthly goal of a maxi- ,, j mum of 400 since August 1994. l Mantanance Overtime 1 (Page 49) J The percent of overtime hours with respect to normal i hours for the reporting month (12.11%) exceeds the 1994 monthly on line goal of s105 l Vi

Tabl@ of Cont;nts/ Summary eaaE QQ&LE.. ..........................XI o SAFE OPERATIONS EAGE NDUSTRIAL SAFETY ACCDENT RATE - INPO .................................,.......... 2 t DISABLING INJURY /lLINESS FREQUENCY RATE. 3 RECORDABLE INJURY /lLLNESS CASES FREQUENCY RATE...... ............................................4 CLEAN CONTROLLED AREA CONTAMINATIONS 21,000 DISINTEGRATIONS / MINUTE PER PROBE AREA.... .............5 PREVENTABLE / PERSONNEL ERROR LERs... ...................6 SAFETY SYSTEM FAILURES....... ....................................... 7 SAFETY SYSTEM PERFORMANCE: HIGH PRESSURE SAFETY INJECTION SYSTEM. 8 AUXILIARY FEEDWATER SYSTEM............ .9 EMERGENCY AC POWER SYSTEM.. ..........~.............. -............ 10 EMERGENCY DIESEL GENERATOR UNIT RELIABILITY........ ..................~....................11 EMERGENCY DIESEL GENERATOR RELIABILITY (25 DEMANDS). ...... 12 EMERGENCY DIESEL GENERATOR UNRELIABill1Y... ..................13 FUEL RELIABILITY INDICATOR 14 NUMBER OF CONTROL ROOM EQUIPMENT DEFICIENCIES -- ...........-..............................15 COLLECTIVE RADIATION EXPOSURE. 16 MAXIMUM INDIVIDUAL RADIATION EXPOSURE......................... 17 VIOLATIONS PER 1,000 INSPECTION HOURS.. ........................................-... 18 SIGNIFICANT EVENTS...-... .. 19 NUMBER OF MISSED SURVEILLANCE TESTS RESULTING IN LERS................................... 20 PERFORMANCE EAGE STATION NET GENERATION......... ..... 22 FORCED OUTAGE RATE...... .... 23 UNIT CAPACITY FACTOR.,... 24 = vil

t I o;...u (continued) f2GE ^ 4 EQUIVALENT AVAILABILITY FACTOR .............. 25 ~! UNIT CAPA81LITY FACTOR ........_..__.__......._....26-UNPLANNED CAPABILITY LOSS FACTOR............ ............................... 27 ,j i UNPLANNED AUTOMATIC REACTOR SCRAMS PER 7,000 HOURS CRITICAL. _-.._ ...~.._........~..._._....__.28_ UNPLANNED SAFETY SYSTEM ACTUATIONS - (INPO DEFINITION)...... ... 29 UNPLANNED SAFETY SYSTEM ACTUATIONS - (NRC DEFINITION) .... 30 GROSS HEAT RATE ................-...................31 l THERMAL PERFORMANCE........... . 32 l 5 DAILY THERMAL OUTPUT...... =.............33 .t EQUIPMENT FORCED OUTAGES PER 1,000 CRITICAL HOURS..........._............-...... ... 34 l --= COMPONENT FAILURE ANALYSIS REPORT (CFAR)

SUMMARY

35 t REPEAT FAILURES... ......................._..._.................36 CHECK VALVE FAILURE RATE.......~..... ......... 37 i t t VOLUME OF LOW-LEVEL SOLID l' RADIOACTIVE WASTE 38 PRIMARY SYSTEM CHEMISTRY PERCENT OF HOURS OUT OF L1MIT.... -- ............ 39 r CHEMISTRYINDEX/ SECONDARY SYSTEM CHEMISTRY.......... -- _.40 GQS.I PEaE [ I CENTS PER KILOWATT HOUR. .....,.........._.42 STAFFING LEVEL................._.. .. 43 SPARE PARTS INVENTORY VALUE....._................. .....................44 s: i [..: DIVISION AND DEPARMIENT PERFORMANCE INDICATORS PEaE MAINTENANCE WORKLOAD BACKLOGS (CORRECTIVE NONOUTAGE)...._.......- .......... 46 t i i viii r .f

J l DIVISON AND DEPARTMENT PERFORMANCE NDICATORS (continued) ISQE RATO OF PREVENTIVE TO TOTAL MAINTENANCE & PREVENTIVE MANTENANCE ITEMS OVERDUE.................... 47 PERCENTAGE OF TOTAL MWOs COMPLETED PER MONTH DENTIFIED AS REWORK..... 48 l MAINTENANCE OVERTIME ..... 49 PROCEDURAL NONCOMPLIANCE INCOENTS (MAINTENANCE).. .... 50 PERCENT OF COMPl.ETED SCHEDULED MAINTENANCE ACTIVITIES (ALL MANTENANCE CRAFTS).... ..... 51 IN-LNE CHEMISTRY INSTRUMENTS OUT-OF-SERVICE ... 52 HAZARDOUS WASTE PRODUCED........... 53 CONTAMINATED RADIATON CONTROLLED AREA........ .54 RADIOLOGICAL WORK PRACTICES PROGRAM........................... ....................55 DOCUMENT REVIEW 56 LOGGABLEMEPORT A8LE INCIDENTS (SECURITY). .. 57 TEMPORARY MOOFCATIONS.... ~ ... 58 OuTSTANDNG WOOF CATONS.,..... ................59 ENGINEERHG AS$tSTANCE REQUEST (EAR) BREAKDOWN. . 60 ENGINEERmG CHANGE NOTICE STATUS............... 61 ENGINEERNG CHANGE NOTICES OPEN............. . 62 LER ROOT CAUSE BAE AKDOWN......... . 63 LICENSED OPE RA TOR REQUALIFICATION TRAINING..................... . 64 .65 LICENSE CANDOATE EKAMS....... OPEN CORRECTIVE ACiON REPORTS AND INCIDENT REPORTS....... 66 MWO PLANNWG ST ATUS (CYCLE 16 REFUELING OUTAGE).. ... 67 OVERALL PROJE C 7 ST ATUS (CYCLE 16 REFUELING OUTAGE)..... ...... 68 PROGRESS OF CYCLE 16 OUTAGE MODIFICATION PLANNING . 69 i PROGRESS OF t 994 ON LNE MODIFCATON PLANNING....... .70 ix

ACTDN PLANS. DEFNITIONS. SEP NDEX & DISTRBUTION LIST EeCaE ACTON PLAN S ..... -.............-.....-...... ~.......... . 71 i PERFORMANCE INDICATOR DEFNITIONS................. ..................................74 -1 SAFETY ENHANCEMENT PROGRAM NDEX.. ................-...... 81 1 I REPORT DISTRIBUTDN LIST ................~... .................. 83 1 i l l 1 I ? s h l 1 I I 1 I I I I i I e Mi l l l i l 4 X l l i I

OPPD NUCLEAR ORGANIZATION GOALS Vice President - 1994 Priorities MISSION The safe, reliable and cost effective generation of electricity for OPPD customers through the professional use of nuclear technology. The Company shall conduct these operations prudently, efficiently and effectively to assure the health, safety and protection of all personnel, the general public and the environment. faDALS Gant 1: SAFE OPERATIONS To ensure the continuation of a " safety culture" in the OPPD Nuclear Program and to pmide a professional working environment, in the control room and throughout the OPPD nuclear organi-zation, that assures safe operation so that Fort Calhoun Station is recognized as a nuclear indus-try leader. 1994 Priorities: 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. Goal 2: PERFORMANCE To strive for Excellence in Operations utilizing the highest standards of performance at Fort Calhoun Station that result in safe, reliable plant operation in power production. 1994 Priorities: 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. Goal 3: COSTS Operate Fort Calhoun Station in a manner that cost effectively maintains nuclear generation as a viable source of electricity. 1 l' 1994 Priorities: Maintain total O & M and Capital expenditures within budget. Streamline work processes to improve cost effectiveness. 1 Goals Source: Scofield (Manager) i xi I l

t I t l l SAFE OPERATIONS 1 Goal: To ensure the continuation of a " safety culture" in the i OPPD Nuclear Program and to provide a professional work-t i ing environment in the control room and throughout the OPPD Nuclear Organization that assures safe operation so that Fort Calhoun Station is recognized as a nuclear indus-try leader. e b l

- e-Year-to-Date INPO hxfustrial Safety Accident Rate - O-- Fort Calhoun Year-Erxl Goal ( 0.50) 1 GOOD l 1.8 - -D-Industry Upper 10% V 1.6 - -e-- 1995 INPO Industry Goat ( 0.50) 1.4 - 1.2 - i 1-0.8 - 0.6 - g 3 u a g 0.2 - C C C C C O O O O O O O Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 INDUSTRIAL SAFETY ACCIDENT RATE-INPO As stated in INPO's December 1993 publication ' Detailed Descriptions of World Asso-ciation of Nuclear Operators (WANO) Performance indicators and Other Indicators for Use at U.S. Nuclear Power Plants': "The purpose of this indicator is monitor progress in improving industrial safety performance for utility personnel permanently assigned to the station." The INPO industrial safety accident rate value year-to-date was 0.45 at the end of November 1994. The value for the 12 months from December 1,1993 through Novem-ber 30,1994 was 0.42. There were no restricted-time or lost-time accidents in November. There has been 1 restricted-time accident and 2 lost-time accidents in 1994. The values for this indicator are determined as folk:ws: (number of restricted-time accidents + lost-time amidents + fatalities) X 200.000 (number of station person-hours worked) The 1994 Fort Calhoun year-end goalis 50.50. The 1995 INPO industry goal is s0.50. 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 G.;&r&ger/ Source) Accountability: Chase /Ccaner Adverse Trend: None 2

+ 1994 Disabling injury / Illness Frequency Rate l Dl -M-1993 Disabling injury /lliness Frequency Rate V - O-Fort Calhoun Year End Goal ( 0.5) 1.2 - 1 l 1-l 0.8 - I b ^ ^ ^ ^ ^ C y" " 'T " l 0.2 - 0 i Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 l l DISABLING INJURY /lLLNESS FREQUENCY RATE (LOST TIME ACCIDENT RATE) This indicator shows the 1994 disabling injury / illness frequency rate. The 1993 dis-abling injury / illness frequency rate is also shown. The disabling injury / illness frequency rate year-to-date was 0.30 at the end of Novem-ber 1994. There were no lost-time accidents reported for the month. There have been 2 lost-time accidents in 1994. The disabling injury / illness frequency rate for the 12 months from December 1,1993 through November 30,1994 was 0.28. The 1994 Fort Calhoun year-end goal for this indicator is a maximum value of 0.5. Data Source: Sorenson/Skaggs (Manager / Source) Accountability: Chase / Conner Positive Trend SEP 25, 26 & 27 4 ) l 3 1994 Recordable injury / Illness Frequency Rate --M-1993 Recordable injury / Illness Frequency Rate I GEI 2.5 - V -O-- 1994 Fort Calhoun Year-End Goal ( 1.5) 2.25-2- 1.75 - 1.5 - C O ^ ^ ^ ^ ^ ^ ^ ^ v v v v v v v v 1.25-1- ^ 0.75-0.5 - 0.25-0 Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 I RECORDABLE INJURY / ILLNESS CASES FREQUENCY RATE This indicator shows the 1994 recordable injury / illness cases frequency rate. The 1993 recordable injury 4tiness cases frequency rate is also shown. A recordable inpry4tiness case is reported if personnel from any of the Nuclear Divi-sions are injured on the job and require corrective medical treatment beyond first aid. The recordable inpry4tiness cases frequency rate is computed on a year-to-date basis. The recordable inpryAliness cases frequency rate year-to-date was 1.05 at the end of November 1994 There were no recordable injury / illness cases reported for the month of November. There have been 7 recordable injury / illness cases in 1994. The recordable inpryAliness cases frequency rate for the 12 months from December 1, 1993 through November 30,1994 was 0.98. The 1994 Fort Calhoun year-end goal for this indicator is a maximum value of 1.5. Data Source: Sorenson/Skaggs (Manager / Source) Accountability: Conner Positive Trend SEP 15,25,26 & 27 4

Contaminat' n Events e l GOOD l -O-Fort Calhoun Year-End Goal ( 54) V 60-55-C O O O O O O O O O O O I 50-45-f40-5 35-B 30-25-320-15-10-5- ~ l 0 i i i i i i i i i i i i Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 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. This includes the contamination events associated with the spent fuel rerack project. There was 1 contamination event in November 1994. There has been a total of 42 contamination events in 1994. Tne 1994 year-end goal for this indicator is a maximum of 54 contamination events. Data Source: Chase /Little (Manager / Source) i Accountability: Chase /Lovett Adverse Trend: None. To exceed the year-end goal of a maximum of 54 contamination events,13 additional contamination events would have to occur in the last month of 1994. Based on a projected rate of approximately 4 events per month, the Station total will be 46 contamination events at the end of the year and the goal will be met. SEP 15 & 54 5

_ - _ _ _ Preventable (18 Month Totals) -D-Personnel Error (18 Month Totals) E Personnel Errors (Each Month) 40-35-30-25-20-E 15-g== ~ 10-5- 0 i i i i i i i i i i i i i iii $k $kbhhhb55$kE $$f 2 o PREVENTABLE / PERSONNEL ERROR LERs This indicator depicts 18 month totals for numbers of " Preventable" and " Personnel Error" LERs. The graph shows the 18 month totals for preventable LERs, the 18 month totals for Personnel Error LERs and the Personnel Error totals for each month. The LERs are trended based on the LER event date as opposed to the LER report date. In October 1994, there was 1 event that was subsequently reported as an LER. No LERs were categorized as Preventable or as Personnel Error. The total LERs for the year 1994 (through October 31,1994) is 7. The total Personnel Error LERs for the year 1994 is 2. The total Preventable LERs for the year is 2. The 1994 goals for this indicator are that the year-end values for the 18-month totals be no more than 12 Preventable and 5 Personnel Error LERs. (Note: Because this indica-tor is based on an 18-month period, the 1994 year-end totals will include LERs occur-ring in 1994 and the last 6 months of 1993.) Data Source: Trausch/Cavanaugh (Manager / Source) Accountability: Chase Adverse Trend: None SEP 15 6

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

1994 Monthly High Pressure Safety injection System g UnavailabilityValue 1994 Year-to-Date High Pressure Safety injection System Unavailability Value l GOOD l O 1994 Fort Calhoun Goal ( 0.004) V - 1995 INPO industry Goal (0.02) --O-industry Upper 10% (0.0011) 0.03-0.025-0.02-A A A 'A A A A E A A A 0 4 0.015 - O.01 - 0.005-0.00036 pg q g g g ,y q i i -i-i i-i i i i e i i i i 1993 Unavailability Value Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 HIGH PRESSURE SAFETY INJECTION SYSTEM SAFETY SYSTEM PERFORMANCE This indicator shows the High Pressure Safety injection System unavailability value, as defined by INPO in the Safety System Performance Indicator Definitions, for the report-ing month. The High Pressure Safety injection System unavailability value for the month of Novem-ber 1994 was 0.0004. There was 0.93 of an hour of planned unavailability for surveil-lance tests, and no hours of unplanned unavailability, during the month. The 1994 year-to-date HPSI unavailability value was 0.0024 at the end of the month. The unavailability value for the last 12 months was 0.0023. There has been a total of 58.41 hours of planned unavailability and no hours of unplanned unavailability for the HPSI system in 1994. The 1994 Fort Calhoun year-end goal for this indicator is a maximum value of 0.004. The 1995 INPO industry goal is 0.02 and the industry upper ten percentile value (for the three year period from 7/91 through 6/94) is approximately 0.001. Data Source: Jaworski/Schaffer Accountability: Jaworski/Schaffer Positive Trend 8

E Monthly Auxiliary Feedwater System Unavailability Value 1994 Year-to-Date Auxiliary Feedwater System

UnavailabilityValue

-O-1994 Fort Calhoun Goal (0.01) lGOODI " 1995 INPO Industry Goal ( 0.025) O Industry Upper 10%(0.0021) I 0.025-a a a a a a a a a a a a 0.02-0.01 5 - 0 01 - C O O O O O O O O O O O I 1 1 i 1993 Unavadatety vaus Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 l AUXILIARY FEEDWATER SYSTEM SAFETY SYSTEM PERFORMANCE This indicator shows the Auxiliary Feedwater System Unavailability value, as defined by INPO in the Safety System Performance Indicator Definitions, for the reporting month. The Auxiliary Feedwater System Unavailability Value for November 1994 was 0.0. There were no hours of planned or unplanned unavailability during the month. The year-toeste unavaitabbty value was 0.0029 and the value for the last 12 months was 0.0028 at the end of the month. There has been a total of 28.85 hours of planned unavailability and 17.26 hours of l unplanned unavailablity for the auxiliary feedwater system in 1994. { H j The 1994 Fort Calhoun year-end goal for this indicator is a maximum value of 0.01. l The 1995 INPO industry goal is 0.025 and the industry upper ten percentile value (for the three year period from 7/91 through 6/94) is approximately 0.002. Data Source: Jaworski/Nay Accountability: Jaworski/Nay Positive Trend g l

E Monthly Emergency AC Power Unavailability Value --M-Year-to-Date Emergency AC Power Unavailability Value l GOODI O Fort Calhoun Goal ( 0.025) + NO Wuspal(0.025) 0.07 - --D-Industry Approximate Upper 10% (0.0035) 0.06 - 0.05 - 0.04 - 0.03 - 0 0.02 - 0.01 - M-- -JL---arls--.-O s i e i i i i i e i i i Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 EMERGENCY AC POWER SYSTEM SAFETY SYSTEM PERFORMANCE This indicator shows the Emergency AC Power System unavailability value, as defined by INPO in the Safety System Performance Indicator Definitions, for the reporting month. The Emergency AC Power System unavailability value for November 1994 was 0.0046. During the month, there were 6.6 hours of planned unavailability for testing, and no hours of unplanned unavailability. Tlie Emergency AC Power System unavailability value year-to-date was 0.0137 and the value for the last 12 months was 0.0128 at the end of the month. The large unavailability value for February is due to maintenance outages on both diesel generators. There has been a total of 208.64 hours of planned unavailability and 11.25 hours of unplanned unavailability for the emergency AC power system in 1994. The 1994 Fort Calhoun year-end goal for this indicator is a maximum value of 0.025. The 1994 DG unavailability has increased over 1993 DG unavailability due to changes in operational definitions of out-of-service equipment. The 1995 INPO industry goal is 0.025 and the industry upper ten percentile value (for the three year period from 7/91 through 6/94) is approximately 0.0035. Data Source: Jaworski/Ronning Accountability: Jaworski/Ronning Positive Trend 10 m

E Number of Failures /20 Demands --G-Trigger Values for 20 Demands -V-Tri 0er Values for 50 Demands O Number of Failures /50 Demands O E Number of Failures /100 Demands - Trio 0er Values for 100 Demands 8-IGOODI t 6-V T Y 7 7 7 7 7 7 ? Y 7 4-l = = = = = = = = = = = = 2-1 1 1 1 1 1 1 1 1 1 1 1 00 00 00 00 00 00 00 00 00 00 00 00 0 Dec93 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov94 EMERGENCY DIESEL GENERATOR UNIT RELIABILITY This bar graph shows three monthly indicators pertaining to the number of failures that were reported during the last 20,50, and 100 emergency diesel generator demands at the Fort Calhoun Station. Also shown are trigger values which correspond to a high level of confidence that a unit's diesel generators have obtained a reliability of greater { than or equal to 95% when the failure values are below the corresponding trigger val-I ues. The Fort Calhoun 1994 goalis to have fewer failures than these trigger values. t 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 realload signal, a load-run test expected to carry the plant's load and duration as stated in the test specifications, and a special test in which a diesel generator was expected to be operated for a mini-mum of one hour and to be loaded with at least 50% of design load (see exceptions and other demand criteria in the Definition Section of this report). Data Source: Jaworski/Ronning (Manager / Source) Accountability: Jaworski/Ronning } Positive Trend 11

m_ O DG-1 Fallures/25 Demands ' IGOODI E DG-2 Failures /25 Demands y 5- - e - Failure TriODer Value for 25 Demands / Fort Calhoun Goal 4-C' O O O O O 'O O O O O O 3-l i 2-1- 00 00 00 00 00 00 00 00 00 00 00 00 I I I I I I I I I I I I Dec93 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov94 DIESEL GENERATOR RELIABILITY (25 DEMANDS) This indicator shows the number of failures experienced by each emergency diesel generator during the last 25 start demands and the last 25 load run demands. A trigger value of 4 failures within the last 25 demands is also shown. This trigger value of 4 failures within 25 demands is the Fort Calhoun goal for 1994. i it must be emphasized that, in accordance with NUMARC criteria, certain actions will take place in the event that any one emergency diesel generator experiences 4 or more failures within the last 25 demands on the unit.- These actions are described in the Definitions Section of this report. A System Engineering Instruction has been approved I for the Fort Calhoun Station to institutionalize and formally approve / adopt the required NUMARC actions. l l Diesel Generator DG-1 has not experienced any failures during the last 25 demands on the unit. Diesel Generator DG-2 has not experienced any failures during the last 25 demands on 'l the unit. Data Source: Jaworski/Ronning (Manager / Source) Accountability: Jaworski/Ronning Positive Trend { 12 a

E DG-1 Unreliability Value DG-2 Unreliability Value lGOODI --+-- Station Unreliability Value Industry Upper 10% (0.002 for 0.0025 - a Three Year Average) 0.002-O O O O O O O O O O O O 0.0015 - 0.001 - 0.0005-0,0 0,0 0,0 0,0 0,0 0,0 0,0 0,0 0,0 0,0 0,0 0,0 i - i - i - i - i i - i - i - i Dec93 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov94 EMERGENCY DIESEL GENERATOR UNRELIABILITY The purpose of this indicator is to monitor the likelihood that emergency AC power generators will respond to off-normal events or accidents. It also provides an indication of the effectiveness of maintenance, operation and test practices in controlling genera-tor unreliability. The year-to-date station EDG unreliability value at the end of November 1994 was 0.0. The 1994 goal for this indicatoris a maximum value of 0.0. For DG-1: There were 2 start demands for the reporting month without a tailure. In addition, there was 1 load-run demand without a failure. For DG-2: There was 1 start demand for the reporting month without a failure. In addition, there was 1 load-run demand without a failure. Emergency diesel generator unreliability is calculated as follows: value per DG = SU + LU -(SU x LU) where SU = Start Unreliability = number of unsuccessful starts number of valid start demands LU = Load-run Unreliability = number of unsuccessfulload-runs number of valid load-run demands Station Value = average of DG-1 and DG-2 values Data Source: Jaworski/Ronning (Manager / Source) Accountability: Jaworski/Ronning Positive Trend 13

~ E Fuel Reliability Indicator ' l A 1995 INPO Industry Fuel Defect Reference (5 X 104 Microcuries/ Gram) lGOODI O 1994 & 1993 Fort Calhoun Goals 15-b,0 i i i Dec93 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov94 FUEL REUABILITY INDICATOR The Fuel Reliability Indicator (FRI) value for November 1994 was 13.72 X 10-4 microcu-ries / gram. The purpose of the FRIis to monitor industry progress in achieving and maintaining a high level of fuel integrity. The November FRI value, which is greater than the zero defect threshold value, discussed below, indicates a potential fuel defect in the core. The plant operated at full power during the month. The November FRI was calculated based on the average fission product activities present in the reactor coolant during the steady state full power operation days, November 1 through 30. The November FR1 value of 13.72 X 10d microcuries/ gram indicated a slight decrease from the October value of 13.89 X 104 microcuries/ gram. The 13.72 X 104 microcuries/ gram FRI value exceeds the 1994 operational goal. The value will not significantly decrease until the leaking pin or pins are removed from the core but may show small monthly changes due to chemistry variability. Fission product activity data from November full power operation showed a Xenon-133 l activity increase but no lodine spiking. The Westinghouse technical expert on fuel reliability has determined that there is a potential for 1 or 2 defective fuel rod (s) in the Cycle 15 core. This prediction is based on a change in the Xe-133 to 1-131 ratio. This prediction has been supported by results from the CHIRON and CADE fuel reliability codes which also indicate 1 or 2 fuel pins to be failed. Westinghouse will be sending a formal report on the evaluation. The INPO September 1992 Report " Performance Indicators for U.S. Nuclear Utility industry" (INPO No. 92-011) states that "...the 1995 industry goal for fuel reliability is that units should strive to operate with zero fuel defects. A value larger than 5.0 X 104 microcuries/ gram indicates a high probability of reactor core operation with one or more fuel defects. The determination of current defect-free operation requires more sophisti-cated analysis by utility reactor engineers." The value of 5.0 X 104 microcuries/ gram is defined as a " Fuel Defect Reference" numoer or a "Zero Leaker Threshold". Each utility will calculate whether the core is defect free or not. The 1994 Fort Calhoun Station FRI performance indicator goal is to maintain a monthly FRI below 5.0 X 10-4 microcuries/ gram. Data Source: Holthaus/ Weber Accountability: Chase /Spilker Adverse Trend: An Adverse Trend is indicated based on not meeting the 1994 goal. 14

D Control Room Equpment Deficiencies Repairable On-Line lGOODI l 5 Total Number of Control Room Equipment Defciencies V -O-Fort Calhoun Goa! For Total Equipment Deficiencies 80-70-so-F 50-d 4 m -~'~ 40-5 t ? l j t 1 4 E 3 i f [ 30-I: f-J = i 20-1; { j /, f j j 10- 's a /. / 2 ? ? ? a / / v v g i i i i i i i i i i i i Dec93 Jan Feb Mar Apr May Jun Jul Aug Sep Oct94 Nov34 9 Operator Work Around items Repairable On-Line O Total Number of Operator Work Around items 10- --O-Fort Calhoun Goal for Total Operator Work Around items 8- "~ 0-0 C O O O O O O O O O 4-A a,,, n n n n B 2 O i i i i i i i i i i DecS3 Jan Foo Mar Apr May Jun Jul Aug Sep Oct Nov94 l i NUMBER OF CONTROL ROOM EQUIPMENT DEFICIENCIES i This indicator shows the number of control room equipment deficiencies that are repair-able during plant operabons (on-line), the number of outstanding control room equip-ment defoencies the number of Operator Work Around (OWA) Items repairable on-l line, the number of outstanding OWAs and the Fort Calhoun goals. There was a total of 48 control room equipment deficiencies at the end of November l 1994.12 of these oefoencies are repairable on-line and 36 require a plant outage to repair. There were 5 ident.f ed Operator Work Around items at the end of the month. The OWAs were on equ'pment tags: CH-208 C/R Panel CB-1/2/3, RC-3C C/R Panel CB-1/ 2/3, RC-3D C/R Panel CB-1/2/3, FP-368 C/R Panel CB-10/11, and MOV-D1 C/R Panel CB-10/11. 4 OWAs require an outage to repair. The 1994 Fort Calhoun monthly goal for this indicator is a maximum of 45 deficiencies and 5 OWAs. Data Source: Chase / Tills (Manager / Source) Accountability: Chase /Faulhaber Adverse Trend: None 15 1-

E Monthly Personnel Radiation Exposure (Non-Spent Fuel Rerack) ' Personnel Cumulative Radiation Exposure (Non-Spent Fuel Rerack) --O-Fort Calhoun AnnualGoal(44 Person-Rem) h40-C c c c c c c c c c c c [ 30-6 20- ^ 1-i i e i i i i i e i i Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 0" Monthly Personnel Radiation Exposure for Spent Fuel Rerack IGOODI Personnel Cumulative Radiation Exposure for Spent Fuel Rerack V --O - Fort Calhoun Annual Goal ( 23 Person-Rem) e3: c c c c c c c c c c c c 6: 8 0 0 0 0 -i-4 -i-i i i i e i i i 0-Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 COLLECTIVE RADIATION EXPOSURE The 1994 Fort Calhoun goal for collective radiation exposure, excluding the spent fuel rerack, is less than 44 person-Rom. The exposure for November 1994 was 1.701 person-Rem. The year-to-date exposure was 15.657 person-Rem. The Fort Calhoun goal for collective radiation exposure to complete the Spent Fuel Rorack is less than 23 person-Rem. The Spent Fuel Rerack exposure for November was 0.737 person-Rem. The year-to-date Spent Fuel Rerack exposure was 5.904 person-Rem. The collective radiation exposure at the end of November (i.e., the sum of non-spent fuel rerack exposure and spent fuel rerack exposure) was 21.567 person-Rem. The collective radiation exposure for the last 12 months was 27.55 person-Rem at the end of the month. The 1995 INPO industry goal for coIIective radiation exposure is 185 person-rem per year. The approximate industry upper ten percentile value (for the three year period from 7/91 through 6/94) is 106 person-rem per year. The yearly average for Fort Cal-houn Station for the three years from 11/91 through 10/94 was 146.344 person-rem per year. Data Source: Chase /Little (Manager / Source) Accountability: Chase /Lovett Adverse Trend: None SEP54 i 16 l

Highest Exposure for the Month (mrem) O Highest Exposure for the Year (mrem) 5000 - OPPD 4500 mRom/yr. Limit P 4000 - 3000-E E 2000 - Fort Calhoun 1,000 mrem /yr. Go.i! 1000-686 B klE? %i ? 0 W ' w' gggg;;'l';"g,m 154

m..

November 1994 kAXIMUM INDIVIDUAL RADIATION EXPOSURE During November 1994, an individual accumulated 154 mrem, which was the highest individual exposure for the month. The maximum individual exposure for the year was 686 mrem at the end of November. The OPPD limit for the maximum yearly individual radiation exposure is 4,500 mrem / year. The 1994 Fort Calhoun year-end goal is a maximurn nf 1,000 mrem. \\ Date Source: Chase /Little (Manager / Source) i Accountability: Chase /Lovett Adverse Trend: None 17 l

- Violations per 1,000 inspection Hours 3.03 3-lGOODI -O-Fort Calhoun Goal ( t 2-N l I'* k ^/ W l I>0 k1-I i i 12 13 Nov93 Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct94 VIOLATIONS PER 1,000 INSPECTION HOURS This indicator displays the number of NRC violations cited in inspection reports per 1,000 NRC inspection hours. This indicator is one month behind the reporting month due to the time in-volved with collecting and processing the data. The violations per 1,000 inspection hours indicator was reported as 1.48 for the twelve months from November 1,1993 through October 31,1994. The following inspections ended during this reporting period: i IER No. Iida No. of Hours 94-04 Inspection of SWOPl SeN-Assessment 120 (1st weak of 2 week inspection) To date, OPPD has received 11 violations for liispections conducted in 1994: l Level lil Violations (1) Level IV Violations (7) .l Level V Violations (0) Non-Cited Violations (NCV) (3) ,l The 1994 Fort Calhoun goal for this indicator is a maximum of 1.4 violations per 1,000 inspec-tion hours. Data Source: Trausch/Cavanaugh (Manager / Source) i i Accountability: Trausch Adverse Trend: None 18

E NRC Significant Events lGOODI - Industry Avera0e Trend y 1 1 1-0.5 - 0 91 2 91-3 91-4 92-1 92-2 92-3 92-4 93-1 93-2 93-3 93-4 94 1 Year-Quarter lGOODI @ INPO Significant Events (SERs) V 2-3 4 3 3 M, ,M,M, 0 91 2 91-3 91-4 92-1 92 2 92-3 92-4 93-1 93-2 93-3 93-4 94-1 Year-Quarter SIGNIFICANT EVENTS This indicator illustrates the number of NRC and INPO Significant Events for Fort Calhoun Station as reported by the Nuclear Regulatory Commission's Office for Analysis and Evaluation of Operational Data in the biannual " Performance Indicators for Operating Commercial Nuclear Power Reactors" report and INPO's Nuclear Network. The following NBC significant events occurred between the second quartar of 1991 and the First quarter of 1994: Second Quarter 1991: Safety related electrical equipment was not adequately protected from a I high energy line break. Third Quarter 1992: The failure of a Pressurizer Code safety valve to ressat initiated a LOCA with the potential to degrade the reactor coolant pressure boundary. The following INEQ significant events, as reported in Significant Event Reports (SERs), oc-t curred between the fourth quarter of 1991 and the first quarter of 1994: Second Quarter 1992: Intake of Transuranics during Letdown Filter Change-out. Third Quarter 1992: 1) RC-142 LOCA; and 2) Premature Lift of RC-142. First Quarter 1993: Inoperability of Power Range Nuclear instrumentation Safety Channel D. Second Quarter 1993: SBFU Breaker Relay (Switchyard) Plant Trip Fourth Quarter 1993: Unexpected CEA Withdrawal. Data Source: Nudear Regulatory Commission & INPO l Accountability: Chase l Adverse Trend: None gg

3- @ Number of Missed STs Resulting in LERs ~ 2 1-0 0 0 0 0 0 0 0 0 0 0 0 0 e i i i i i e i i i i i S2 S3 Dec93 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov94 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 1994. During the month of January 1993 it was discovered that during December 1992 an ASME Section XI Code required surveillance was not completed nor corrective mainte-nance performed as a result of AC-10A falling into the " Alert Range" (LER 93-003 Fail-ure to Satisfy inservice Testing Requirements for Raw Water Pump). The 1994 Fort Calhoun monthly goal for this indicator is 0. Data Source: Monthly Operating Report & Plant Licensee Event Reports (LERs) Accountability: Chase /Jaworski Positive Trend SEP 60 & 61 l 20

8 PERFORMANCE Goal: To strive for Excellence in Operations utilizing the highest standards of performance at Fort Calhoun Station that result in safe, reliable plant operation in power produc-tion. i e 21 l

E NetGeneration (10,000 Mwhours) 40-U 34.6 34.9 34.85 34.88 34.14 33.88 i i i i i i i Dec93 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov94 STATION NET GENERATION During the month of November 1994 a net total of 348,068 MWH was generated by the i Fort Calhoun Station. Cumulative net generation for Cycle 15'was 4,092,234 MWH at i the end of the month. Energy losses for the month of February 1994 were attributable to a generator and reactor trip that occurred following the failure of the relay for the Containment High Pressure Signal Supervisory Circuit. Energy losses forthe month of January 1994 were attributable to derates to repair condenser tubes and a failed level control valve on a l heater drain tank. Energy losses for the month of December 1993 were a result of a forced outage that began on December 6 and ended on December 7. The outage was caused by an EHC l test failure. Energy losses for September, October and November 1993 were attribut-able to the shutdown for the Cycle 15 refueling outage, which began on September 25 I and ended on November 26. l l Data Source: Station Generation Report Accountability: Chase Adverse Trend: None 22

- Forced Outage Rate IGOODl l -O-Fort Calhoun Goal (2.4%) y 10.1 10%- 9.3 8%- l 6%-- i r + 4%- i O--O--O--O--C O--C O O O--C O 1.38' ~ f i i i i i i i i i i i i i i 3 i '91 '92 '93 Dec93 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov94 FORCED OUTAGE RATE The forced outage rate (FOR) was reported as 0.87% for the twelve months from December 1,1993 thru November 30,1994. The 1994 year-to-date FOR was 0.61% at the end of the month. l A forced outage occurred on February 11,1994 due to a generator and reactor trip that occurred following the failure of the relay for the Containment High Pressure Signal Supervisory Circuit. The generator was off-line for 48.9 hours. A forced outage occurred on December 6,1993 when the plant tripped during weekly I' testing of the turbine EHC system. The generator was off-line for 27.1 hours. l The 1994 Fort Calhoun year-end goal for this indicator is a maximum value of 2.4%. l The 1993 Fort Calhoun year-end goal was a maximum value of 2.4%. i Data Source: Monthly Operations Report Accountability: Chase ] i Positive Trend 23 i,

O Monthiy unit Capacity Factor - Cycle 15 Unit Capacity Factor + 36 Month Average Unit Capacity Factor 110 % - 100 % - [""" = 0 90%- ~ g 80%- p Y 0 0 0 ~ ' ^ .,y 70%- p v ? 60%- l 50%- M 40%- 30% - 20%- 10%- 0% Dec93 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov94 UNIT CAPACITY FACTOR This indicator shows the plant monthly Unit Capacity Factor, the Unit Capacity Factor for the current fuel cycle and the 36 month average Unit Capacity Factor. The Unit Capacity Factor for November 1994 was reported as 101.1%. Energy losses for the month were due to a reduction to 95% power for MTC testing. At the end of the month the Cycle 15 Unit Capacity Factor was 90.6% and the Unit Capacity Factor for the last 36 months was 77.6%. The Unit Capacity Factor is computed as follows: Net Electrical Eg Generated (MWH) Maximum Dependable Capacity (MWe) X Gross Hours in the Reporting Period Data Source: Monthly Operating Report Accountability: Chase Positive Trend 24

A l. E Monthly EAF - - Year-to-Date Avera0e Monthly EAF I industry Median Value(76.7% for a , Three Year Avera0e) i 100 % - 85.6 76.2 80 % - 60.8 t 40%- 20%- 0%- '91 '92 '93 Dec93 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov94 EQUIVALENT AVAILABILITY FACTOR This indicator shows the plant monthly Equivalent Availability Factor (EAF), the year-to-date average monthly EAF, and the year-end average monthly EAF for the previous 3 years. The EAF for November 1994 was reported as 99.88%. Energy losses for the month were due to a power reduction for MTC testing and a power reduction to correct an inverter problem. The year-to-date monthly average EAF was 96.95% at the end of the month. i Energy losses for the month of February were due to a generator and reactor trip that occurred following the failure of the relay for the Containment High Pressure Signal Supervisory Circuit. Energy losses for the month of January were due to derates for condenser tube repair and a failed level control valve on a heater drain tank. The Fort Calhoun average monthly EAF for the three years prior to this report was 78.03%. The industry median EAF value for the three year period from 7/90 through 6/93 was 76.7%. Data Source: Dietz/Parra (Manager / Source) Accountability: Chase Adverse Trend: None

3 Monthly Unit Capability Factor --M-- Year to-Date Unit Capability Factor --+ - 36 Month Average Unit Capability Factor 4 O Fort Calhoun Goal l GOOD l 1995 INPO Industry Goal ( 80%) Industry Upper 10% (89.9% for a Three Year Average) Dec93 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov94 UNIT CAPABILITY FACTOR This indicator shows the plant monthly Unit Capability Factor (UCF) value, the year-to-date UCFs, the 36 month average UCFs, and the UCF goals. UCF is defined as the. ratio of the available energy generation over a given period of time to the reference energy generation (the energy that could be produced if the unit were operated continu-ously at full power under reference ambient conditions) over the same time period, expressed as a percentage. The UCF for November 1994 was reported as 99.6%. ' Energy losses for the month were due to a power reduction for moderator temperature c:cefficient testing and a 2.5 hour power reduction due to the inoperability of an inverter. The year-to-date UCF was 97.8%, the UCF for the last 12 months was 97.4%, and the 36-month average UCF was reported as 78.7% at the end of the month. Energy losses for the month of February 1994 were due to a generator and reactor trip that occurred following the failure of the relay for the Containment High Pressure Signal Supervisory Circuit. Energy losses for the month of January were due to derates to repair condenser tubes and a failed level control valve on a heater drain tank. Energy losses for the month of December 1993 were due to rampup from the Cycle 15 Refueling Outage and a plant trip that occurred on December 6 during testing of the EHC system. The 1995 INPO industry goal is 80% and the industry upper ten percentile value (for the three year period from 7/91 through 6/94)is approximately 89.9%. The 1994 Fort Calhoun year-end goal for this indicator is a minimum of 96.03%. Data Source: Generation Totals Report & Monthly Operating Report Accountability: Chase Positive Trend 26

i L'11 Monthiy unpianneo Capabiiity toss Factor Year-to-Date Unplanned Capability Loss Factor lGOODI Fort Calhoun Goal 9 ^ 1995 INPO Industry Goal ( 4.5%) 25%- industry Upper 10% (1.38% for a Three Year Average) 15%- 10%- 5%- I n n a a n = = 3 3 g a y = Dec93 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov94 UNPLANNED CAPABILITY LOSS FACTOR This indicator shows the plant monthly Unplanned Capability Loss Factor (UCLF), the year-to-date UCLF and the goal. UCLF is defined as the ratio of the unplanned energy losses during a given period of time, to the reference energy generation (the energy that could be produced if the unit were operated continuously at full power under reference ambient conditions), expressed as a percentage. The UCLF for the month of November 1994 was reported as 0.03%. The unplanned energy losses for the month were due to the inoperability of the "B" 120-VAC instrument inverter for 2.5 hours on November 30. The year-to-date UCLF was 1.76%, the UCLF for the last 12 months was 2.23%, and the 36 month average UCLF was reported as 5.73% at the end of the month. ' Unplanned energy losses for the month of February 1994 were due to a generator and reactor inp that occurred following the failure of the relay for the Containment High Pressure 5.gnal Supervisory Circuit. Unplanned energy losses for the month of January were due to derates to repair condenser tubes and a failed level control valve on a heater drain tank Unplanned energy losses for the month of December 1993 were the result of a plant trip that occurred dunng EHC testing. The 1995 INPO industry goal is 4.5% and the industry upper ten percentile value (for the three year penod from 7/91 through 6/94) is approximately 1.36%. The 1994 Fort Calhoun year-end goal for this indicator is a maximum value of 3.97%. Data Source: Generation Totals Report & Monthly Operating Report Accountability: Chase Positive Trend 27

==== FCS Reactor Scrams Per 7,000 Hours Critical Year-to-date -+-- FCS Reactor Scrams Per 7,000 Hours Critical for the last 36 months j -O-1994 & 1993 Fort Cah)un Goals (o.0) + 1995INPOIndustryGoal 6- -O-Industry Upper 10% (o.48 per 7,000 hours critical over a 36 month time period) 5-4- 3-0 0 0 ^ 0 0 0 0 0 2-A T ! r M1 1 1 ? 1 j j j o-i r- - r-r .-ir, Dec93 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov94 E Numberof FCSReactorScrams 4~ 3 2 3-2- 1 1 rj~ 1-o o o o o o o o o o oo o i i i i i i i i i i i i i i i i '90 '91 '92 '93 Dec93 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov94 [ UNPLANNED AUTOMATIC REACTOR SCRAMS PER 7,000 HOURS CRITICAL The upper graph shows the number of unplanned automatic reactor scrams per 7,000 hours critical (as defined in INPO's 12/93 publication " Detailed Descriptions of Interna-tional Nuclear Power Plant Performance Indicators and Other Indicators") for Fort Cal-houn Station. The lower graph shows the number of unplanned automatic reactor scrams that occurred during each month for the last twelve months. The year-to-date station value was 0.88 at the end of November 1994. The value for the 12 months from December 1,1993 through November 30,1994 was 1.61. The value for the last 36 months was 1.94. An unplanned automatic reactor scram occurred on February 11,1994 when supervi-sory relay 86B/CPHSS failed. An unplanned automatic reactor scram occurred on December 6,1993 during EHC testing. The 1994 Fort Calhoun goal for this indicator is 0. The 1995 INPO industry goal is a maximum of 1 unplanned automatic reactor scram per 7,000 hours critical. The industry - upper ten percentile value is approximately 0.48 scrams per 7,000 hours critical for the 36 month time period from 7/91 through 6/94. Data Source: Monthly Operations Report & Plant Licensee Event Reports (LERs) Accountability: Chase Adverse Trend: None 28

~ E Safety System Actuations (INPO Definition) -O-Fort Calhoun Goal (0.0) O Industry Upper 10 Percentile 2-I i 1 1-OEo O-a i i i 91 92 93 Dec93 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov94 UNPLANNED SAFETY SYSTEM ACTUATIONS-(INPO DEFINITION) There were no INPO unplanned safety system actuations during the month of Novem-ber1994. There was 1 INPO unplanned safety system actuation during the month of February 1994. It occurred on February 11 when supervisory relay 86B/CPHSS failed, which resutted in tripping relay 86B/CPHS. The CPHS relay trip actuated the Safety injection Actuation Signal, Containment Isolation Actuation Signal, Ventilation Isolation Actuation Signal and Steam Generator Isolation Signal. The Steam Generator Isolation Signal automatically closed both main steam isolation valves, which resulted in a concurrent turbine and reactor trip. An INPO unplanned safety system actuation occurred during the month of July 1992. It was due to the loss of an inverter and the subsequent reactor ti;p cn 7/3/92. l The 1994 Fort Calhoun goal for this indicator is 0. Data Source: Monthly Operations Report & Plant Ucensee Event Reports (LERs) l Accountability: Jaworski/Foley/Ronning Adverse Trend: None 29 l

- 12 Month Running Total SSAs (NRC Definition) ' CriticalHours j B Safety System Actuations (NRC Definition) 10-1000 Cycle 15 900 { 8-Refueling - 800 Outage v-v- v -v - 700 g 8- - 800 y l 500 4 - 400 g l 4-3 g U> y 300 o 2- -200 i y 0 11 12 13 DJFMAMJJASONDJFMAMJJASON 1992 1993 1994 UNPLANNED SAFETY SYSTEM ACTUATIONS-(NRC DEFINITION) This indicator shows the number of unplanned safety system actuations (SSAs), which includes the High and Low Pressure Safety injection Systems, the Safety injection Tanks, and the Emer-gency Diesel Generators. The NRC classification of SSAs includes actuations when major equipnent is operated and when the logic systems for these safety systems are challenged. There was 1 NRC unplanned safety system actuation during the month of February 1994. It occurred on February 11 when supervisory relay 86B/CPHSS failed, which resulted in a concur-t rent turt>ine and reactor tnp. There were 3 NRC unplanned safety system actuations in 1993: 1) In December 1993 the main f turbine and reactor tnpped during Electro-Hydraulic Control pump start testing; 2) In June 1993 1 the inadverient Jarnng of a 345 KV fault relay in the switchyard caused a turbine and reactor trip, l and 3) in Apnl 1993 a non-licensed operator mistakenly opened the wrong potential fuse i j drawer, causmo a low voltage alarm on bus 1 A1, a loadshed on bus 1 A1 and an auto start of an i i EDG. There were 4 unplanned safety system actuations in 1992: 1) In August, due to the failure of an i AC/DC converter in the Turbine Electro Hydraulic Control: ystem, pressurizer safety valve RC-142 opened prer to reaching design pressure during a plant transient and trip; 2) On July 3 there was an inver1er tailure and the st:bzaquent reactor trip; 3) On July 23 there was an 6 unplanned desel generator start when an operator performing a surveillance test inadvertently q pushed the normal star 1 button instead of the alarm sckrs.-/ edge button; and 4) in May the I turbine generator tnoped on a falso high level moisture separator trip signal which caused a simultaneous reactor tnp and subsequent anticipatory start signal to both diesel generators. [ There have been 2 unplanned safety system actuations in the last 12 months. The 1994 Fort Calhoun goal for this indicator is 0. Data Source: Monthly Operations Report & Plant Ucensee Event Reports (LERs) I Accountability: Jaworski/Foley/Ronning Adverse Trend: None 30 ) l I

) 3 MontNyGrossHeatRate -e-Year-to-Date Gross Heat Rate -G-1994 &1993 Fort Calhoun Goals 10.5-l 10300 10223 10.25-10177 l 8 l o. j 10-i ) ] l 9.75-i i i I '91 '92 '93 Dec93 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov94 GROSS HEAT RATE This indicator shows the Gross Heat Rate (GHR) for the reporting month, the year-to-date GHR, the goals and the year-end GHR for the previous 3 years. The gross heat rate for Fort Calhoun Station was 10,056 for the month of November 1994. The 1994 year-to-date GHR was 10.189 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 1994 Fort Calhoun year-end goal for this indicator is s10,190. Data Source: Holthaus/ Gray (Manager / Source) Accountability: Chase /Jaworski Adverse Trend: None 31

5 Monthly Thermal Performance --46-- Year-to-Date Average Monthly Thermal Performance 4 0 1994 & 1993 Fort Calhoun Goals lGOODI -+- 1995 INPO Industry Goal ( 99.5%) a industry Upper 10% (99.9%) 10W.- g 3 g g 3 3 3 0 0 0 0 O I ^ ^ ^ ^ ^ ^ ^ f e 98 % J Dec93 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov94 THERMAL PERFORMANCE This indicator shows the Thermal Performance value for the reporting month, the year-to-date average monthly thermal performance value, the Fort Calhoun goals, the 1995 INPO industry goal and the approximate industry upper ten percentile value. The thermal performance value for November 1994 was 99.04%. The year-to-date average monthly thermal performance value was 99.3% at the end of the month. The average monthly value for the 12 months from December 1,1993 through November l l 30,1994 was 99.31%. Thermal Performance improved in May as a result of the backwash valve adjustments on "A" Condenser and improvements in Heater 2A level control. l The low thermal performance value for February 1994 is attributable to level control problems on heaters 3A and 5B, and to spring runoff resulting in screen carry-over and condenser fouling. Improvements made during the month of March were: warm water recire. was taken off-line; some recovery in condenser performance was achieved due to backwashing at regular intervals; and the level control problems for heater 3A were l corrected. t The 1994 Fort Calhoun year-end goal for this indicator is a dnimum of 99.5%. The 1993 Fort Calhoun goal was a minimum of 99.4%. The 1995 INPO industry goalis 99.5% and the industry upper ten percentile value (for the one year period from 7/93 l through 6/94) is approximately 99.9%. Data Source: Jaworski/Popek Accountability: Jaworski/Popek i Adverse Trend: An Adverse Trend is indicated. The primary reason for the decline in i this indicator for November is increased auxiliary steam flow for facilities heating. 32

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,,'ct ' n.',',~~<^>'s- 'o ' :' - "' '~ - : s',, 1420-,, s ?r&,, ' ' q, >', '<i, ' -l ;, ' ,~7',,<n+, ',v s s v-1 > c + N, 3 l:: '. *: r <.>,s s g'>-,, v, r, , n s,. ',, ,.4,- a 4,< 1415 i,, i,,,,,,, i i i i i i i i i i i i i i i i i 1 3 5 7 9 11 13 15 17 19 21 23 25 27 29 DAILY THERMAL OUTPUT f The thermal output graph displays the daily operating power level during November 1994, the 1500 thermal megawatt average technical s,pecification limit, and the 1495 thermal megawatt Fort Calhoun goal. Energy losses for the month were due to a power reduction for MTC testing on 11/5 and a power reduction for inverter repair on 11/30. Data Source: Holthaus/ Gray (Manager / Source) l Accountability: Chase / Tills Adverse Trend: None 33
Equipment Forced Outa0e Rata /1,000 Critical 0.8'J Hours for a 12 Month interval lGOODI ~ --O-1993 & 1994 Fort Calhoun Year-End Goals ( 0.2) V 0.6 - 0.5 1,,0 0.4 - 0.2 - C O O O O O O O O O O O 0 91 '92 '93 Dec93 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov94 2 E Number of Equipment Forced Outages Per Month 1-0- k $ 5k$$ E $$b 5 ~ 8 2 EQUIPMENT FORCED OUTAGES PER 1,000 CRITICAL HOURS The equipment forced outage rate per 1,000 critical hours for the 12 months from December 1,1993 through November 30,1994 was 0.11. The rate per 1,000 critical hours for the months from January through November 1994 was 0.12. An equipment forced outage occurred on February 11,1994 when the plant experi-enced an unplanned automatic reactor trip as a result of the failure of the relay for the Containment High Pressure Signal Supervisory Circuit. An equipment forced outage occurred in August 1992 and continued through Septem-I ber. It was due to the failure of an AC/DC converter in the Turbine Electro Hydraulic Control System. l The 1994 Fort Calhoun year-end goal for this indicator is a maximum value of 0.20. Data Source: Monthly Operations Report & Plant Ucensee Event Reports (LERs) { Accountability: Chase /Jaworski Positive Trend l 34
of Cup nent CaWork 40-
-+- # of Application Categories 35- -*- Total # of Categories 30-c 25-y 20-O A A - - v" s-a 10-5- WY' _#:ll f i l l l l l l l l l l l l l l l l l l J93 J A S O N D J F M A M J J A S O N94 E WearOut/ Aging @ OtherDevices 8 Manufacturing Defect O Maintenance / Action 4.9% 4.9% 0 Engineering / Design @ Error / Operating Action 43 4.9% i, Percent of Total Failures During the Past 18 Months e['o IIII 8. 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 sign!ficantly higher (1.645 standard deviations) failure rates than the industry failure rates during the past 18 months (from February 1993 through July 1994). Fort Calhoun Station reported a higher failure rate in 5 of the 87 component categories (valves, pumps, motors, etc.) during the past 18 months. The station reported a higher failure rate in 6 of the 173 application categories (main steam stop valves, auxiliary / emergency feedwater pumps, control element drive motors, etc.) during the past 18 months. The pie chart depicts the breakdown by INPO cause categories (see the " Definitions" section of this report for descriptions of these categories) for the 95 failure reports that were submitted to INPO by Fort Calhoun Station during the past 18 months. Of these, the failure cause was known for 81. The pie chart reflects known failure causes. Data Source: Jaworski/ Frank (Manager / Source) Accountability: Jaworski/ Frank Adverse Trend: None 35
Components With More Than One Failure .-e-- l GOOD l Y 25- --M-Components With More Than Two Failures h 20-t 15-12 12 12 12 10 10-v 9 8 8 8 8 7 7 5-4'(3 3, U 1 1 1 1 1 1 1, A a a a a o n 0 Dec93 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov94 ~ REPEAT FAILURES The Repeat Failures Indicator (formerly called the " Maintenance Effectiveness" perfor-mance indicator) was developed in response to guidelines set forth by the Nuclear l Regulatory Commission's Office for Analysis and Evaluation of Operational Data (NRC/ AEOD). The NRC requirement for a Maintenance Effectiveness Performance Indicator has been dropped, but station management considers it useful to continue to track repetitive component failures using the Nuclear Plant Reliability Data System (NPRDS). This indicator shows the number of NPRDS components with more than 1 failure during the eighteen month CFAR period and the number of NPRDS components with more than 2 failures during the eighteen month CFAR period. During the last 18 reporting months there were 8 NPRDS components with more than 1 ,[ failure.1 of the 8 had more than 2 failures. The tag numbers of the components with more than 1 failure are: AC-10A, AC-100, AC-10D, FW-48, I W-40, HCV-386-0, NT-001 and RC-374. The tag number of the component with more than 2 failures is AC-10C. Recommendations and actions to correct these repeat component failures are listed in the quarterly Component Failure Analysis Report. l Data Source: Jaworski/ Frank (Manager / Source) Accountability: Chase l Adverse Trend: None 38 l 1
_ Calculated Check Valve Failure Rate per Million Cormonent Hours l GOOD l Calculated Industry Check Valve Failure Rate per p Million Component Hours 3- -O-Fort Calhoun Goal ] 2.5 - 2-C Mp"C O O O [1.5-A = 1 1 1 0.5 - '911293 Dec93 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov94 No.of Failures CHECK VALVE FAILURE RATE This indicator shows the calculated Fort Calhoun NPRDS check valve failure rate, the Fort Calhoun goal and the industry check valve failure rate average. The failure rates are based on submitted NPRDS failure reports for an 18 month time interval. They do not include failure reports outside of the 18 month time interval. The interval starts 22 months prior to the current month and ends 4 months prior to the current month. For example, the November 1994 Component Failure Analysis Report (CFAR) covers the 18 month interval from February 1,1993 through July 31,1994. This delay is due to the time involved in collecting and processing failure report data. The actual numbers of NPRDS reportable check valve failures at Fort Calhoun Station are shown above on the graph at the left side of the page. For November 1994, the CFAR provided the following failure rates: Fort Calhoun Station 1.19 E-6 Industry (excluding FCS) 1.54 E-6 The increase in the FCS failure rate is due to 2 reportable failures of RC-374, Pressur-Izer RC-4 Spray Line Check Valve; one failure occurred in October and another in November 1993. The 1994 Fort Calhoun monthly goal for this indicator is 51.75 E-6. Data Source: Jaworski/ Frank (Manager / Source) Accountability: Jaworski/Rollins Adverse Trend: None SEP 43 37
E Radioactive Waste Buried This Month (in cubic feet) 750 - - Cumulative Radioactive Waste Buried lGOODI -O-Fort Calhoun Goal For Waste Buried (500 cubic feet) V 600 - ry al(3,m cWc feet) industry Upper 10% (965.3 cubic feet) /o c c c c c 450-q 300-150-0l i i 1 4 1 Jan94 Feb Mar Apr May Jun94 VOLUME OF LOW-LEVEL SOLID RADIOACTIVE WASTE This indicator shows the volume of the monthly radioactive waste buried, the cumulative annual total for radioactive waste buried, the Fort Calhoun and INPO goals, and the approximate industry upper 10%. Amount of solid radwaste shipped off-slie for processing during November (cubic feet) 0.0 i Amount of metals from rack cut-up shipped off-site for processing during November (bs.) 37,200.0 Volume of Solid Radwaste Buried during June (cubic feet) 206.0 Cumulative volume of solid radioactive waste buried in 1994 (cubic feet) 543.6 Amount of solid radioactive waste in temporary storage after July 1,1994 (cubic feet) 0.0 j The 1994 Fort Calhoun goal for the volume of solid radioactive waste which has been buried is 500 cubic feet. The goal was exceeded in June because OPPD's 18 month goal (established in 1993) allowed the opportunity to further reduce the amount of solid radioactive waste. The 1995 INPO industry goal is 110 cubic meters (3,884 cubic feet) per year. The industry upper ten percentile value from 7/91 through 6/94 is approxi-mately 27.33 cubic meters (965.3 cubic feet) per year. Data Source: Chase /Breuer (Manager / Source) Accountability: Chase /Lovett Adverse Trend: Although the 1994 goal was exceeded, this indicator is not exhibiting an adverse trend because Fort Calhoun did not exceed the 18 month goal of 1,500 ft.8 that was established in 1993. The 18 month total for Fort Calhoun was 1,401.4 ft.8 at the end of June 1994. SEP 54 38 t
E Primary System Chemistry Percent of Hours Out of Limit FGOODI -O-Fort Calhoun Goal ( 0.02) y i 3%- 2%- O O O O O O O O O O 1%- 0*'s i i i i i i i i i Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 PRIMARY SYSTEM CHEMISTRY PERCENT OF HOURS OUT OF LIMIT The Primary System Chemistry Percent of Hours Out of Limit indicator tracks the pri-mary system chemistry performance by monitoring 6 key chemistry parameters. The key parameters are: lithium, dissolved oxygen, chlorides, fluoride, hydrogen and sus-pended solids.100% equates to all 6 parameters being out of limit for the month. The Primary System Chemistry Percent of Hours Out of Umit was 0.0% for the month of November 1994. The 1994 Fort Calhoun monthly goal for this indicator is a maximum of 2% hours out of limit. Data Source: Smith / Spires (Manager / Source) j Accountability: Chase / Smith Positive Trend s 39
l 3 Secondary System CPI 1.6 - --O-Fort Calhoun Goal ( 1.5) p l 1.5 - C C C C C C C C C C C C ~ 1.4 - 1.3 - E li;lhllh 0.0 i i i i i i i i i i Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 SECONDARY SYSTEM CHEMISTRY l 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 1994 was 1.0, which is the minimum value that can be obtained. The year-to-date average monthly CPI value was 1.17 at the end of the month. The CPI for December 1993 was 1.92. This relatively higher number was due primarily to iron transport following the plant start-up. The 1994 Fort Calhoun monthly goal for the CPI is a maximum value of 1.5. The CPI calculation is different from that reported in 1993 in that it reflects the recent INPO revision to the calculation. This revision addresses the penalties for the beneficial effect of alternative chemistry,i.e., morpholine, such as used at Fort Calhoun Station, and focuses more on specific impurities. t Data Source: Smith / Spires (Manager / Source) Accountability: Chase / Smith Positive Trend 40
COST ~ Goal: To operate Fort Calhoun Station in a manner that cost effectively maintains nuclear generation as a viable source of electricity. 5 k l ) i a d i 4 i + 1 { 41 i
4- --G-Actuals --O-Budget ,er-- Plan 3.75-3.5 - 325-20 3-2.75-4 2.5 "A1 D92 D93 J94 F M A M J J A S O N D94 D95 D96 D97 D98 Months CENTS PER KILOWATT HOUR The purpose of this inde.ator is to quantify the economical operation of Fort Calhoun Station. The cents per Mowatt hour indicator represents the budget and actual cents per kilowatt hour on a 12 month rolling Average for the current year. The basis for the budget curve is the approved 1993 and 1994 revised budget. The basis for the actual curve is the Financial and Operating Report. The December 31 amounts are also shown for the prior years 1991,1992 and 1993. In addition, the report t. hows the plan amounts for the years 1995 through 1998 for refer-ence. The basis for the dollars are the Nuclear Long Range Financial Plan and the 1994 Corporate Planrung and Budget Review. The basis for the generation is provided by Nuclear Fuels. The unit price (2.67 cents per kilowatt hour for the reporting month) is averaging lower than budget due to expenses being below budget while generation exceeds the budget. Data Source: Scofield/Jamieson (Manager / Source) Accountability: Scofield Positive Trend 42
E Nuclear Services Dkision Staffing O Production Engineering Division Staffing Q Nuclear Operations Division Staffing B TotalNuclearStaffing 7 7 7 7 7 7 9 l 4 2 1 4 4 800-9 ~ 5 5 5 600-3 2 5 4 4 4 4 4 4 500-9 400-1 1 1 1 1 300-0 0 b 1,1 200-1 1 ~ 4 7 6 6 4 4 5 5 4 i I i i i i ~ Jan90 Jan91 Jan92 Jan93 Jan94 Apr94 Jul94 Oct94 ACTUAL STAFFING LEVEL (UPDATED QUARTERLY) STAFFING LEVEL The actual staffing levels for the three Nuclear Divisions are shown on the graph above. ] The authorized staffing levels for 1994 are: i 1994 Authorized Staffing l 453 Nuclear Operations Division 191 Production Engineering Division 117 Nuclear Services Division Data Source: Ponec (Manager & Source) Accountability: Ponec Adverse Trend: None SEP 24 43 l
- Spare Parts inventory Value ($ Million) 17-16-P 2 E \\ 8 o 15-E2 5 14-13 Dec93 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov94 SPARE PARTS INVENTORY VALUE The spare parts inventory value at the Fort Calhoun Station at the end of November 1394 was reported as $16,646,391. Data Source: Steele/Huliska (Manager / Source) Accountability: Willrett/McCormick Adverse Trend: None 44
DIVISION AND ~ DEPARTMENT PERFORMANCE INDICATORS These Indicators may t deleted from this report if the responsible group con-tacts the Manager-Station Engineering to request their removal. Indicators referencing SEP ltems require documentation to ensure that the original intent and scope of the SEP ltem will not be altered by removal of the Indicator from this report. 45
O Corrective Maintenance Non-Corrective / Plant improvements E Preventive Maintenance - O-- Fort Calhoun Goal 776 800-723 752 720 691 700-626 617 600-581 500-400-f 300-O 200-100-0 'e i i i i i i i i i i i 4 Dec93 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov94 Non-Outage Maintenance Work Order Backlog O TotalMWOs E MWOs Which Exceed Mainleunce Completion Goals 400-392 i 350 - 300 - 250 228 200 - 150-100- >3 >14 F"g >90 > ISO 42 g y 1
18. 19 days 30 L,,,,,,,[Y8 fyj days
[gj days i i i i i i i i Priority 1 Priority 2 Priority 3 Priority 4 Priority 5 Priority 6 Non-Outage Maintenance Work Order Aging 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 1994 goal for this indicator has been changed to 400 non-outage corrective MWOs. To ensure that the MWO backlog is worked in a timely manner, non-outage maintenance completion goals have been established as: GQal Priority 1 Emergency N/A Priority 2 Immediate Action 3 days Priority 3 Operations Concem 14 days Priority 4 Essential Corrective 90 days Priority 5 Non-Essential Corrective 180 days Priority 6 Non-Corrective / Plant improvements N/A Data Source: Chase /Schmitz (Manager / Source) Accountability: Chase /Faulhaber Adverse Trand: None SEP 36 46 1
E Ratioof PreventivetoTotalMaintenance 100 % - Dec03 Jan Feb Mar Apr May Jun Jul ' Aug Sep Od Nov94 5-O Preventive Maintenance llems Overdue l GOOD -O-Fort Calhoun Goal V 1%- o -5 _c 2 .p_ _o--o --c o o-o-o rm ri og Dec93 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov94 RATIO OF PREVENTIVE TO TOTAL MAINTENANCE & i PREVEN 11VE MAINTENANCE ITEMS OVERDUE The top graph shows the ratio of completed non-outage preventive maintenance to total l completed non-outage maintenance. The ratio of preventive to total maintenance was 46.3% for the month of November - 1994. The trend of this ratio reflects the revised definition of corrective maintenance l which was implemented in March. j i The lower graph shows the percentage of preventive maintenance items overdue. ~ During November,525 PM items were completed.1 of these PM ltems (0.19% of the j total) was not completed within the allowable grace period or administratively closed. l The 1994 Fort Calhoun monthly goal for the percentage of preventive maintenance items overdue is a maximum of 0.5%. Accountability: Chase /Faulhaber l Data Source: Chase /Schmitz/Meistad (Manager / Sources) Positive Trend SEP 41 47
E Rework As identified By Planning or Craft -O-Fort Calhoun Goal (.3%) 5%- 4%- o 3.16 % C O O O O {3%- W 2.43% 2.44 % 2.06 % O 2% - E 1.58 % 1%- 0.6% a i i i i i i i Mi May94 Jun Jul Aug Sep Oct Nov94 PERCENTAGE OF TOTAL MWOs COMPLETED PER MONTH IDENTIFIED AS REWORK This graph ind. cates the percentage of total MWOs completed per month identified as rework. Ree actmties are identified by maintenance planning and craft. The 1994 Fort Calhoun monthly goal for this indicatoris <3%. Data Source: Fauthaber/Schmitz (Manager / Source) Accountability: Chase /Faulhaber Adverse Trend: None 48
i 80%- E Maintenance Overtime --M-12 Month Average Maintenance Overtime lgl D~ -O-Fort Calhoun "On-Une" Goal (10%) 60%- 50%- 40%- ) 30%- 20%- X X ~ m m 10%- O ^ ^ ^ ^ ^ 1 M,, i i i i i i i i i i Dec9 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov94 MAINTENANCE OVERTIME The Maintenance Overtime indicator monitors the ability to perform the desired mainte-nance activities with the allotted resources. l The percent of overtime hours with respect to normal hours was reported as 12.11% for the month of November 1994. The 12 month average percentage of overtime hours with respect to normal hours was reported as 8.24% at the end of the month. The 1994 Fort Calhoun monthly "on-line" goal for this indicator is a maximum value of 10%. i I j Data Source: Chase /Schmitz (Manager / Source) I f Accountability: Chase /Faulhaber I AdverseTrend: None 49
O Open irs Related to the Use of Procedures (Maintenance) j @ Closed irs Related to the Use of Procedures (Maintenance) E Procedural Noncornpliance irs (Maintenance) 2-l l l 1-000 000 000 00 00 000 000 000 000 0 000 000 0 Dec93 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov94 PROCEDURAL NONCOMPLIANCE INCIDENTS (MAINTENANCE) This indicator shows the number of open Maintenance incident Reports (irs) that are related to the use of procedures, the number of closed irs that are related to the use of procedures, and the number of open and closed irs that received procedural noncom-pliance cause codes for each of the last twelve months. There were no procedural noncompliance incidents for maintenance reported for the month of November 1994. There was 1 procedural noncompliance incident (IR 940323) for maintenance reported for the month of September 1994. The IR was written to document procedural noncom-pliance that occurred when a mercury thermometer was used, rather than the required alcohol thermometer, during a surveillance test. Data Source: Chase (Manager) Accountability: Chase / Conner Adverse Trend: None SEP 15,41 & 44 50
=_ . E Completed scheduled Activities (AllCrahs) D Numberof EmovgentMWOsCompleted l Fort Calhoun Goal (80%) -110 ~ 100 3 "*- 80.g g 80%- C O O O E - 80 E 70%- - 70 8 e l ' "0%- P 5- -a j ss s4 5 46 E /4 - s0 g - n m 40%- %W ((: % Completed 34 % Completed % Completed - 40 0 scheduW scheduled I
gg<
scheduled scheduled 3ng-Ac6== = =m
mie. =
=
..=
^# 20%- II[l Available Available Available - 20 0 f 3 r,y, g j 10%- l((l id' Z E ,/ / og .n Augs:54 september October November 14 i PERCENT OF COMPLETED SCHEDULED MAINTENANCE ACTIVITIES I i (ALL MAINTENANCE CRAFTS)- This indicator shows the percent of the number of completed scheduled maintenance l-activities as compared to the number of scheduled maintenance activities concerning all l Maintenance Crafts Maintenance activities include MWRs, MWOs, STs, PMOs, cali-brations, and miscellaneous maintenance activities. The number of emergent MWOs j completed tor the month is also shown. The percent of the number of completed scheduled maintenance activities as compared i l to the number of scheduled maintenance activities for the months of July, August, j September and October 1994 are not available due to the software and data collection method changes invoked with the implementation of the Integrated Plant Schedule. There were 54 emergent MWOs completed during the month of November. The 1994 Fort Calhoun monthly goal for completed scheduled maintenance activities is j 80%. 4 1 Data Source: Chase /Schmitz (Manager / Source) Accountability: Chase /Faulhaber Adverse Trend: None SEP 33 i i 51 i i l
E % of Hours the in-Line Chemistry instruments are Inoperable 12- --O-1994 Fort Calhoun Goal ( 10%) 11-10-C O O O O O O O-O O O O 9-8- 7-E 6- , ~. 5-ihdiI O i i i i i i j i Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 IN-LINE CHEMISTRY INSTRUMENTS OUT-OF-SERVICE This indicator shows the percentage of hours the in-line chemistry system instruments are inoperable for the reporting month. The chemistry systems involved in this indicator include the Secondary System and the Post Accident Sampling System (PASS). At the end of November 1994 the percentage of hours the in-line chemistry system Instruments were inoperable was 6.29%. 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. l l The 1994 Fort Calhoun monthly goal for this indicator is a maximum of 10% in-line chemistry instruments inoperable. 5 out-of-service chemistry instruments make up 10% of all the chemistry instruments that are counted for this indicator. Data Source: Chase /Reneaud (Manager / Source) l Accountability: Chase /Jaworski Positive Trend 52
. - - =- Q - Waste Produced Each Month (Kilograms) l Monthly Avera0s Waste Produced Dunng the Last 12 Months (Kilo 0 rams) - O Fort Calhoun Monthly Average Goal ( 100 kilograms): -G-- Federal & State Monthly Limit (Max. of 1,000 KO) h 1000 - 0 O 800-f 000-q H @- g 200-C = = O--C = O-- 0 1sisA i i Dec93 Jan Feb Mar Apr - May Jun Jul Aug Sep Oct Nov94 l HAZARDOUS WASTE PRODUCED i This indicator shows the total amount of hazardous waste produced by the Fort Calhoun i Station each month, the monthly average goal and the monthly average total for hazard-ous waste produced during the last 12 months. This hazardous waste consists of non-l halogenated hazardous waste, halogenated hazardous waste, and other haza,drius L waste produced. During the month of November 1994,0.0 kilograms of non-halogenated hazardous waste was produced,398.7 kilograms of halogenated hazardous waste was produced (this waste was unusable morpholine generated after the station switched to using ethanolamine), and 0.0 kilograms of other hazardous waste was produced. The total for hazardous waste produced during the last 12 months is 958.8 kilograms. The monthly average for hazardous waste produced during the last 12 months is 79.9 kilograms. Hazardous waste is counted based upon a full drum of waste. The 1994 Fort Calhoun monthly average goal for hazardous waste produced during the l last 12 months is a maximum of 100 kilograms. i q_ o Data Source: Chase / Smith (Manager / Source) Accountability: Chase / Smith Positive Trend 4 53 } l I
1 E Contanunated Radiation Controlled Area 15%- l GOOD l -O-Fort Calhoun Goal (non-outage rnonths) --G-Fort Calhoun Goal (outage months) 12%- C O O O O O O O O O O O 9%- 6%- 3%- l l 0% i i i i i i i i i i l Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 l CONTAMINATED RADIATION CONTROLLED AREA This indicator shows the percentage of the RCA that is contaminated based on the total square footage. The 1994 monthly non-outage goalis a maximum of 10% contami-nated RCA and the tr.onthly outage goalis a maximum of 13% contaminated RCA. At the end of November 1994, the percentage of the total square footage of the RCA that was contaminated was 9.4%. Data Source: Chase /Gundal(Manager / Source) Accountability: Chase /Lovett Positive Trend SEP54 I 54
~ 7 1
Number of identified PRWPs Year-To-Date
.) IGOODI 3o _ -O-1994 Fort Calhoun Goal (<25) U M-C O O O O O O O O O O O 20 - b m ]15-H 10-g
n. S -
P 0 l Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 RADIOLOGICAL WORK PRACTICES PROGRAM The Radiological Work Practices Program Indicator shows the number of Poor Radio-logical Work Practices (PRWPs) which were identified during the reporting month. The number of PRWPs which are identified each month should indirectly provide a i means to qualitatively assess supervisor accountability for their workers' radiological performance. During the month of November 1994, there were no PRWPs identified. j-There have been 7 PRWPs in 1994. The 1994 year-end goal for the number of PRWPs is a maximum of 25. 4 Data Source: Chase /Little (Manager / Source) imuntability: Chase /Lovett Myerse Tree! None SEP52 55 l
O DocumentsscheduiedforReview E Documents Reviewed E Overdue Documents 350-300-250-200-1 150-100-1_I..... Dada 50 - Unavailable 0 Dec93 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov94 DOCUMENT REVIEW This indicator shows the number of completed, scheduled, and overdue (greater than 6 months past the scheduled due date) biennial reviews for the reporting month. These document reviews are performed in-house and include Special Procedures, the Site Security Plan, Maintenance Procedures, Preventive Maintenance Procedures, and the Operating Manual. Document review information for Novemoer 1994 was not available for this report. During September 1994 there were 97 document reviews scheduled, while 162 docu- ~ ment reviews were completed. At the end of the month, there were no document re-views more than 6 months overdue. There were 16 new documents initiated in September. Data Source: Chase (Manager) Accountability: Chase /Jaworski Adverse Trend: None SEP 46 56
r 1 l 1 E Non-System Failures Dl 16-14-12-10 10-8- 7 5 6-4 4 4 0 i i i i i i i i i i Dec93 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov94 60 - @ System Failures l GOOD l 50 - y 40-30-26 9 15 16 17 ] 20-17 h, ,h '~ 0 i i Dec93 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov94 LOGG ABLE/ REPORTABLE INCIDENTS (SECURITY) The Loggable/ Reportable incidents (Security) Indicator is depicted in two separate graphs. The top graph depicts the total number of loggable/ reportable non-system failures concerning Security Badges, Access Control and Authorization, Security Force Error, and Unsecured Doors. The bottom graph shows the total number of loggable/ reportable incidonts conceming system failures which occurred during the reporting month. During the month of November 1994, there were 27 loggable/ reportable incidents identi-fled. System failures accounted for 22 (81%) of the loggable/ reportable incidents.13 of the 22 system failures were environmental failures due to sun glare and poor weather conditions. Non-system failures included 2 lost / unattended security badges,1 tailgating incident, and 2 security force error incidents. Through November 1994, system and non-system failures continued on a significant downward trend compared to 1993. l l Data Source: Sefick/Woemer (Manager / Source) Accountability: Sefick Adverse Trend: None SEP 58 57
~ 3 Temporary Modifications >1 cycle old (RFO required for Removal) y Temporary Modifications >6 months old (Rernovable on-line) - O-Fort Calhoun Goal for Temporary Modifications >1 cycle old - G-Fort Calhoun Goal for Temporary Modifications >6 months old s-6 6-5 - 4 4 l- .M .WG i rgpg i iggg August W September W October W Noveniber w 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 l of temporary modifications removable on-line that are greater than six months old. In I addition, the 1994 Fort Calhoun monthly goals for this indicator are zero, however, specific temporary modifications have been approved by management to exceed these t goals due to cost effectiveness considerations. These are listed below. l There is currently 1 temporary modification that is greater than one fuel cycle old requir-ing a refueling outage to remove: Epoxy repairs to ST-4B, which is awaiting completion i of MWO 931325, scheduled start date 1995 Refueling Outage. This temporary modifi-l cation was previously included in the on-line removable >6 months old classification, but j was re-classified as an outage modification to save engineering resources from com-j pilsting 1 ECN to allow the epoxy repair to remain in place and a second ECN to remove itduring the 1995 refueling outage, in addition, at.the end of November 1994 there l were 4 temporary modifications installed that were greater than six months old that can l be removed on-line. These were: 1) Local indicatuun for BAST CH-11 A and CH-11 B, in which Operations is reviewing a draft FLC. After teview, Licensing is to issue an FLC, l and the NRC is to approve; 2) Swap leads for DG-1 shutdown solenoid, which is awaiting completion of MWO 941809, scheduled for the next DG-1 outage; 3) Replace FP-156 with new design plug valve, which is awaiting the completion of MR-FC-92-019, scheduled for completion 12/94; and 4) Rubber patch on surface sluice line, which is l awaiting completion of MWO 940774, re-scheduled for 1/23/95, after corps drops nver l level. Currently,1 temporary modification associated with the surface sluice line is over the goal of 6 months. The other 3 are exceptions to the goal as described in letter PED-STE-94-042. At the end of November 1994, there was a total of 28 TMs installed in the Fort Calhoun Station.16 of the 28 installed TMs require an outage for removal and 12 are removable on-line, in 1994 a total of 41 temporary modifications have been installed. t Data Source: Jaworski/rurner (Manager / Source) Accountability: Jaworski/Gorence Adverse Trend: None SEP 62 & 71 i se
~ E TotalModification Padages Open 264 -O Fort CalhounYear-End Goal 250 200 - i 150- } '127 100 o_ '91 '92 '93 Dod3 Jan Feb Mar Apr May Jun Jul Aug sep Oct hc>v94 OUTSTANDING MODIFICATIONS This indicator shows the total number of outstanding modifications (excludina outstand-ina modifications which are oronosed to be sancelled). cataoorv Renortina Month Form FC-1133 Backlog /in Progress 3 Mod. Requests Being Reviewed 2 Design Engr. Backlog /In Progress 27 Construction Backlog /In Progress 20 Dominn Enar. Undata Backloo/in Proerenn 0 Total - 52 At the end of November 1994,20 additional modification requests had been issued this year and 41 modification requests had been cancelled. The Nuclear Projects Review Committee (NPRC) had completed 128 backlog modification request reviews this year. The Nuclear Projects Committee (NPC) had completed 60 backlog modification request reviews this year. The 1994 year-end Fort Calhoun goal for this indicator is a maximum of 80 outstanding modifications. Datta Source: Jaworski/ Turner (Manager / Source) Scofield/Lounsbery (Manager / Source) Accountability: Scofield/Phelps Adverse Trend: None 59
EARO Requiring EngineerinD N Not in Clomeout O DEN E sE 70-60-40-40-40-50-4~ 30-30 - 30-30 - 20-20 - 20-20 -- 10-10-q q 10-10-0 o o o-i i i i i i i r - r-1 Sep Oct Nov Sep Oct Nov Sep Oct Nov Sep Oct Nov 0-3 months 3-6 months 6-12 months >12 months i November '94 Owenfue EARS 3 Closeout (SE) O Engineering Response 80-60-1 40-R R Priority 0 Priority 1 Priority 2 Priority 3 Priority 4 Priority 5 Priority 6 O Priority 1 & 2 E Priority 3 Total Open EARS 200-150-100-Dec93 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov94 D 63 EARS Resolved and in Closeout O 88 Overdue Responses E 61 Overdue Closeouts Q 108 EARS Requiring Respons* g 22 EARS on Schedule 'k 51.5 % + 36.8 %/ [ lll lll 63.2 % 35.7% 12.8 ENGINEERING ASSISTANCE REQUEST BREAKDOWN This indicator shows a breakdown of the number of EARS assigned to Design Engineer-ing and System Engineering. The 1994 year-end goal for this indicator is a maximum of 140 outstanding EARS. Total EAR breakdown is as follows: EARS opened during the month 12 EARS closed during the month 17 Total EARS open as of the end of the month 171 Data Source: Skiles/Mikkelsen (Manager / Source) Accountability: Jaworski/Skiles Adverse Trend: None SEP 62 so i
~. E in DEN - 181 E Ohnths - 280 28.7 .1% O in System Engineering - 10e 34. 1 5 0 34 wnes - 84 I eme notr. - 128 3.1% 3 g,'1% 15 O >s Months - 190 Q in Closecut - 159 ECN STATUS-OVERALL BACKLOG 3 ECNs Bec6 dogged O ECNs Received During the Month G ECNs Completed During the Month 250-E 0-3 Months - 87 ,f26.7% 200-0% O 3-6 Months - 31 '(19 3 150-100-50-O >6 Months-43 Jun94 Jul Aug Sep Oct Nov94 (Year-to-Date monthiy average of ECNs received was 48.1) ECN STATUS - DEN I I 250-200-E 0-3 Months - 26 150-100-1 52.8 % O 34 Months - 8 0 11.1 % i i i i i i Jun94 Jul Aug Sep Oct Nov94 ECN STATUS SE 250-g 3 0-3 Months - 55 100-i 48.4% .0%l O 34 Months - 11 O >s uonths - 82 Jun94 Jul Aug Sep Oct Nov94 8.8% ECN STATUS - PROC /CONSTR 250-g 2@ E 0-3 Months - 112 .0% O 3-s uonths - 34 0 0 >s Months - 47 Jun94 Jul Aug Sep Oct Nov94 ECN STATUS CLOSF.OUT ENGINEERING CHANGE NOTICE STATUS Data Source: Skiles/Mikkelsen (Manager / Source) Accountability: Skiles/Jaworski Adverse Trend: None SEP 62 61
= G SRIType=255 E FC Type - 187 E Priorky 1 & 2 - 111 8 Priorky 3 & 4 -300 i O DC Type - 112 54.2W D Priorty 5 & 6 = 143 TOTAL OPEN ECNS BY TYPE (554 TOTAL) TOTAL OPEN ECNe BY PRIORITY (554 TOTAL) O DEN-Engineering Not Complete E System Engineering - Response, Confirmation Not Complete @ Maintenance / Construction / Procurement -Work Not Complete E DEN Closoout or Drafting Not Complete 213 204 190 130 - 137 p 4 150 - E Priority 1 or 2 @ Pr'ority 3 or 4 100 - 85 50- 'w T O Priority 5 or 6 4g 0-i i Jun94 Jul Aug Sep Oct Nov94 Facility Change ECNs Open 241 247 250 24e 255 13. 250 - E Priorty 1 or 2 68 4. 200-150 - 66 @ Priority 3 or 4 100 - 43 .M O Priority 5 or 6 50-78 V 0-i g 3 Jun94 Jul Aug Sep Oct Nov94 Substitute Replacement item ECNs Open 250 - 200-181 182 188 2.7 E Priority 1 or2 150 - ~ 100 - 46
5. M
@ Priorky 3 or 4 61.6% - y 7 Jun94 Jul Aug Sep Oct Nov94 Document Change ECNs Open ENGINEERING CHANGE NOTICES OPEN I Data Source: Skiles/Mikkelsen (Manager / Source) Accountability: Skiles/Jaworski Adverse Trend: None SEP 62 62 I
@ Administrative Control Problem j O Licensed Operator Error @ Other Personnel Error 2 2 Maintenance Problem 3-E Desion/ Construction / Installation / Fabrication Problem B Equipment Failures 2-1- g g E E 5 E 5 5 0 ,2 Nov93 Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct94 LICENSEE EVENT REPORT (LER) ROOT CAUSE BREAKDOWN This indicator shows the LERs by event date broken down by Root Cause Code for each of the past twehm months from November 1,1993 through October 31,1994. To be consistent with the Preventable / Personnel Error LERs indicator, this indicator is reported by the LER event date, as opposed to the LER report date. The cause codes are intended to identify possible programmatic deficiencies. For detailed desenptions of these codes, see the " Performance Indicator Definitions" section of this report. There was 1 event m October 1994 that resulted in an LER. Data Source: Trausch/Cavanaugh (Manager / Source) Accountability: Chase Adverse Trend: None =
O TotalRequalificationTraining Hours O SimulatorTraining Hours Q Non-RequalificationTraining Hours 50 - E Number of Exam Failures i sg 1 30-20 - 1s 37 ~ 14 14 12 j o*
11 7
10-5 v i 6
s. 5
"/ h 8 7 8 8 8 y ^ 2 2 7 0 i i i i .i e i Cycle 93-7 Cycle 94-1. Cycle 94-2 Cycle 94-3 Cycle 94-4 Cycle 94-5 Cycle 94-6 ' Note 1: The Simulator was out-of-service during Cycle 94-4.

Note 2: Includes 8 hours of General Employee Training.
LICENSED OPERATOR REQUAUFICATION TRAINING This indicator provides information on the total number of hours of training given to each crew during each cycle. The Simulator training hours shown on the graph are a subset of the total training hours. Non-Requalification Training Hours are used for AOP/EOP l verification & validation, INPO commitments, GET, Fire Brigade, Safety Meetings, and l Division Manager lunches. Exam failures are defined as failures in the written, simulator, and Job Performance Measures (JPMs) segments of the Licensed Operator Requalification Training. Rotation 94-6 was the annual Requalification Examination rotation. There were 2 crew simulator failures and 1 written examination failure. The crews that failed the simulator evaluation were remediated without impacting the Operations Department shift sched-ule, as was the individual who failed his written examination. Data Source: Gasper /Guliani (Manager / Source) Accountability: Gasper /Guliani 1 1 Adverse Trend: None SEP 68 l 64 l
l @ SRO Exams Administered O SRO Exams Passed E RO Exams Administered O RO Exams P&ssed j 20-15-10-7 / l-l I? / \\ 7 I I ) l j j 5- ? 3 ? 5 / 1 ? ? ? O DecS3 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov94 LICENSE CANDIDATE EXAMS This indicator shows the number of Senior Reactor Operator (SRO) and Reactor Opera-tor (RO) quines ard exams taken and passed each month. These internally adminis-tered quines and ezams are used to plot the SRO and RO candidates' monthly progress. In November 1994 there were 4 SRO exams administered and all of these exams were 1 passed, in addition, there were 8 RO examinations administered and all of these ex-ams were passed. Data Source: Gasper /Guliani(Manager / Source) i Accountability: Gasper /Guliani Adverse Trend: None SEP 68 65
5 TotalOpen CARS Q TotalOpenIRs D Open CARS > Six Months Old E Open irs > Six Months Old 400- = 400 360-360 320-c - 320 280-280 240-240 l 200-n l -200 120- } l 160-160 l l 120 i l l l l 80 - 3 k:l i l - 80 i b l b ~' l 0 ,0 Dec93 Jan Feb Mar Apr May. Jun Jul Aug Sep Oct Nov94 120-E Open Significant CARS O Open SigniricantiRs 100-so 64 67 69 3 3 3 72 ] 74 80-l g-51 l 40-M- 5 4 6 6 8 7 8 8 7 6 7 7 0 Dec93 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov94 l OPEN CORRECTIVE ACTION REPORTS AND INCIDENT REPORTS This indicator shows the total number of open Corrective Action Reports (CARS), CARS >6 months old, the total number of Open irs, irs >6 months old, the number of open significant CARS and the number of open significant irs. At the end of November 1994 there were 58 open CARS.15 of these CARS were greater than 6 months old. There were 7 Open Significant CARS at the end of the month. Also, at the end of November there were 414 open irs. 231 of these irs were greater than 6 months old. There were 74 Open Significant irs at the end of the month. The 1994 monthly goal for the number of CARS greater than 6 months old is less than 30. Data Source: Orr/Gurtis (Manager / Source) & CHAMPS Accountability: Andrews/Gambhir/ Gates Adverse Trend: Although the number of irs has been increasing, an adverse trend is not indicated because the increase is a result of a revision to Standing Order R-4 that lowers the threshold for writing irs and requires 66 completion of all corrective actions prior to closing irs. I
r: + Engineering Hold -+- Planning Cornplete j -O-Planning Hold Ready -V-- Part Hold Total 850 - 800-750 - 700 - 650 - 600-3 550 - j500-g 450-4: 400 - 3 350 - a ,e 300- f 250 - 200 - N 150 - 100-j v if ~., 50-0 Dec93Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan95 Feb Mar 95 MWO PLANNING STATUS (CYCLE 16 REFUELING OUTAGE) This indicator shows the total number of Maintenance Work Requests (MWRs) and Maintenance Work Orders (MWOs) that have been approved for inclusion in the Cycle 16 Refueling Outage. This graph indicates: Parts Holds (part hold removed when parts are staged and ready for use) Engineering Holds (Engineering hold removed when appropriate engineering paper-work or support is received for the package) Planning Holds (Planning hold removed when planning is completed to the point when package is ready or other support is necessary to continue the planning process) Planning Complete (status given when only items keeping the job from being ready to work are parts or engineering support) Ready (status when all planning, supporting documentation, and parts are ready to go) Data Source: Chase /Schmitz (Manager / Source) Accountability: Chase /Faulhaber AdverseTrend: None SEP 31 67
ll I l! D pR a ie r of t u' e a r 1 W0 t s S oi 0 e o t u h r e O c
r e
Ru V et E J f a ug R aw l A ee 'h o i. L n mEE r n r gS L s /i O P k E R u S D O ta w gs J je e 1 a e E 9 o C r s a T 9 n t d gi t s a 5 S r i OEO O je n ( d T M ao A u h T t t a e. a n a U s A A c c c g a v S jr h t t g e u u e e ( d al al P e /r I C u Y i C C r S p C de o o o o r m m j C pl pl e
r u
o L j E o e e r s 6 pi oi ti c c m t e 1 t o n n s ) l i T L S e R t lc o h a E t n i s F s t a U M M t o o u e E n n s te L y7 I ie t t h h N R e G p O o lr r U t T 5 AG J S E h le E O ) P d 3 a y 1 s i ir
.[ l 1995 0'UTAGE MODIFICATIONS -*-- Baselirw L:hedule for PRC Approval = - Projected / Actual Schedule for PRC Approval g_ Final Design Package issued 5 l Total Modification Packa0es (18) (4 added after 1/14/94) 3 15- "E llllllllllllllllllll: : lllll'llllll*llllllll o e r 10-e e g a E 5-b a g 1 O a o o O iiiiiiiiiiiiiiii4 iiiiiiiiiiiiiiiii iiiieiiiii 5 ! IiiS 1 l le l 1 i 5 5 5 s o PROGRESS OF CYCLE 16 OUTAGE MODIFICATION PLANNING (FROZEN SCOPE OF 13 MODIFICATIONS) This indicator shows the status of modifications approved for installation during the Cycle 16 Refueling Outage. The data is represented with respect to the baseline schedule (established 1/14/94) and the current schedule. This information is taken from the Modification Variation Report produced by the Design Engineering group. In November 1994 no modifications were deleted and none were added. The goal for this indicator is to have all modification packages identified prior to 1/14/94 and PRC approved by October 15,1994. 4 modifications added after 1/14/94 are not included in this performance indicator. The 4 modifications are scheduled and will not impact the 1995 outage. This performance goal was achieved on 9/12/94. Data Source: Skiles/Ronne (Manager / Source) Accountability: Phelps/Skiles Adverse Trend: None SEP 31 69
= 1994 ON-LINE MODIFICATIONS --+-- Baseline Schedule for PRC Approval Projected / Actual Schedule for PRC Approval -- Final Design Package issuoi (7 FD DCPs issued prior to 1/14/94) l20-Total Modification Packages (17) (2 are Close Out Only) (1 Added aflor 1/14/94) g P~ -E
,

;;::::i::::::
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o. @
15 l E 5h-ilt, 0 iiiiiiiiiiiiiiiiiiiii iiiiiiiiiiiii .ii iiii E l l IIl l E 'I s = M M e PROGRESS OF 1994 ON-LINE MODIFICATION PLANNING l (FROZEN SCOPE OF 14 MODIFICATIONS) This indicator shows the status of modfications approved for on-line installation during 1994. The data is represented w!!n respect to the baseline schedule (established 1/14/
94) and the current schedule. This information is taken from the Modification Variance Report produced by the Design Engineeririg Nuclear group.
In jovember 1994 no modifications were deleted and none were added. The goal for this indicator is to have all modification packages identified prior to 1/14/94 and PRC approved by August 15,1994.1 modification was added after 1/14/94 and is not included in this performance indicator. The modification is scheduled and will not impact 1994 on-line construction. All packages, except 1, met the goal of PRC approval by 8/15/94. The package which did not meet the goal was ready for PRC review on 8/11/94. However, unavoidable changes to the package were required, and final PRC approval was completed on 8/29/ 94. Data Source: Skiles/Ronne (Manager / Source) Acccuntability: Phelps/Skiles Adverse Trend: None 70 l
u -a _4 e m. a .aa I l + G ACTION PLANS a } l [ l e 71
ACTION PLANS This section lists action plans that have been developed for the performance indcators - 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 3 consecutive months. in accordance with Revision 3 of NOD-QP-37, the following performance indicators would require action plans based on 3 consecutive months of performance cited as ~ "Needing increased Management Attention": . Unplanned Automatic Reactor Scrams Por 7,000 Critical Hours . Unplanned Safety System Actuations (INPO and NRC) i The Plant Manager and Station Engineering Manager have reviewed the daily and [ ongoing actions being taken to return these performance indicators to meeting the goals. This review indicates appropriate action is being taken and no explicit action plan is required. The action plan for Fuel Reliability Indicator (page 14) follows:
1) The prediction that there is a potential for 1 or 2 defective fuel rods in j
the core is based on a change in the Xe-133 to 1-131 ratio. The power reduction in late October was unable to provide any conclusive data. i ' 2) A specification will be prepared for Ultrasonic Testing / Fuel Sipping during the next refueling outage. . i The action plan for Violations Por 1,000 inspection Hours (page 18) follows:
1) The number of inspections (and thus exposure to potential violations) l currently scheduled for the remainder of the year is much less than the first half of 1994 (SALP period ended 7/31/94). Only the SWOPl and Resident inspections are currently scheduled.

2) Pursuit of Resident inspector concems/ problems / issues will be i
~ thorough to preclude them from becoming violations.
3) Preparation for scheduled inspections (e.g. SWOPI) will be thorough l
and comprehensive. .e t 72 i
!~ ACTION PLANS (continued) The action plan for Thermal Performance (page 32) follows: Actions to improve Thermal Performance are:
1) Backwash durations have been lengthened over the weekends to Improve condenser performance.

2) Investigate the possibility of FW flow nozzle fouling. Test equipment was installed at the beginning of October.
I
3) Investigate the effects of adding Ethanolamine to secondary chemistry to clean system and possibly reduce S/G blowdown.
1 I i 5 i I f 73 I
PERFORMANCE WDICATOR' DEFNTIONS L AUXIUARY PEEDWATER SYSTEM SAFETY SYSTEM CENTS PER IGLOWATT HOUR PERF0fEAANCE The purpose of thir indmator is to quantNy the economi- _j The sum of the known (planned and unplanned) unavail-caloperskion of FJrt Calhoun Station. The cents per i able hours and the estimated unavailable hours for the knowatt hour indicator represents the budget and actual auxiliary feedwater system for the reporting period di-cents por lulowatt hour on a 12 month roNin0 avera0e for vided by the critical hours for the reporting period multi-the current year. The basis for the budget curve is the plied by the number of trains in the auxiliary foodweier approved 1993 budget. The basis for the actual curve is system. the Financial and Operating Report CNECK VALVE FAILURE RATE CLEAN CONTROLLED AREA CONTAINAATIONS %9p the Foet Calhoun check valve failure rate to 21,000 DISSITEGRATlONS/BANUTE PER PROBE the industry check valve failure rate (failures per 1 million AREA component hours). The data for the industry failure rate The personnel contamination events in the clean con - is three months behind the PI Report reporting month-trol led area. This indicator tracks personnel perfor-This indicator tracks performance for SEP 843. mance for SEP #15 & 54. COLLECTWE RADIATION EXPOSURE CONTARBNATED RADIATION CONTROLLED AREA Conective radiation exposure is the total extemal whole-The percentage of the Radation ControNed Area, which - body dose received by all on-site personnel (including includes the auxHiery building, the radwaste building, and contracsors and visitors) during a time penod, as mea-areas of the C/RP building, that is contaminated based sured by the thermoluminescent dosimeter (TLD). Col-on the total square footage. This indicator tracks perfor-lective radetion exposure is reported in units of person-mance for SEF # 54. rom. This indicator tracks radological work performance for SEP e64. DAILY THERRAAL OUTPUT This indiamor shows the daily core thermal output as Cotr0NENT FAILURE ANALYSIS REPORT (CFAR) measured from computer point XC105 (in thermal mega-SURAAARY watts). The 1500 MW Tech Spec limt, and the unmet i The number of INPO categories for Fort Calhoun Station portion of the 1495 MW FCS daHy goal for the reporting j wth significantly higher (1.645 standard deviations) faH-month are also shown. ute rates than the rest of the industry for an eighteen month time period. Failures are reported as component DOESEL GENERATOR REUABluTY (25 DERAANDS) l (i.e. pumps, motors, valves, etc.) and appication (i.e. This indicator shows the number of failures occurrin0 or f i charging pumps, main steam stop valves, control el*- each emergency diesel generator during the last 25 start j ment drive motors, etc.) categories. demands and the last 25 load-run demands. FaHure Cause Categories are: ) Wear Out/ Aging a faHure thought to be the cons *- D6SABlaeG SWURY/ ILLNESS FREQUENCY RATE quence of expected wear or aging. (LOSTTBE ACCIDENTRATE) I Manufactusing Defect - a failure attributable to inad-This indmetor is defined as the number of accidents for equate assembly or initial quality of the responsbie com-aN utiky personnel permanently assigneed to the station. ponent or system. involving days away from work per 200,000 man-hours Engineering /Deeegn - a failure attrbutable to the inad-worked (100 man-years). This does not include contrac-equate design of the resportsible component or system. tor personnel. This indicator tracks personnel perfor-j Other Devices - a faHure attributable to a faRure or mance for SEP #25 & 26. misoperation of another component or system, including aaeas eed devices DOCUBAENT REVIEW (BIENDSAL) Maintenance / Testing a failure that is a resuk of im-The Docuraent Review Indicator shows the number of proper maantonance or testing, lack of maintenance, or documents reviewed, the number of documents sched-- l personnel errors that occur during maintenance or test-uled for review, and the number of document reviews l ing activities performed on the responsible component or that are overdue for the reporting month. A document system, including failure to follow procedures. renew is considered overdue if the revow is not com-Errors - failures attributable to incorrect procedures that plate within 6 months of the assioned due date. This were fonowed as written, improper installation of equip-indicator tracks performance for SEP #46. ment, and personnel errors (including failure to fonow / l-procedures property). Also included in this category are ERERGENCY AC POWER SYSTEM SAFETY SYSTERA failures for which the cause is unknown or cannot be as-PERFORRAANCE i signed to any of the proceding categories. The sum of the known (planned and unplanned) unavaN-l able and the estimated unavaHable hours for the emer-l goney AC power system for the reporting penod dnnded i by the number of hours in the reporting period multiolied by the number of trains in the emergency AC power sys-l tom. ? I 74
PERFORMANCE MDICATCR DEFINITIONS BERGENCY DIESEL GENERATOR UNIT RELIABIL-BERGENCY DIESEL GENERATOR UNRELIABILITY ITY This indmetor measures the total unreletzlity of emer. This indcator shows the number of fauures that were gency diesel generators. In general, unreliability is the reported during the last 20,50, and 100 emergency de.- ratio of ur-===ful operations (starts or load-runs) to nel generator demands at the Fort Calhoun Station. Also the number of valid demands. Total unreliabuty is a ehoa n are trigger values which correlate to a high level combmahon of start unrelebHNy and load-run of confidence that a unit's diesel generators have ob-unrelebility. tained a reliabuity of greater than or equal to 95% when the demand failures are less than the trigger values. < ASSISTANCEREQUEST(EAR)
1) Number of Start Demands: AN valid and inadvertent BREAMDOWN start demands, including all start only demands and all This iruhcator shows a breakdown, by age and priority of start demands that are followed by load-run demands, the EAR, of the number of EARS assigned to Design En-whether by automate or manualinitiation. A startenly gineenng Nuclear and System Engineering. This indica-demand is a demand in which the emergency generator tor trads performance for SEP #62.
is started, but no attempt is made to load the generator.
2) Number of Start FaNures: Any failure within the emer.
ENGINEERING CHANGE NOTK:E (ECN) STATUS gency generator system that prevents the generator from The number of ECNs that were opened ECNs that were achieving specNied frequency and voltage is classified as wnC 1, and open becklog ECNs awaiting completion a valid start failure. This includes any condition identified by DEN for the reporting month. This indicator tracks in the course of maintenance inspedions (with the emer-performance for SEP #62. gency generator in standby mode) that definitely would have resuhed in a start failure if a demand had occurred. ENGINEERB4G CHANGE NOTICES OPEN
3) Number of Load-Run Demands: For a valid load-run This indicator breaks down the number of Engineering demand to be counted the load-run attempt must meet Change Notees (ECNs) that are assioned to Design one or more of the following criteria:
Engineering Nuclear (DEN), System Engineering, and A) A load-run of any duration that results from a real au-Maintenance The graphs provide dets m ECN Facility tomatic or manualinitiation. Changes open. ECN Substitute Replacement Parts -
8) A lood-run test to satisfy the plant's load and duration open, and ECN Document Changes open. This indicador as stated in each test's specifications.
tracks performance for SEP #62. C) Other special tests in which the emergency generator is expected to be operated for at least one hour while EOUlFRENT FORCED OUTAGES PER 1,000 CRITl-loaded with at least 50% of its design load. CAL HOURS
4) Number of Load-Run Failures: A load-run failure Equipment forced outages per 1000 critical hours is the should be counted for any reason in which the emer-inverse of the mean time between forced outa0es gency generator does not pid up load and run as pro-caused by equipment failures. The mean time is equal dicted. FaHures are counted during any valid load-run to the number of hours the reactor is critical in a period demands.
(1,000 hours) divided by the number of forced outages
5) Exceptions: Uns-aaful attempts to start or load-run caused by equipment failures in that period.
should not be counted as valid demands or failures when they can be attributed to any of the followm9' EQUIVALENT AVAILABILITY FACTOR A) Spurious trips that would be bypassed in the event of This indicator is defined as the ratio of gross available an emergency. generation to gross maximum Cone ation, expressed as B) Malfunction of equipment that is not required during a percenta0s. Available generation is the energy that an emergency. can be produced if the unit is operated at the maximum C)Intentionaltermination of a test because of abnormal power level permitted by equipment and regulatory limi-conditions that would not have resulted in major diesel tations. Maximum generation is the energy that can be generator dama0e or repair, produced by a unit in a given period if operated mntino-D) Malfundions or operating errors which would have not ously at maximum capacity, prevented the emergency generator from being restarted and brought to load within a few minutes. FORCED OUTAGE RATE E) A failure to start because a portion of the starting sys-This indicator is defined as the percentage of time that tem was disabled for test purpose, if followed by a suc-the unt was unavaHable due to forced events compared cessful start with the etatting system in its normal align-go the time planned for electrical generation. Forced ment. events are failures or other unplanned conditions that Each emergency generator failure that results in the gen-require removing the unit from service before the end of orator being declared inoperable should be counted as the next weekend. Forced events include start-up fail-i one demand and one failure. Exploratory tests durin0 pres and events initiated while the unit is in reserve shut-I corrective maintenance and the successful test that foi-down (i.e., the unit is available but not in service). lows repair to verify operability should not be counted as f demands or f ailures when the EDG has not been de-l clared operable again. I 75
PERFORMANCE INDICATOR DEFINITIONS FUEL REuASEJTy MDICATOR ucENSE CANDIDATE EXARIS This indiator is dehned as the steady-state primary cool-This indecator shows the number of SRO andApr RO quiz-ant 1-131 activity, corrected for the tramp uranium contri-zes and exams that are admitustered and passed each buten and normalized to a common purification rate. month This indicator tracks training performance for Tramp uranium is fuel which has been dar=awon re-SEP #88. actor core intamals from previous deledive fuel or is present on the surface of fuel elements from the menu. s ar ssaasn OPERATOR REQUAUF9 CATION TRAM. facturing process. Steady state is defined as continuous MG l operation for at least three days at a power level that The total number of hours of training given to each crew ~ does not very more than + or - 5%. Plants should collect during each cycle. Also provided are the simulator train ~
t data for this indcator at a power level above 85%, when ing hours (which are a subset of the total training hours),
f===h Plants that did not operate at steady-state the number of non-requalificaton training hours and the i power above 85% should coned data for this indicator at number of exam failures. This indicator trads training the highest steady-state power level astamed during the performance for SEP #68. month The density correction factor is the ratio of the spedfic UCENSEE EVENT REPORT (LER) ROOT CAUSE ] volume of coolant at the RCS operating temperature BREAKDOWN i (640 degrees F., Vf = 0.02146) dwided by the specific This indicator shows the number and root cause code for volume of coolant at normal letdown temperature (120 Licensee Event Reports The root cause codes are as j degrees F at outlet of the letdown cooling heat ex-follows-i changer, VI - 0.016204), which results in a density cor-
1) Administrative Control Problem - Management end rection factor for FCS equal to 1.32.
supervisory deficiencies that affect plant programs or activities (i.e., poor planning, breakdown or lad of ad-GROSS HEAT RATE equate management or supennsory control, incorrect Gross heat rate is defined as the ratio of total thermal procedures, etc.) energy in British Thermal Units (BTU) produced by the
2) Licensed Operator Error - This cause code captures
{ reactor to the total gross electrical energy produced by errors of omission / commission by bconsed reactor opera-l the generator in idiowatt-hours (KWM). tors during plant actwetes j
3) Other Personnel Error - Errors of omissiorvoommis-t HAZARDOUS WASTE PRODUCED sion committed by non-licensed personnel involved in The total amount (in Kilograms) of non-halogenated haz-plant adivities.
ardous waste, halogenated hazardous waste, and other
4) Maintanance Problem - The intent of this cause hazardous waste produced by FCS oach month.
code is to capture the full range of problems which can i be attributed in any way to programmatic deficiencies in HIGH PRESSURE SAFETY INJECTION SYSTEM the maintenance functonal organization. Activities in. 1 SAFETY SYSTEld PERFORMANCE ciudad in this category are maintenance, testing, surveil-i The sum of the known (planned and unplanned) unavail-lance, cahbraton and radiation protection. l able hours and the estimated unavailable hours for the
5) DesigrVConstructiorvinatallatiorvFabricaten Problem I
high pressure safety injection system for the reporhng - This cause code covers a fun range of programrnatic period dwided by the critical hours for the reporting po-dehciencies in the areas of design, construdion, mstaBa-riod muniplied by the number of trains in the high pres-tion, and fabricaten (i.e., loss of control power due to sure safety injection system. underrated fuse, equipment not qualified for the envron-ment, etc.). l WDUSTRIAL SAFETY ACCIDENT RATE-INPO
6) Equipment Failures (Electronic Piece-Parts or Envi-This indicator is defined as the number of accidents por ronmental-Related Failures) - This code is used for spuri-l 200,000 man-hours worked for aN utilky personnel per-ous failures of electronic piece-parts and fatures due to l
manently assigned to the station that resuk in any of the meteorological conditions such as lightning, ice, high following 1) one or more days of restricted work (ex-winds, etc. Generally, it includes spunous or one-time ciuding the day of the accident); 2) one or more days failures Electric components included in this category i away from work (excluding the day of the accident); and are drcuit cards, rectifiers, betables, fuses, capacitors,
3) fatalkies. Contractor personnel are not included for diodes, reestors, etc.
l this indicator. } LOGGABLE4tEPORTABLE MCIDENTS (SECURfTV) W-LSdE CHERESTRY MSTRUMENTS OUT OF SER-The total number of security incidents for the reporting VICE saonth depided in two graphs. This indicator trads so-Total number of in-line chemistry instruments that are curty performance for SEP #58. l out of-service in the Secondary System and the Post j Accident Sampling System (PASS).~ MAINTENANCE OVERTBAE The % of overtime hours compared to normal hours for maintenance. This includes OPPD personnel as well as contract personnel. 76 i r - -,-_...._..__- -._ - -,, ~
' PERFORMANCE MDICATOR DEFINITIONS eldMNTENANCE WORROAD BACROGS NUMSER OF CONTROL ROOM EQUN' MENT DEFl- . This indsoetor shows the backlog of non outage Maint*- CIENCES nonce Work Orders romaning open at the and of the A control room equipment deficiency (CRD)is defined as reportmg month. Maintenance classificatons are de-any component which is operated or controued from the fined as: Control Room, pmvides indication or alarm to the Control Room, provides testing capabilties from the Control Corrective Repair and restoration of equipment or com. Room, provides automatic actens from or to the Control ponents that have failed or are maNunctioning and are Room, or provides a passive funchon ior the Control not performing their intended function. Room and has been identified as deficient, i.e., does not poderm under aN condtions as designed. This definition Proventive - Actions taken to maintain a piece of equip-also apphes to the Altomate Shutdown Panels Al-179, ment within design operating conditions, prevent equip-Al-185, and Al-212. ment faRure, and extend its life and are performed prior A plant component which is dehcient or inoperable is to equipment failure. considered an ' Operator Work Around (OWA) Item" if some other action is required by an operator to compen-Non-Corrective / Plant improvements - Maintenance ac. sale for the condsten of the component. Some examples i tivities performed to implement station improvements or of OWAs are: 1) The control room level indicator does to repair non-plant equipment. not work but a local sightglass can be read by an Opera-tot out in the plant; 2) A deficient pump cannot be re-i Maintenance Work Prerses are defined as: paired because replacement parts require a long lead time for purchase /deirvery, thus requiring the redundant [ Emergency - Condaens whch significantly degrade sta. pump to be operated continuously; 3) Special actions tion safety or avadabday are required by an Operator because of equ' ment de-p sign problems. These actions may bu described in Op-Immediate Action Eeuomere defeiencies which signifi. erations Memorandums Operasor Notes, or may require cantly degrade etston reliatadey Potential for unit shut-changes to Operating Procedures. 4) Deficient plant l down or power rarbr* an equipment that is required to be used during Emergency i Operating Procedures or Abnormal Operating Proco-i Operations Concern - [oupmere defeiencies which dures. 5) System indication that provides critical infor-i hinder station oporaten mation during normal or abnormal operations. Essential-Routee conect ve masteenance on essential NUBASER OF BSSSED SURVEILLANCE TESTS RE-station systems and segment SULT54G Bd LICENSEE EVENT REPORTS The number of Surveillance Tests (STs) that result in Non-Essential Roueno conecove maintenance on non-Licensee Event Reports (LERs) during the reporting essential staten sysaems eruf soupment month This indicator tracks missed STs for SEP #60 & 61. Plant improvemers hoa conectsve maintenance and plant improvemeros OPEN CORRECTWE ACTION REPORTS & INCIDENT REPORTS This indcator tracas marwenance pedormance for SEP This indicator displays the total number of open Correc-l
36.
tive Acton Reports (CARS), the number of CARS that are older than six morths and the number of open significant i' MAXIMUM DdDIVIDUAL RADIATtON EXPOSURE CARS. Also displayed are the number of open incident The total masvnum amow o resalon received by an Reports (irs), the number of irs that are greater than six r individual person wo*ng at F CS on a monthly, quarterly, months old and the number of open significant irs. and annual besse OUTSTANDING MODIFICATIONS MWO PLmeepeG STATUS (CYCtX 16 REFUELN4G The number of Modificaten Requests (MRs) in any state OUTAGE) between the issuance of a Modification Number and the The total number of Meree6enos Work Orders that have completion of the drawing update. been approved tor ecwuon e the Cycle 15 Refueling
1) Form FC-1133 Baddog/in Progress. This number rep-
? Outage and the tweer that are ready to' work (parts resents modification requests that have not been plant staged, planning comspese. and all other paperwork approved during the reporting month. ready for fold use) Aaeo ecuded is the number of
2) Modification Requests Being Reviewed. This category MWOs that have eng***'mG holds (ECNs, procedures includes:
and other misceaaneous engmeerng holds), parts hold, A.) Modification Requests that are not yet reviewed j (parts staged, not yet nopected, pans not yet arrived) B.) Modification Requests being reviewed by the Nuclear ^ and planning hold (pob scopo not yet completed). Main-Projects Review Committee (NPRC). tenance Work Requests (WWRs) are also shown that C.) Modificaten Requests being rev'ewed by the Nuclear have been identifed for the Cycle 15 Refueling Outage Projects Committee (NPC) and have not yet been converted to MWOs. These Modification Requests may be reviewed several i times before they are approved for accomplishment or 77
PERF@RMANCE INDICATOR DERNITIONS canooted. Some of thase Modification Requests are years of the " Event Date* specified in the LER (e.g., an retumed to Engineering for more information, some ap-event for which the cause is attributed to a problem with pmved for evaluation, some approved for study, and the original design of the plant would not be considered some appmved for planning. Once pionning is com-preventable). pisted and the scope of the work is clearly defined, those For purposes of LER ovent classificahon, a " Personnel Modficaten Requests may be approved tot accompinh-Error" LER is defmed as it,ilows An event for which the i ment wkh a year assigned for constructen or they may root cause is inappropriate acton on the part of one or be cancelled. Allof these different phases require re-more individuals (as opposed to being attrbuted to a de-vie,v. partment or a general gmup). Also, the inappropriate
3) Design Engineering Backlog /In Progrees. Nuclear action must have occurred within approximdely two
l Planning has assioned a year in which construction will years of the

Event Date" specNied in the LER.
be w,,T-;'-M and design work may be in progress. ^ '~ d';, each event classified as a
Personnel Error"
4) Construction Backlo0/in Progress. The Constructen should also be clansified as " Preventable
This indicator Package has been issued or construction has begun but trends personnel periormance for SEP hem #15.
the modification has not been accepted by the System Acceptance Committee (SAC). PR18AARY SYSTEM CNERESTRY % OF NOURS OUT l
5) Design Engineering Update Bacidog/in Progress. PED OFUIST has received the Modificaton Completon Reprt but the The % of hours out of limit are for six primary chemistry drawings have not been updated.
parameters divided by the total number of hours possble The above mentoned outstanding modif' ations do not for the month.' The key parameters used are: Lithium,. c Include modifications which are proposed for cancella-Chloride, Hydrogen. Dissolved Oxygen Fluoride and tion. Suspended Solids. EPRIlimits are used. OVERALL PROJECT STATUS (REFUELING OUTAGE) PROCEDURAL NONCOR58f LANCE INCIDENTS This indicator shows the status of the projects which are (RSANTENANCE) in the scope of the Refueling Outage The number of identified incidents concerning mainte-nance procedural problems, the number of closed irs PERCENTAGE OF TOTAL MWOs COMPLETED PEft related to the use of procedures (includes the number of ROONTH IDENTIFIED AS REWORK closed irs caused by procedural noncompliance), and r The percenta0e ol lotal MWOs w,,TCed per rnonth the number of closed procedural nor compliance irs. idemified as rework. Rework activities are identified by This indicator trends personnel performance for SEP maintenance planning and craft. Rework is: Any main-
15,41 & 44.
tenance work repeated to correct a deficiency which has re-occurred within 60 days following similar work activi-PROGRESS OF CYCLE 16 OUTAGE RAODIFICATION ties. Any additional work required to correct deficiencies PLAIGGNG (FROZEN SCOPE OF 15 MODIFICA-discovered during a failed Post Maintenance Test to on-TIONS) sure the component / system passes subsequent Post This indicator shows the status of modifications ap-Maintenance Tests. This definition can be found in S. O. proved for completion during the Refueling Outage M-101. PROGRESS OF 1994 ON LME RAODIFICATlON PLAN. I PERCENT OF CORAPLETED SCNEDULED RAAINTE-IGNO (FROZEN SCOPE OF 14 RAODIFICATIONS) NANCE ACTIVITIES This indicator shows the status of modifications ap-i The % of the number of completed maintenance activi-proved for corupletion during 1994. ties as compared to the number of scheduled mainte-nance activities each month. This % is shown for all RADIOLOGICAL WORK PRACTICES PROGRAM maintenance crafts. Also shown are the number of The number of identified poor radiologeal work practicos emergent MWOs. Maintenance activities include MWRs, (PRWPs) for the reporting month. This indicator trads MWOs, STs, PMOs, calibrations, and other miscella-radiological work performance for SEP #52. neous activities. This indicator trads Maintenance per-formance for SEP #33. RATIO OF PREVENTIVE TO TOTAL RIAINTENANCE & PREVENTIVE BAAINTENANCE ITEMS OVERDUE PREVENTABLE / PERSONNEL ERROR LERe The ratio of preventive maintenance (including survoih This indicator is a breakdown of LERs. For purposes of lance testing and calibration procedures) to the sum of LER event dassification, a preventable LER is defined non outage corrective maintenance and preventive main-as: An event for which the root cause is personnel error tenance completed over the reporting period. The ratio, (i.e., inappropriate action by one or more individuals), expressed as a percentaoe, is calculated %d on man-inadequate administrative controis, a design /construc-hours. Also displayed are the % of preveA Minte-tiorvinstaRation/labncation problem (involving work com-nance items in the rnonth that were not conped or ad-pisted by or supervised by OPPD personnel) or a main-ministratively closed by the scheduled date plus a grace tenance problem (attributed to inadequate or improper period equal to 25 % of the scheduled interval. This indi-upkeep / repair of plant equipment). Also, the cause of cator tracks preventive maintenance activities for SEP - the event must have occurred within approximately two
41.
78 l
PERFORMANCE BIDICATOR DEFINITIONS RECORDASLE MJURYALLNESS CASES FRE-SIGIGFICANT EVENTS The number of injuries requiring more than normal first. Significant events are those events identdied by NRC OUENCY RATE staff through detaued screening and evaluation of operat-aid per 200,000 man-hours worked This indcator ing experience The screening process includes the trends personnel performance for SEP #15,25 & 26. daily review and dimenaalant of all reported operating re-actor events, as wel as other operatonal data such as REPEAT FAILURES special tests or construction activities. An event idente-The number af Nuclear Plant Reliability Data Spbm fied from the screening process as a significant event . (NPRDS) components with more than 1 failure and the candidate is further evaluated to determine if any actual number of NPRDS components with more than 2 failures or potential threat to the health and salsty of the public - for the eighteen month CFAR penod, was involved Specinc examples of the type of criteria are summarized as follows 1) Degradation of important SAFETY SYSTEM FAILURES safety equ5 ment; 2) Unewpar*=d plant response to a Safety system failures are any events or conditons that trenesent: 3) Degradation of fuel integrty, primary cook could prevent the fulfillment of the salsty functions of ant pressure boundary, important===aci= sad features; - strudures or erstems. If a system consists of mukiple
4) Scram with complicaton; 5) Unplanned release of redundant subsystems or trains, failure of al trains con-radioactivity; 6) Operation outside the limts of the Tech-situtes a safety evstem failure. Failure of one of two or nicalSpecircations: 7) Other.
more trains is not counted as a safety system failure. INPO significant events reported in this indicator are The definition for the Iruheator parallels NRC reporting SERs (Significant Event Reports) which inform utuities of requirements in 10 CFR 50.72 and to CFR 50.73. The significant events and lessons loamed identified through following is a list of the major safety systems, sub-the SEE-IN screening process systems, and components monitored for this iruhcalor. Accident Monitoring instrumentation, Auxaiary (and SPARE PARTSINVENTORY VALUE Emergency) Feedwater System, Combustble Gas Con-The donar value of the spare parts inventory value for trol, Component Cooling Water System, Contairment FCS during the reporting period. and Containment isolation Containment Coolant Sys-tems, Control Room Emergency VentHation System, STAFFING LEVEL Emergency Core Coohng Systems, Engineered Safety The actual staffing level and the authorized staffing level Features instrumentation, Essential Compressed Air for the Nuclear Operations Division, the Production Engi-Systems, Essential or Ernargency Service Water, Fire neering Divison, and the Nuclear Services Division. This Detechon or Suppression Systems, isolation Condenser, indcator tracks performana for SEP #24. Low Temperature Overpressure Protection, Main Steam Line loclation Valves, Onske Emergency AC & DC STATION NET GENERATION Power w/ Distribution, Radiation Monitoring Instrumenta-The not generation (sum) produced by the FCS during tion, Reactor Coolant System, Reactor Core isolation the reporting month. Coohng System, Reactor Trip System and instrumenta-tion, Recirculation Pump Trip Actuation Ir.strumentation, TEMPORARY MODIFICATIONS Residual Heat Removal Systems, Safety Valves, Spent The numeer of temporary mechanical and electrical con-Fuel Systems, Standby Liquid Control System and Ulti-figurations to the plant's systems, mate Heat Sink.
1) Temporary configurations are dehned as electrical jumpers, etectrical blods, medanical jumpers, or me-SECONDARY SYSTEM CHERS$TRY PERFORMANCE chanirW blods which are instaRed in the plant operating l
MDEX systems and are not shown on the latest revision of the The Chemistry Performance index (CPI) is a calculation PalD, schematic, connecton, wiring, or flow diagrams. based on the concentration of key impurities in the sec.
2) Jumpers and blocks which are installed for Surveil-
) l ondary side of the plant. These key impurities are the lance Tests, Maintenance Procedures, Calibration Pro-1 most kkely rause of deterioration of the steam genera-cedures, 9arial Procedures, or Operating Procedures tors. Critoria int calculating the cpl are: 1) The plant is are not considered as temporary modifications unless the l at greater than 30 percent power; and 2) The power is jumper or block remains in place after the test or proco-changing less than 5% per day. The cpl is calculated dure is complete. Jumpers and blocks installed in test or using the followmg squation: cpl. (sodiunVO.90) + lab instruments are not considered as temporary modifi-(Chloride /1.70) + (Sulfals/1.90) + (Irort'4.40) + (Copper / cations. j 0.30)/5. Where: Sodium, suNato and chloride are the
3) Scaffolding is not considered a temporary modifica-montNy ave'ege blowdown concentrations in ppb, iron tion Jumpers and blods which are installed and for and copper are monthly time weighted average which MRs have been submitted win be considered as feedwau concentrations in ppb. Tne denominator for temporary modifications until final resolution of the MR oaco of the 5 fadors is the if 4PO median value. If the and the jumper or blod is removed or is permanently monthly average for a specifh parameter is less than the recorded on the drawings. This indicator tracks tempo-INPO median value, the median value is used in the cal-rary modifications for SEP #62 & 71, culation.
I 79
PERFORMANCE INDICATOR DEMNITIONS j THEfM4AL PERFOfM4ANCE UNPLAletED SAFETY SYSTEM ACTUATIONS -(NPO The ratio of the deenrjn gross heat rate (corrected) to the DEPMITION) adjusted actual go.,s heat rate, expressed as a percent-This indicator is defined as the sum of the followng safety j age. system actuatens.
1) The number of unplanned Emergency Core Coolmg UNIT CAPABlUTY FACTOR System (ECCS) actuations that result from readiing an The ratio of the avaRable energy generation over a given ECCS actuation seapoint or from a spuriouslinadvertent time period to the reference energy generation (the on-ECCS signal orgy that could be produced if the unit were operated

2) The number of unplanned emergency AC power system.
continuously at fur power under reference ambient con-actuatens that result from a loss of power to a safeguards ditions) over the same time period, expressed as a per-bus. An unplanned salety system actuation occurs when contage. an actuation setpoint for a sdely system is reached or when a spurious or inadvertent signal is generated (ECCS l UDST CAPACITY FACTOR only), and major equipment in the system a actuated. l The not eledrical energy generated (MWH) divided by Unplanned means that the system aduation was not part ) the product of maximum dependable capar*y (not MWe) of a planned test or evolution. The ECCS actuations to be times the gross hours in the reportmg period expressed counted are actuations of the high pressure injection sys-as a percent. Not electrical energy generated is the tem, the low pressure injection system, or the safety injec-gross electricaloutput of the unit measured at the output tion tanks.- 3 terminals of the turbine generator minus the normal sta-tion sonnes loads during the gross hours of the reporting UNPLAfG4E0 SAFETY SYSTEM ACTUATIONS (NRC I period, expressed in megawatt hours. DEFMITION) The number of safety system actuations which include UNPLANNED AUTOMATIC REACTOR SCRAAAS PER (enk) the High Pressure Safety injection System, the Low 7,000 CRITICAL HOURS Pressure Safety injection System, the Safety injection This indicator is defined as the number of unplanned au-Tanks, and the Emergency Diesel Generators. The NRC tomatic scrams (reactor protection system logic actua-classification of safety system actuations includes actua. l tions) that occur por 7,000 hours of critical operation. tions when major equipment is operated mod when the i The value for this indicator is calculated by multiplying logic systems for the above safety systems are chal-the total number of unplanned automatic reactor scrams longed .) in a specific time period by 7,000 hours, then dividing i that number by the total number of hours critical in the VIOLATIONS PER 1,000 INSPi:CTION HOURS same time period. The indicator is further defined as This indicator is defined as the number of violations sited follows: in NRC inspection reports for FCS per 1,000 NRC inspec-
1) Unplanned means that the scram was not an antici-tion hours. The violations are reported in the year that the j
pated part of a planned test. inspection was actually performed and not based on when
2) Scram means the automatic shutdown of the reactor the inspection report is received. The hours reported for by a rapid insertion of negative reactivity (e.g., by control each inspecten report are used as the inspection hours.
rods, liquid injection system, etc.) that is caused by ac-tuation of the reactor protection system. The scram sig-VOLURE OF LOW-LEVEL SOLID RADIOACTIVE nal may have resulted from exceeding a setpoint or may WASTE have been spurious. This indicator is defned as the volume of low-level solid
3) Automatic means that the initial signal that caused radioactive waste actually shipped for burial. This indica-actuation of the reactor protection system logic was pro-tor also shows the volume of low-level radioactive waste e
vided from one of the sensors monitoring plant param-which is in temporary storage, the amount of radioactrve eters and conditions, rather than the manual scram oH that has been shipped off-site for processing, and the switches or, in manual turbine trip switches (or push-but-volume of solid dry radioactive waste which has been tons) provided in the main control room. shipped off-site for processing. Low-level solid radioactrve
4) Critical means that during the steady-state condition of waste consists of dry active waste, sludges, resins, and l
the reador prior to the scram, the effective multiplication evaporator bottoms gerTrated as a result of nuclear power factor (k,) was essentiaRy equal to one. plant operation and maintenance. Dry radioadive waste t includes contaminated rags, cleaning materials, dispos-UNPLANNED CAPABluTY LOSS FACTOR able protective clothing, plastic containers, and any other The ratio of the unplanned energy losses during a given material to be disposed of at a low-level redcactive waste period of time, to the reference energy generation (the disposal site, except resin, sludge, or evaporabr bottoms. onergy that could be produced if the unit were operated Low-level refers to au radioactive waste that is not spent [ continuously at fun power under reference ambient con. fuel or a by-product of spent fuel processing. This indica-ditions) over the same time period, expressed as a per-tor tracks radiologeal work performance for SEP #54. contage. 1 f 1 I
SAFETY ENHANCEMENT PROGRAM INDEX. l The purpose of the Safety Enhancement Program (SEP) Performance indicators Index is to list perfor-mance indicators related to SEP llems with parameters that can be trended 4 i SEP Reference Number 15 P.aoa i I increase HPES and IR Accountability Through Use of Performance Irdcators Procedural Noncompliance incidents (Maintenance)........................................................... 50 Clean Controlled Area Contaminations 21,000 Disintegrations / Minute Per Probe Area............... 5 Recordable injury / Illness Cases Frequency Rate.............................................................. 4 Proventabio/ Personnel Error LERs........................................................................................... 6 SEP Reference Number 24 Complete Staff Studies S;affing Level ...................................................................................................43 SEP Reference Number 25 Training Program for Managers and Supervisors implemented Disabling injury / Illness Frequency Rate...... .............................3 Recordable injury / Illness Cases Frequency Rate................................................ ..........4 SEP Reference Nurnbar 26 Evaluate and implement Station Standards for Safe Work Practice Requirements Disabling injury / Illness Frequency Rate............ ................................................3 Recordable injury /lliness Cases Frequency Rate....................................................... 4 e : SEP Reference Number 27 Implement Supervisory Enforcement of Industrial Safety Standards 1 Disabling injury / Illness Frequency Rate................................................................... 3 Recordable injury / Illness Cases Frequency Rate......................... ...............................4 SEP Reference Number 31 Develop Outage and Maintenance Planning Manual and Conduct Project Management Training MWO Planning Status (Cycle 16 Refueling Outage)......................... ... 67 Overall Project Status (Cycle 16 Refueling Outage)................................................... 68 Progress of Cycle 16 Outage Modification Planning. ..............................................69 SEP Reference Number 33 Develop On-Line Maintenance and Modification Schedule i Percent of Completed Scheduled Maintenance Activities (All Maintenance Crafts).................................................. ............. 51 SEP Reference Number 36 l noduce Corrective Non-Outage Backlog Maintenance Workload Backlogs (Corrective Non-Outage)...... . 46 i, SEP Reference Number 41 Develop and implement a Preventive Maintenance Schedule 3 r Ratio of Preventive to Total Maintenance & Preventive Maintenance items Overdue............ 47 Procedurtai Noncompliance incidents...... .................-...............................................50 i SEP Reference Number 43 Implement the Check Valve Test Program 7 Check Valve Failure Rate.......... _................................ .............................37 ) 81 l t
SAFETY ENHANCEMENT PROGRAM INDEX (::cntinued) SEP Reference Number 44 Eagg Compliance With and Use of Procedures Procedural Noncompliance incidents (Maintenance)............................................................. 50 SEP Referenca Number 48 Design a Procedures Control and Administrative Program a - Docurnent Review............................................................................ -............................... 56 i SEP Rafarance Number 52 Establish Supervisory Accountability for Workers Rad.0 logical Prac*)ces Radiological Work Practices Program....................................................................... 55 SEP Reference Number 54 Complete implementation of Radiological Enhancement Program Collective Radiation Exposure.......................................................................................... 16 Volume of Low-Level Solid Radioactive Waste................................................................. 38 i Clean Controlled Area Disintegrations 21,000 Counts / Minute Per Probe Area,............. ........5 Contaminated Radiation Controlled Area............................ ......................................54 j SEP Reference Number 58 Revise Physical Security Training and Procedure Program Loggable/ Reportable incidents (Security)......................................................................... 57 SEP Reference Number 80 improve Controls Over Surveillance Test Program Number of Missed Surveillance Tests Resulting in Licensee Event Reports............................. 20 ' SEP Reference Number 81 Modify Computer Program to Correctly Schedule Surveillance Tests Number of Missed Surveillance Tests Resulting in Licensee Event Reports.............................. 20 l SEP Reference Number 82 Establish interim System Engineers Temporary Modifications.................................................................................................... 58 Engineering Assistance Request (EAR) Breakdown......................................................... 60 Engineering Change Notice Status.............. ..............................................................61 Engineering Change Notices Open...................................................................... 62 SEP Reference Number 88 Assess Root Cause of Poor Operator Training and Establish Means to Monitor Operator Training L Licensed Operator Requalification Training................................ ............................64 i License Candidate Exams............................................................................................ 65 SEP Reference Number 71 Improve Controls over Temporary Modifications -l Temporary Modifications.................................................. .....................~.........58 9 i ) I i l 82 l i
REPORT DISTRIBUTION UST L T. Kusek R.L. Andrews K. L Belek M. P. Lazar B. H. Blorne B. R. LMngston j D. L. Lovett C. E. Boughter J. H. MacKinnon C. J. Brunnert J. W. Marcil G. R. Cavanaugh N. L Marfice J. W. Chase R. D. Martin A. G. Christensen T. J. Mcivor O. J. Clayton K. G. Meistad R. P. Clernens K. A. Miller R. G. Conner P. A. Mruz J. L. Connolley G. M. Cook Nuclear Licensing S. R. Crites & Industry Affairs D. W. Dale J. T. O'Connor D. C. Dietz W. W. Orr _ T. L. Patterson M. L. Ellis R. T. Pearce H. J. Faulhaber M. T. Frans R. L Phelps D. P. Galle W. J. Ponec C. R. Rice S. K. Gambhlr A. W. Richard J. K. Gasper D. G. Ried W. G. Gates S. W. Gebers G. K. Samide M. J. Sandhoefner L. V. Goldberg D. J. Golden F. C. Scofield H. J. Sefick R. H. Guy A. L. Hale J. W. Shannon 1 J. B. Herman C. F. Simmons T. L Herman E. L Skaggs i K. C. Hohhaus J. L. Skiles F. K. Smith L P. Hopkins R. L Sorenson C.K. Huang T. W. Jamieson K. E. Steele R. L Jaworski M. A.Tesar R. A.Johansen J. J. Tesarek J. W. Johnson J. W. Tills 1 R. Jones D. R. Trausch W. C. Jones J. M. Waszak G. R. Williams J. D. Keppler i S. J. Willrett D. D. Kloock 83
FORT CALHOUN STATION OPERATING CYCLES AND REFUELING OUTA*IE DATES l Event Date Ren0e Production (MWH) Cumulative (MWH) Cycle 1 09/26/73 02/01/75 3,299,639 3,299,639 1st Refueling 02/01/75-05/09/75 Cycle 2 05/09/75 -10/01/76 3,853,322 7,152,961 2nd Refueling 10/01/76-12/13/76 Cycle 3 12/13/76 - 9/30/77 2,805,927 9,958,888 3rd Refueling 09/30/77-12/09/77 Cycle 4 12/09/77 10/14/78 3,026,832 12,985,720 4th Refueling 10/14/78-12/24/78 Cycle 5 12/24/78- 01/18/80 3,882,734 16,868,454 l 5th Refueling 01/18/80 - 06/11/80 l Cycle 6 06/11/80 - 09/18/81 3,899,714 20,768,168 6th Refueling 09/18/81 -12/21/81 Cycle 7 12/21/81 -12/06/82 3,561,866 24,330,034 7th Refueling 12/06/82- 04/07/83 Cycle 8 04/07/83- 03/03/84 3,406,371 27,736,405 8th Refueling 03/03/84- 07/12/84 i Cycle 9 07/12/84 - 09/28/85 4,741,488 32,477,893 9th Refueling 09/28/85- 01/16/86 Cycle 10 01/16/86 - 03/07/87 4,356,753 36,834,646 10th Refueling 03/07/87 - 06/08/87 Cycle 11 06/08/87 - 09/27/88 4,936,859 41,771,505 tith Refueling 09/27/88 - 01/31/89 Cycle 12 01/31/89 - 02/17/90 3,817,954 45,589,459 12th Refueling 02/17/90 - 05/29/90 Cycle 13 05/29/90 - 02/01/92 5,451,069 51,040,528 13th Refueling 02/01/92 - 05/03/92 Cycle 14 05/03/92-09/25/93 4,981,485 56,022,013 14th Refueling 09/25/93 -11/26/93 Cycle 15 11/26/93 - 03/11/95 15th Refueling 03/11/95 - 04/29/95 (Planned Dates) ) FORT CALHOUN STATION CURRENT PRODUCTION AND OPERATIONS " RECORDS" First Sustained Reaction August 5,1973 (5:47 p.m.) First Electricity Supplied to the System August 25,1973 Commercial Operation (180,000 KWH) September 26,1973 Achieved Full Power (100%) May 4,1974 Longest Run (477 days) June 8,1987 Sept. 27,1988 i Highest Monthly Not Generation (364,468,800 KWH) October 1987 Most Productive Fuel Cycle (5,451,069 MWH)(Cycle 13) May 29,1990-Feb.1,1992 m -.-}}

ML20079A822

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