Text

FCS Performance Indicators Sept 1994 Rept
	ML20076J723
Person / Time
Site:	Fort Calhoun
Issue date:	09/30/1994
From:	; OMAHA PUBLIC POWER DISTRICT
To:	;
Shared Package
ML20076J722	List: LIC-94-0225, Forwards FCS Performance Indicators Sept 1994 Rept; ML20076J723;
References
	NUDOCS 9410260244
	Download: ML20076J723 (97)
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Omaha PubtK Power Metrut FORT CALHOUN STATION PERFORMANCE INDICATORS

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1 OMAHA PUBLIC POWER DISTRICT FORT CALHOUN STATION PERFORMANCE INDICATORS REPORT Prepared By:

Production Engineering Division System Engineering Test and Performance Group SEPTEMBER 1994

FORT CALHOUN STATION SEPTEMBER 1994 MONTHLY OPERATING REPORT OPERATIONS

SUMMARY

During the month of September, Fort Calhoun Station (FCS) operated at a nominal 100% power level. Normal plant maintenance, surveillance, and equipment rotation activities occurred during the month.

~

Ventilation units VA-86/96 for the Quality Assurance Records Storage room, which had been inoperable since August 29,1994, were declared operable on September 12. These units had a new compressor and new evaporator coils installed.

The "B" channel Reactor Protective System (RPS) Trip Units 1 (High Power Trip),9 (Thermal Margin / Low Pressure Trip), and 12 (Axial Power Distribution Trip) were declared inoperable on September 7 and were bypassed. A 48-hour Limiting Condition for Operation (LCO) was en-tered, I & C repaired a power supply and the trip units were retumed to an operable status on September 7.

The inner Personnel Air Lock (PAL) door equalizing valve was found to be leaking on Septem-ber 8. The inner PAL door was declared inoperable and a 48 hour5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months LCO was entered. The valve was repaired and the inner PAL door was returned to an operable status on September 8.

Control Room restroom exhaust fan damper VA-84A failed to reopen following a surveillance test. Since dampers VA-84A and VA-84B are in series with each other, both have been tagged shut to maintain the Control Room Boundary. Repairs are in progress.

On September 30, an auxiliary steam line in Room 19 was discovered to be leaking and had dripped into the control cabinet for air compressor CA-lC. The moisture caused the CA-lC mo-tor start relay to malfunction. Repairs were in progress at month's end.

The following NRC inspections were completed during this reporting period:

IER No. Descriotion l

94-18 Monthly Resident Inspection j i

94-19 New 10 CFR 20 Implementation There were no Licensee Event Reports submitted during this reporting period.

Source: Nuclear Licensing & Industry Affairs i

E:

Year-To-Data Value r- r - r r-- Performance Cateaories l .

! 3 Performance in Industry l ! Unplanned 1 Thermal 6 Upper 10% and better Unit 90 1hed 1 Automatic .. ; Performance; than 1994 OPPD goal Capability Factor i

Lo%

C pip bl ilIY JScrams/7,0006 l ssFactor_. ( Hours Critical- : ---

Performance Better Than i '

1 ___--___ , = = -

' =- -

1994 OPPD Goal I i I .

i I;-- Ii1 i ii I I l AFW Safetv E jFueli. Performance Not Meeting

! h3'M i Qtf $ysteirli i l lpG Shfety

$ydteh {ReliabilitYi

---]

1994 OPPD Goal Perforrnance i

i Porf6h44dde P4ris46drice lindicatori i __.

! I

_________ _ ;- l l

. =

June July August s

94 94 94 dha'm$st Collective $V510Nutidf( Musbl1

'yff i Radiation LOW-Levels W-Accident; Se em W Exposure Radioactive 3 _

! Rate; gg4

--' kWaste

=- { c__.-.. ._

. Year-To-Date Best Possbie

.y -

Value 1994 Year-End Performance INPO PERFORMANCE INDICATORS (Performance for the months of January through September 1994)

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_- _ ____ _ _ _ _ _ _ _ _ __.__ _-- m - _ __A -. _ -- _ ____ _ _ _ _ _ _ _ _

!AutoH Scrams) ,

' While -

? critical Year-To-Date Value Performance Cateaories

!l';..

E Performance Better Than industry Average Trend

? Safety;- )Significanti System : Events s idctnations~::: Performance Better Than 1994 OPPD Goal ge :-

Performance Not Meeting 1994 OPPD Goal or Industry Average Trend (Sofsty) Forced 4 JSystoni Outage 1Fellures; Rate June July August

( S4 '94 34

_ _.;_ _2 September 1994 ddulphet Year-To-Date jg3j j Collective Value Best Possible odtagede ,000 Radiation Performance 1994 Year-End gjggd .I Exposure Performance E

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 otherindicator values are for the months of January through September 1994.)

4 FORT CALHOUN STATION PERFORMANCE INDICATORS REPORT - ' '

i SEPTEMBER 1994 -

SUMMARY

POSITIVE TREND REPORT 4

A performance indicator with data representing three

consecutiva months of improving performance or three Rati f Preventive to Tota! Maintenance & Preventive i consecutive months of performance that is superior to Maintenance items Overdue i

the stated goalis exhibiting a positive trend per Nuclear (Page 47) t Operations Division Quality Procedure 37 (NOD-OP-37). i 1

Maintenance Overtime The following performance indicators exhibi'ed positive (Page 49) trends for the reporting month:

in-Line Chemistry Instruments Out-of-Service l l (Page 52) l I Diuhlino Iniurv/fliness Frecuency Rate (Lost Time Acci- I dent Rate) Harardous Wasta Produced j (Page 3) (Page 53) 4 Recordable Iniurv/fliness Cases Frecuency Rate Contaminated Radiation Controlled Area j (Page 4) (Page 54)

}

4 Aurisarv Feedwater System Safety System Performance (p,g,g) End of Positive Trend Report.

1 Emeroency AC Power System Safety System Perfor-1 mance 1

(Page 10)

ADVERSE TREND REPORT j Emeroenev Diesef Generator Unit Reliability j (Page 11) A Performance Indicator with data representing 3 con-i secutive months of declining performance; or four or

. Djgel Generator Reliability (25 Demands) more consecutive months of performance that is trending (Page 12) towards declining as determined by the Manager - Sta-

] tion Engineering, constitutes an adverse trend per NOD-

Emeroency Diesel Generator Unreliability OP-37. A supervisor whose performance indicator ex- i (Page 13) hibits an adverse trend by this definition may specify in l written form (to be published in this report) why the trend Number of Missed Surveillance Tests Resultino in Lic- is not adverse.

ensee Event Reoorts (Page 20) The following performance indicator exhibited an ad- l verse trend for the reporting month:

Forced Outaae Rate (Page 23)

Fuel Reliability Indicator Unit Canacity Factor (Page 14)

(Page 24) An adverse trend is indicated based on the FRt value for the reporting month exceeding the 1994 Fort Calhoun Unit Canabilitv Factor monthly goal of less than 5.0 X 10*. and the potential for (Page 26) 1 or 2 defective fuel rods in the core.

Unolanned Canability loss Factor I (Page 27) End of Adverse Trend Report.

Primary System Chemistry Percent of Hours Out of Limit (Page 39)

Secondary System Chemistry (Page 40)

Cents Per Kilowatt Hour (Page 42) iv

FORT CALHOUN STATION PERFORMANCE INDICATORS REPORT l SEPTEMBER 1994 -

SUMMARY

INDICATORS NEEDING INCREASED MANAGEMENT ATTENTION REPORT :

A performance indicator with data for the reporting period Maintenance Workload Backloos i that is inadequate when compared to the OPPD goal is (Page 46) defined as "Needing increased Management Attention

The backlog of non-outage MWOs for cx>rrective mainte-per NOD-OP-37. nance has exceeded the 1994 monthly goal of a maxi-mum of 400 since August 1994.

The following performance indicators are cited as need- ,

ing increased management attention for the reporting Percentaos of Tota! MWOs Comoteted Per Month identi-month; fied As Rework (Page 48)

Industrial Safe +v Accident Rate - INPO The percentage of total MWOs identified as rework (Page 2) (3.16%) for the reporting month exceeds the 1994 The year-to-date value for this indicator has exceeded monthly goal of <3%.

the Fort Calhoun goal of 50.50 since May 1994.

Number of Control Room Eouioment Deficiencies End of Management Attention Report.

(Page 15)

The total number of control room equipment deficiencies at the end of the reporting month (49) exceeds the 1994 '

Fort Calhoun monthly goal of $45. In addition, the num-ber of identified Operator Work Around items for the re-porting rnonth (7) exceeds the monthly goal of 55. PERFORMANCE INDICATOR REPORT IMPROVEMENTS / CHANGES Violations Per 1.000 insoection Hours (Page 18) This section lists significant changes made to the report The number of NRC violations per 1,000 inspection and to specific indicators within the report since the pre-hours has exceeded the Fort Calhoun goal of 51.4 since vious rnonth.

March 1994.

Unolanned Automatic Reactor Scrams Per 7.000 Hours INPO Anoroximate Industry Unoer 10% Values have Critical been added to the appropriate performance indicators (Page 28) based on INPO's Mid-year 1994 report.

The number of unplarined automatic reactor scrams per 7,000 hours0 days 0 hours 0 weeks 0 months critical has exceeded the Fort Calhoun goal Clean Controlled Area Contaminations >1.000 Disinte-of 0 since February 1994. There have been no orationeMinute Per Probe Area unplanned automatic reactor scrams since February (Page 5) 19 % This indicator has been revised to include contamina-tions that were a result of the Spent Fuel Rerack project.

Unolanned Safety System Actuations -(INPO Defini+ ion)

(Page 29) Collective Radiation Exoosure The number of INPO unplanned safety system actua. (Page 16) tions has exceeded the Fort Calhoun goal of 0 since The collective radiation exposure graphs have been re-February 1994. There have been no INPO unplanned vised to reflect quarterly TLD readings. Radiation expo-safety system actuations since February 1994. sure totals for the months of July and August 1994 had been based on ALNOR readings.

Unolanned Safety System Actuations -(NRC Definition)

(Page 30) Temocrary Modifications The number of NRC unplanned safety system actuations (Page 58) has exceeded the Fort Calhoun goal of 0 since February The goals for this indicator have been revised to recog-1994. There have been no NRC unplanned safety sys. nize that management actions on a specific set of 8 tem-tem actuations since February 1994. porary modifications allows these to be installed for dura-tions exceeding their related duration goal.

Thermal Performance (Page 32)

The year-to-date average monthly thermal performance End of Performance Indicator Report improvements /

value has been below the 1994 Fort Calhoun goal of Changes Report 299.5% since January 1994.

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i Table of Contents / Summary GOALS . . . .. X l SAFE OPERATONS EAGE INDUSTRIAL SAFETY ACCIDENT RATE -INPO . .. . .. . 2 DISABLING INJURY /lLLNESS FREQUENCY RATE. 3 RECORDABLE INJURY /lLLNESS CASES FREOUENCY RATE - . - . . . . . . . . .4 :

CLEAN CONTROLLED AREA CONTAMINATONS 21,000 DISINTEGRATIONS / MINUTE PER PROBE AREA. .. .. .5 .

PREVENTABLE / PERSONNEL ERROR LERs . . .6 i SAFETY SYSTEM FAILURES .. .. .... .7 SAFETY SYSTEM PERFORMANCE:

HIGH PRESSURE SAFETY INJECTON 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 '

UNRELIABILITY .. ... . . . . . ... .. .. .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 INSPECTON HOURS . .. .18 SIGNIFICANT EVENTS - . . . . .. ..19 NUMBER OF M!SSED SURVEILLANCE TESTS RESULTING IN LERS .._ .. . . 20 PERFORMANCE E6GE STATON NET GENERATON . . .. . 22 FORCED OUTAGE RATE.... .. . . ... . 23 UNIT CAPACITY FACTOR.. .. . . . . . . 24 vi I

PERFORMANCE (continued) EAGE EOUIVALENT AVAILABILITY FACTOR - .. . .- . . 25 l I

UNIT CAPABillTY FACTOR ..~... . . . 26 UNPLANNED CAPABILITY LOSS FACTOR . .. .. . . . . 27 l

UNPLANNED AUTOMATIC REACTOR SCRAMS PER 7,000 HOURS CRITICAL.- . .. .. . . 28 l l

UNPLANNED SAFETY SYSTEM ACTUATONS - (INPO DEFINITON) .... . . . 29 UNPLANNED SAFETY SYSTEM ACTUATONS -(NRC DEFINITON) = .. . 30 GROSS HEAT RATE.. .. . 31 THERMAL PERFORMANCE... .. . 32 DAILY THERMAL OUTPUT .. = . . . . . 33 EQUIPMENT FORCED OUTAGES PER 1,000 CRITICAL HOURS - . . .... . 34 COMPONENT FAILURE ANALYSIS REPORT (CFAR)

SUMMARY

- . . . .. . 35 ;

REPEAT FAILURES.. . . . 36 ,

CHECK VALVE FAILURE RATE - . .37 l VOLUME OF LOW-LEVEL SOLID RADOACTIVE WASTE 38 PRIMARY SYSTEM CHEMISTRY PERCENT OF HOURS OUT OF LIMIT . . . 39 CHEMISTRY INDEX/ SECONDARY SYSTEM CHEMISTRY.. .. . . . 40 l

COST EAGE i l

l CENTS PER KILOWATT HOUR .. . 42 STAFFING LEVEL .. . . . . . .. ., . 43 SPARE PARTS INVENTORY VALUE.. .. . . 44

)

QB(JSDN AND DEPARTMENT PERFORMANCE INDICATORS EAQE MAINTENANCE WORKLOAD BACKLOGS (CORRECTIVE NONOUTAGE).. . . . . . 46 i

vii i

___ _ __ _ _ _ _ _ _ ____-__._m . . - _ _. _ _ _ . . . _ _ _ _. ._. . . - .__.

DIVISON AND DEPARTMENT PERFORMANCE INDICATORS (continued) PAGE RATO OF PREVENTIVE TO TOTAL MAINTENANCE

& PREVENTIVE MAINTENANCE ITEMS OVERDUE . .- .. . . . 47 PERCENTAGE OF TOTAL MWOs COMPLETED PER MONTH IDENTIFIED AS REWORK.... . . . . 48 MAINTENANCE OVERTIME ............ _ . . . . . . . . 49 PROCEDURAL NONCOMPLIANCE INCIDENTS (MAINTENANCE).. .. . .. . .. . . . .. . . .. . . . 50 PERCENT OF COMPLETED SCHEDULED MAINTENANCE ACTIVITIES (ALL MAINTENANCE CRAFTS) .. .. ... . . . . . .. . 51 IN-LINE CHEMISTRY INSTRUMENTS OUT-OF-SERVICE . .. .. 52 l i

HAZARDOUS WASTE PRODUCED ... . ., . . . . . .. . 53 CONTAMINATED RADIATON CONTROLLED AREA . . 54 RADOLOGICAL WORK PRACTICES PROGRAM -- .. .. . . .. .. . 55 DOCUMENT REVIEW. .. . . . ... . . 56

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LOGGABLE/ REPORTABLE INClDENTS (SECURITY) . . .. .. . . . 57 TEMPORARY MODIFICATIONS -- . . .. . 58 OUTSTANDING MODIFICATONS . .. . . 59 ENGINEERING ASSISTANCE REQUEST (EAR) BREAKDOWN = . .. .. . . . . . . 60 l

ENGINEERING CHANGE NOTICE STATUS .. .. .. . .. . 61 ENGINEERING CHANGE NOTICES OPEN . .. . . 62 l

LER ROOT CAUSE BREAKDOWN.. . .. .. . .. ......63 LICENSED OPERATOR REQUAllFICATON TRAINING . ..,. .. .. . . . . 64 LICENSE CANDIDATE EXAMS . ... . . . . ., .. . 65 ,

OPEN CORRECTIVE ACTON REPORTS AND INCIDENT REPORTS . . .. .. . 66 i

MWO PLANNING STATUS (CYCLE 16 REFUELING OUTAGE) . . . 67 OVERALL PROJECT STATUS (CYCLE 16 REFUELING OUTAGE) . . . . .. -. 68 PROGRESS OF CYCLE 16 OUTAGE MODIFICATON PLANNING.. . . . . 69 PROGRESS OF 1994 ON.LINE MODIFICATON PLANNING ..._ ... . .. .. 70 I

i l

viii i

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ACTON PLANS DEFINITONS. SEP INDEX & DISTRIBUTION LIST M ACTON PLANS.. . . 71 PERFORMANCE INDICATOR DEFINITONS . .. . . . . 74 SAFETY ENHANCEMENT PROGRAM INDEX.. . . 81 REPORT DISTRIBUTON LIST. . . 83 ix

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

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OPPD NUCLEAR ORGANIZATION GOALS i Vice President - 1994 Priorities 1

i MISSION s 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.

GOAIS Goal 1: SAFE OPERATIONS To ensure the continuation of a " safety culture" in the OPPD Nuclear Program and to provide a professional working environment, in the control room and throughout the OPPD nuclear organi-zation, that assures safe operation so that Fort Calhoun Station is recognized as a nuclear indus-try leader.

1994 Priorities:

Improve SALP ratings.

Impmve INPO rating.

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

No unplanned automatic reactor scrams or safety system actuations.

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

1994 Priorities:

Improve Quality, Pmfessionalism, and Teamwork.

Improve Plant Reliability.

Meet or exceed INPO key parameters and outage performance goals.

Reduce the number of human performance errors.

Identify programmatic perfonnance problems through effective self assessment.

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

l 1994 Priorities:

Maintain total O & M and Capital expenditures within budget. l Streamline work processes to improve cost effectiveness.

l Goals Source: Scofield (Manager) x i

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

e 1

I

- e-- Year to-Date INPO Industrial Safety Accident Rate O Fort Calhoun Year-End Goal ( 0.50) 1.8 - -O- Industry Upper 10%

V 1.6 - --b- 1995 INPO Industry Goal ( 0.50) 1.4 -

1.2 -

1-0.8 -

1 0.6 - l

3-----O O O ,

j 0.4 - l i !

O O O O O O O O O O O O , . , , , , , , , , i i i Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 151DUSTRIAL SAFETY ACCIDENT RATE-INPO As stated in INPO's December 1993 publication ' Detailed Descriptions of World Asso- l l ciation of Nuclear Operators (WANO) Performance Indicators and Other Indicators for j 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 0.55 at the end of September 1994. The value for the 12 months from October 1,1993 through Septem-ber 30,1994 was 0.52. I 1

] There were no restricted-time and no lost-time accidents in September. There has

, been 1 restricted-time accident and 2 lost-time accidents in 1994.

q The values for this indicator are determined as follows:

I

\

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

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The 1994 Fort Calhoun year-end goalis s0.50. The 1995 INPO industry goalis 50.50.

. The approximate industry upper ten percentile value (for the period from 7/93 through 6/

94) is 0.12.

Data Source: Sorensen/Skaggs (Manager / Source)

Chase / Booth (Manager / Source)

Accountability: Chase / Conner Adverse Trend: None 2

1

i l

! - @ -- 1994 Disabling injury / Illness Frequency Rate

-M- 1993 Disabling injury / Illness Frequency Rate l GOOD l

! O Fort Calhoun Year-End Goal ( 0.5)

Y 1.2 - l i 1-i

0.8 -

i C ^ ^ ^ ^ ^

b 0.4 -

l 0.2 -

O - , - . . . , , , , . . , ,

Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 j l

DISABLING INJURY /lLLNESS FREQUENCY RATE (LOST TIME ACCIDENT RATE) l 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 0.37 at the end of Septem-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 October 1,1993 through September 30,1994 was 0.39. l The 1994 Fort Calhoun year-end goal for this indicator is a maximum value of 0.5.

Data Source: Sorenson/Skaggs (Manager / Source) !

Accountability: Chase / Conner Positive Trend SEP 25, 26 & 27 3

--G-- 1994 Recordable injury / Illness Frequency Rate

-X- 1993 Recordable injury / Illness Frequency Rate IGOODl 2.5 - V

--G-- 1994 Fort Calhoun Year-End Goal ( t.5) 2.25 - !

I 2-l 1.75 -

^ ^ ^ ^ ^ ^ ^

1.5 - C v v v v v v v v O 1.25-1- ^

0.75 -

0.5 -

0.25 -

0 . , . , , , , , , , , , , ,

Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 RECORDABLE INJURY /lLLNESS CASES FREQUENCY RATE This indicator shows the 1994 recordable injury / illness cases frequency rate. The 1993 recordable injury / illness cases frequency rate is also shown.

A recordable injury / illness case is reponed if personnel from any of the Nuclear Divi-sions are injured on the job and require corrective medical treatment beyond first aid.

The recordable injury / illness cases frequency rate is computed on a year-to-date basis.

The recordable injury / illness cases frequency rate year-to-date was 0.93 at the end of September 1994. There were no recordable injury / illness cases reported for the month of September. There have been 5 recordable injury / illness cases in 1994.

The recordable injury / illness cases frequency rate for the 12 months from October 1, 1993 through September 30,1994 was 1.05. ,,

The 1994 Fod Calhoun year-end goal for this indicator is a maximum value of 1.5.

Data Source: Sorenson/Ska jgs (Manager / Source)

Accountability: Conner Positive Trend SEP 15,25,26 & 27 4

l

- Contamination Events

-O- Fort Calhoun Year-End Goal ( 54)

V l

60 - i 55- C C C C C C C C C C C C l 50 -

y, 45- !

40- _ 0 !

c 35-

$30-f25- ~

$ 20-15-10-5-

0 , , , , , , , , , , , 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. i This includes the contamination events associated with the spent fuel rerack project. !

There was 1 contamination event in September 1994. There has been a total of 40 l contamination events in 1994. ;

1 The 1994 year-end goal for this indicator is a maximum of 54 contamination events.

Data Source: Chase /Little (Manager / Source)

Accountability: Chase /Lovett Adverse Trend: Only 1 additional contamination per month has occurred during each !

of the last 2 months. To exceed the year-end goal of a maximum of 54 contamination events,15 additional contamination events would have to occur in the three remaining months of 1994. Based on a projected rate of approximately 4 events per month, the Station total will be 52 contamination events at the end of the year and the goal will be met.

SEP 15 & 54 5

e 0 Preventable (18 Month Totals)

-D- Personnel Error (18 Month Totals)

O Personnel Errors (Each Month) 40-35-30-25 -

20-15- _

10-5 --

o ,

U , , A, , , , ,

i g 9 a a #

2 s# ,8 4 E m 8z8 o g

E g

S a s < s ,8 4 E g

PREVENTABLEPERSONNEL 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 atals for each month. The LERs are trended based on the LER event date as oppowJ to the LER report date.

In August 1994, there were no events that were subsequently reported as an LER. No LERs were categorized as Preventable or a Personnel Error.

The total LERs for the year 1994 (through August 31,1994) is 6. 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 willinclude 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

l

O startup G Shutdown IGOODI

,4- @ Operation y 2

g 3- 7

- Industry Average Trend h ( $

f 1- $ - h \ -

p 7 -Q g 3 0

$ d N '

2 & w $

i i i i i i i i i i i i 91-2 91-3 91-4 92-1 92-2 92-3 92-4 93-1 93-2 93-3 93-4 94-1 Year-Ouarter SAFETY SYSTEM FAILURES This indicatorillustrates the number of NRC Safety System Failures as reported by the Nuclear Regulatory Commission's Office for Analysis and Evaluation of Operational Data in the biannual " Performance Indicators for Operating Commercial Nuclear Power Reactors" report.

The following NRC safety system failures occurred between the first quarter of 1993 and the first quarter of 1994:

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

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

l l

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

First Quarter 1994: A single failure of an ESF relay could result in a loss of safety injection, due to premature actuation of recirculation flow, and a loss of containment spray flow.

Data Source: Nuclear Regulatory Commission Accountability: Chase Adverse Trend: None 7

1994 Monthly High Pressure Safety injection System ;

g Unavailability Value i 1994 Year to-Date High Pressure Safety injection d'~

System Unavailability Value l GOOD l O 1994 Fort Calhoun Goal ( 0.004) y j

- 1995 INPO Industry Goal (0.02) j

-O- Industry Upper 10% (0.0011) !

0.03 -

O.025 -

0.02 - A A A A A A A A A O.01 5 -

1 0.01 -

' O.005 -

~

0.00036 g g n g _g g g i ,0 -i-, i , , , ,

,$,g , , i 1 1993 Unavailability Value Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 1

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.

T The High Pressure Safety injection System unavailability value for the month of Sep-tember 1994 was 0.0. There were no hours of planned or unplanned unavailability during the month. The 1994 year-to-date HPSI unavailability value was 0.0029 at the end of the month. The unavailability value for the last 12 months was 0.0026.

There have been 57.48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months 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 Adverse Trend: None 6

J

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

+ UnavailabilityValue

-O-- lGOODI 1994 Fort Calhoun Goal ( 0.01)

-A- 1995 INPO Industry Goal ( 0.025)

~

C Industry Upper 10% (0.0021) 0.025 - A A A 4 4 A A A A A --- 4 A 0.02 -

0.01 5 -

0.01 - C C C C C C C C C C C C a C 2 D F ,0 ; ; i i ; ; ; i , i ; ;

1993 Unavailability Value Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 AUXILIARY FEEDWATER SYSTEM SAFETY SYSTEM PERFORMANCE This indicator shows the Auxiliary Feedwater System Unavailability value, as defined by INPO in the Safety System Performance Indicator Definitions, for the reporting month.

The Auxiliary Feedwater System Unavailability Value for September 1994 was 0.0.

During the month, there were no hours of planned or unplanned unavailability during the month. The year-to-date unavailability value was 0.003, and the value for the last 12 months was 0.0028 at the end of the month.

There has been a total of 21.7 hours8.101852e-5 days 0.00194 hours 1.157407e-5 weeks 2.6635e-6 months of planned unavailability and 17.26 hours3.009259e-4 days 0.00722 hours 4.298942e-5 weeks 9.893e-6 months of unplanned unavailability for the auxiliary feedwater system in 1994.

The 1994 Fort Calhoun year-end goal for this indicator is a maximum value of 0.01.

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

s E Monthly Emergency AC Power Unavailability Value 2 Year-to-Date Emergency AC Power Unavailability Value O Fort Calhoun Goal lGOOW t

0.07- sty &al(0.025) 0.06-sty Upper 10Y. (0.0030 0.05-0.04 -

0.03 -

4 O O O 3 0.02- - -

0.01 -

r 0 FE-5B-

- m -FB-E"E E-O i i O

i O

i Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 EMERGENCY AC POWER SYSTEM SAFETY SYSTEM PERFORMANCE e

This indicator shows the Emergency AC Power System unavailability value, as defined l by INPO in the Safety System Performance Indicator Definitions, for the reporting month.

The Emergency AC Power System unavailability value for September 1994 was 0.0074.

During the month, there were 10.65 hours7.523148e-4 days 0.0181 hours 1.074735e-4 weeks 2.47325e-5 months of planned unavailability for testing, and no hours of unplanned unavailability. The Emergency AC Power System unavailability value year to-date was 0.016 and the value for the last 12 months was 0.012 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 196.74 hours8.564815e-4 days 0.0206 hours 1.223545e-4 weeks 2.8157e-5 months of planned unavailability and 11.25 hours2.893519e-4 days 0.00694 hours 4.133598e-5 weeks 9.5125e-6 months 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 app oximately 0.0035.

Data Source: Jaworski/Ronning Accountability: Jaworski/Ronning Positive Trend 10

.~

E Number of Failures /20 Demands - Trigger Values for 20 Demands ;

I O Number of Failures /50 Demands -Y- Trigger Values for 50 Demands E Number of Failures /100 Demands -- Trigger Values for 100 Demands j j

8-l GOOD l I

. +

6-4 Y Y Y Y Y Y Y Y Y V- V V j

4-l 2-1 1 1 1 1 1 1 1 1 1 1 1 3

00-I 00f 00; 00d 00 I I I I 00L 00[ 00f 00[ 00 I I I I I 00 I

00 I

Oct93 Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep94 EMERGENCY DIESEL GENERATOR UNIT RELIABILITY This bar graph shows three monthly indicators pertaining to the number of failures that were reported during the last 20,50, and 100 emergency diesel generator demands at the Fort Calhoun Station. Also shown are trigger values which correspond to a high level of confidence that a unit's diesel generators have obtained a reliability of greater than or equal to 95% when the failure values are below the corresponding trigger val-ues. % f ort Calhoun 1994 goalis to have fewer failures than these trigger values.

The demands counted for this indicatorinclude the respective number of starts and the respective number of load-runs for both Diesel Generators combined. The number of start demands includes all valid and inadvertent starts, including all start-only demands and all start demands that are followed by load-run demands, whether by automatic or manualinitiation. Load-run demands must follow successful starts and meet at least !

I one of the following criteria: a load-run that is a result of a real load signal, a load-run test expected to carry the plant's load and duration as stated in the test specifications, and a special test in which a diesel generator was expected to be operated for a mini-mum of one hour and to be loaded with at least 50% of design load (see exceptions and other demand criteria in the Definition Section of this report).

Data Source: Jaworski/Ronning (Manager / Source)

Accountability: Jaworski/Ronning Positive Trend 11

i O DG-1 Failures /25 Demands lGOODI E DG-2 Failures /25 Demands 5- 0 Failure Trigger Value for 25 Demands / Fort Calhoun Goal

~

4- C O O O O O O O O O O O 3-2-

l 1- j 1

00 00 00 00 00 00 00 00 00 00 00 00 l

0 . , i . , , , , . , , , ,

! Oct93 Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep94 DIESEL GENERATOR RELIABILITY (25 DEMANDS) l l This indicator shows the number of failures experienced by each emergency diesel l 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.

! 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 l Definitions Section of this report. A System Engineering instruction has been approved for the Fort Calhoun Station to institutionalize and formally approve / adopt the required NUMARC actions.

Diesel Generator DG-1 has not experienced any failures during the last 25 demands on the unit.

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

Data Source: Jaworski/Ronning (Manager / Source)

Accountability: Jaworski/Ronning Positive Trend 12

O DG-1 Unreliability Value

@ DG-2 Unreliability Value l GOOD l

-+- Station Unreliability Value 0.003-Industry Upper 10% (0.002 for 4

0.0025- a Three Year Average) l 1

0.002 - O O O O O O O O O O O O !

0.0015 -

1 0.001 - ,

I O.0005-0.0 0,0 0,0 0,0 0,0 0,0 0,0 0,0 0,0 00 0,0 0,0

' ' ' T T '

' l '

l ' l '

i ' l ' I l I I l l I !

Oct93 Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep94 l EMERGENCY DIESEL GENERATOR UNRELIABILITY The purpose of this indicator is to monitor the likelihood that emergency AC power l 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 September 1994 was 0.0.

The 1994 goal for this indicator is a maximum value of 0.0.

For DG-1: There was 1 start demand for the reporting month without a failure.

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

For DG-2: There were 2 start demands for the reporting month with no failures, in addition, there was 1 load-run demand without a failure.

Emergency diesel generator unreliability is calculated as follows:

value per DG = SU + LU - (SU x LU) where SU = Start Unreliability = number of unsuccessful starts number of valid start demands LU = Load-run Unreliability = Dumher 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

l

.L E

0 Fud Reliability indicator i I

l $ o 1995 INPO Industry Fuel Defect Reference (5 X 10-4 Microcuries/ Gram) lGOODI i b

^

y '

1994 & 1993 Fort Calhoun Goals g0 i j _ ; ; i j j i i i i i Oct93 Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep94 FUEL RELIABILITY INDICATOR The Fuel Reliability Indicator (FRI) value for September 1994 was 10.06 X 10-4 microcu-ries / gram. The purpose of the FRIis to monitorindustry progress in achieving and

, maintaining a high level of fuelintegrity. The September FRI value, which is greater 4 than the zero defect threshold value, discussed below, indicates a potential fuel defect in the core. The plant operated at full power during the entire month. The September FRI was calculated based on the average fission product activities present in the reactor

coolant during the steady state full power operation days, September 1 through 30.

The September FRI value of 10.06 X 10-* microcuries/ gram indicated a small decrease i from the August value of 10.38 X 104 microcuries/ gram. The 10.06 X 104 microcuries/

gram FRI value exceeds the 1994 operational goal. The value will not decrease until l l the leaking pin or pins are removed from the core but may show small monthly changes

due to chemistry variability.

i

! Fission product activity data from September full power operation showed a Xenon-133 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. A more definitive disposition will -

be possible when a significant power change is made and specific chemistry data (i.e.

Cesium, lodine and Xenon) can be collected. The presence or lack of Xenon and lodine spikes during the power change would confirm or disprove the fuel failure as-

sumption. The last detected fuel failure was during Cycle 13.

i The INPO September 1992 Report " Performance Indicators for U.S. Nuclear Utility Industry" (INPO No.92-011) states that "...the 1995 industry goal fer fuel reliability is 4

that units should strive to operate with zero fuel defects. A value larger than 5.0 X 10-d 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" number or a "Zero Leaker Threshold". Each utility l will calculate whether the core is defect free or not. The 1994 Fort Calhoun Station FRI performance indicator goalis to maintain a monthly FRI below 5.0 X 10-4 microcuries/

gram.

~

Data Source: Holthaus/ Weber i

Accountability: Chase /Spilker Adverse Trend: An Adverse Trend is indicated based on not meeting the 1994 goal.

14 1

\

O Control Room Equipment Deficiencies Repairable On-Line lGOODI O Total Number of Control Room Equipment Deficiencies V

80- -O- Fort Calhoun Goal For Total Equipment Deficiencies 70- ,

60- 5 - -

~

4 ,

30- ? < j $ , s

- / , ?

20- ; .; y y < ,'

10- ?, ',

. /

7 J

i'

?

/

i,

, , ?,

I l j i i i l i I I I I Oct93 Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep94 8 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- _

~

C O O O O O O O O O O C 4-r a Oct93 i

Nov i

Dec i

Jan i

a Feb i

a Mar i

Apr i

n May i

n Jun i

n Jul i

n i Aug Sep94 5 i NUMBER OF CONTROL ROOM EQUIPMENT DEFICIENCIES This indicator shows the number of control room equipment deficiencies that are repair-able during plant operations (on-line), the number of outstanding control room equip-ment deficiencies, the number of Operator Work Around (OWA) Items repairable on-line, the number of outstanding OWAs and the Fort Calhoun goals.

There was a total of 49 control room equipment deficiencies at the end of September 1994.16 of these deficiencies are repairable on-line and 33 require a plant outage to repair. There were 24 deficiencies added and 22 deficiencies closed during the month.

There were 7 identified Operator Work Around items at the end of the month. The OWAs were on equipment tags: YCV-871 B C/R Panel Al-308, CH-208 C/R Panel CB-1/

2/3, RC-3C C/R Panel CB-1/2/3, RC-3D C/R Panel CB-1/2/3, Fl-1392/94 C/R Panel CB-10/11, FP-368 C/R Panel CB-10/11, and MOV-D1 C/R Panel CB-10/11. 4 OWAs re- i quire an outage to repair.

The 1994 Fort Calhoun monthly goal for this indicator is a maximum of 45 deficiencies and 5 OWAs.

Data Source: Chase / Tills (Manager / Source)

Accountability: Chase /Faulhaber Adverse Trend: None 15

I 4

Q Monthly Personnel Radiation Exposure (Non-Spent Fuel Rerack)

l GOOD l

-@-- Personnel Cumulative Radiation Exposure (Non-Spent Fuel Rerack) 4 --O- Fort Calhoun Annual Goal ( 44 Person-Rem) h40- C O O O O O O O O O O O G" 30-

, g20- ,

g 10- , , . -

y0 -

, , i i , i i i , , i i 1

Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 4

@ Monthly Personnel Radiation Exposure for Spent Fuel Rerack 4

l GOOD l

- Personnel Cumulative Radiation Exposure for Spent Fuel Rerack V

--O.- Fort Calhoun Annual Goal ( 23 Person-Rem)

C O O O O O O O O O O O t

' $l:

gi: ~

e r 2 * *

$ : i : i : , i

i i , i i i i ,

Q- Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 3

. COLLECTIVE RADIATION EXPOSURE

. The 1994 Fort Calhoun goal for collective radiation exposure, excluding the spent fuel rerack, is less than 44 person-Rem.

The exposure for September 1994 was 2.336 person-Rem.

The year-to-date exposure was 13.298 person-Rem.

The Fort Calhoun goal for collective radiation exposure to complete the Spent Fuel Rerack is less than 23 person-Rem.

The Spent Fuel Rerack exposure for September was 0.071 person-Rem.

The year-to-date Spent Fuel Rerack exposure was 4.693 person-Rem.

The collective radiation exposure at the end of September (i.e., the sum of non-spent fuel rerack exposure and spent fuel rerack exposure) was 17.991 person-Rem. The collective radiation exposure for the last 12 months was 153.922 person-Rem at the end l of the month.

The 1995 INPO industry goal for collective radiation exposure is 185 person-rem per year. The industry upper ten percentile value (for the three year period from 7/91 through 6/94)is approximately 106 person-rem per year. The yearly average for Fort Calhoun Station for the three years from 10/91 through 9/94 was 147 person-rem per year.

Data Source: Chase /Little (Manager / Source)

Accountability: Chase /Lovett Adverse Trend: None SEP 54 16 l

_______-____-_A

O Highest Exposure for the Month (mrem)

C Highest Exposure for the Year (mrem) l 5000 -

OPPD 4500 mrem /yr. Limit l l

4000 -

)

i 3000 _

b

[

E 2000 -

Fort Calhoun 1,000 mrem /yr. Goal 1000 -

670 264 f I

0 i September 1994 MAXIMUM INDIVIDUAL RADIATION EXPOSURE During September 1994, an individual accumulated 264 mrem, which was the highest individual exposure for the month.

The maximum individual exposure for the year was 670 mrem at the end of Septem-ber.

The OPPD limit for the maximum yearly individual radiation exposure is 4,500 mrem / l year. The 1994 Fort Calhoun year end goalis a maximum of 1,000 mrem.

I Date Source: Chase /Little (Manager / Source)

Accountability: Chase /Lovett 1

Adverse Trend: None l

17

4- Violations per 1,000 inspection Hours l GOOD l

--O- Fort Calhoun Goal k 3.03 2 p3-

.6 ,

82-c.

1.< 8. c = - --

s w w

w w

w O I

S2 4

Ij S3 1

1-0 ,

Sep93 Oct Nov Dec Jan Feb- Mar Apr May Jun Jul- Aug94 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 1.54 for the twelve months from September 1,1993 through August 31,1994.

The following inspections ended during this reporting period:

lER No. Title No. of Hours 94-18 Resident Monthly inspection 464 To date, OPPD has received 9 violations for inspections conducted in 1994:

Level 111 Violations (1)

Level IV Violations (6)

Level V Violations (0)

Non-Cited Violations (NCV) (2)

The 1994 Fort Calhoun goal for this indicator is a maximum of 1.4 violations per 1,000 inspec-tion hours.

Data Source: Trausch/Cavanaugh (Manager / Source)

Accountability: Trausch Adverse Trend: None 18

1 Q NRC Significant Events

- Industry Average Trend y 1 1 1- ,

0.5 -

[f]

O , , , , , i i i i i i i !

91-2 91-3 91-4 92-1 92-2 92-3 92-4 93-1 93-2 93-3 93-4 94-1 )

Year - Quarter

@ INPO Significant Events (SERs) IGOODI V

2 2-

'~

3 g 3 3 3 0 , , , ,

WA,VA, , ,

WA, ,

WA , i 91-2 91-3 91-4 92-1 92-2 92-3 92-4 93-1 93 2 93-3 93-4 94-1 Year - Quarter SIGNIFICANT EVENTS This indicator illustrates the number of NRC and INPO Significant Events for Fort Calhoun Station as reported by the Nuclear Regulatory Commission's Office for Analysis and Evaluation of Operational Data in the biannual " Performance Indicators for Operating Commercial Nuclear Power Reactors" report and INPO's Nuclear Network.

The following NBQ significant events occurred between the second quarter of 1991 and the First quarter of 1994:

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

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

The following INPO significant events, as reported in Significant Event Reports (SERs), oc-curred between the fourth quarter of 1991 and the first quarter of 1994: l Second Quarter 1992: Intake of Transuranics during Letdown Filter Change-out.

Third Quarter 1992: 1) RC-142 LOCA; and 2) Premature Lift of RC-142.

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

Second Quarter 1993: SBFU Breaker Relay (Switchyard) Plant Trip Fourth Quarter 1993: Unexpected CEA Withdrawal.

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

I l

3-

@ Number of Missed STs Resulting in LERs i

2-1 i

l 1-l J

l l

0 0 0 0 0 0 0 0 0 0 0 0 0

, i i i i i i i i i i i i i e i 92 '93 Oct93 Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep94 NUMBER OF MISSED SURVEILLANCE TESTS l 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 September 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 20

i l

l l

!4 PERFORMANCE i

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

l 1

I 1

i s

}

3 i

4 21 1

}

l

E Net Generation (10,000 Mw hours) i 40-35.66 34.6 34.9 4* -

33.91 34.14

)

~

Cycle 15 27.8 j g Refueling j 2 Outage b

g 20-I i

10-1 1.54 0 i ; i i i i i i ; i i i i Oct93 Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep94 l STATION NET GENERATION l

! During the month of September 1994 a net total of 341,403 MWH was generated by the i Fort Calhoun Station. The slight reduction compared to August reflects 1 day less of j generation. Cumulative net generation for Cycle 15 was 3,420,816 MWH at the end of l the month. j Energy losses for the month of February 1994 were attributable to a generator and l reactor trip that occurred following the failure of the relay for the Containment High j Pressure Signal Supervisory Circuit. Energy losses for the month of January 1994 were j attributable to derates to repair condenser tubes and a failed level control valve on a j heater drain tank.

i

! Energy losses for the month of December 1993 were a result of a forced outage that l began on December 6 and ended on December 7. The outage was caused by an EHC

! test failure. Energy losses for September, October and November 1993 were attribut-j able to the shutdown for the Cycle 15 refueling outage, which began on September 25 and ended on November 26.

Data Source: Station Generation Report

< Accountability: Chase

! Adverse Trend: None j 22 i l

- Forced Outage Rate l GOOD l 12%- -O- Fort Calhoun Goal ( 2.4%) y 1

10.1 9.3 l l

8%-

t 6%- Cycle 15 Refueling l

Outage 4%-

! O C C C C C C C C C C O U*~

1.38 f

/ -

l . /

f I i i 'l W' i i i i i i i i i i

'91 '92 '93 Oct93 Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep94

FORCED OUTAGE RATE l

l The forced outage rate (FOR) was reported as 1.03% for the twelve months from Octo-ber 1,1993 thru September 30,1994. The 1994 year-to-date FOR was 0.75% at the end of the month.

A forced outage occurred on February 11,1994 due to a generator and reactor trip that i occurred following the failure of the relay for the Containment High Pressure Signal !

Supervisory Circuit. The generator was off-line for 48.9 hours1.041667e-4 days 0.0025 hours 1.488095e-5 weeks 3.4245e-6 months .

A forced outage occurred on December 6,1993 when the plant tripped during weekly testing of the turbine EHC system. The generator was off-line for 27.1 hours1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

The 1994 Fort Calhoun year-end goal for this indicator is a maximum value of 2.4%.

The 1993 Fort Calhoun year-end goal was a maximum value of 2.4%.

t Data Source: Monthly Operations Report Accountability: Chase ;

t Positive Trend 3 i

1

^

4

O Monthly Unit Capacity Factor 1

--St- Cycle 15 Unit Capacity Factor 4

-+- 36 Month Average Unit Capacity Factor 110 % -

i 100% - _

l _

l 90%- m E

g - + - -

80%- / #

/ -

c C V 70%- - ; O p N "

7 Cycle 15 50%- Refueling Outage 40%-

~

30%-

20%-

10%-

0% i i i i i , , i i i i i Oct93 Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep94 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 September 1994 was reported as 99.2%. At the end of the month the Cycle 15 Unit Capacity Factor was 89.3%, and the Unit Capacity Factor for the last 36 months was 76.8%.

The Unit Capacity Factor is computed as follows:

Net Electrical Enerov Generated (MWH) l Maximum Dependable Capacity (MWe) X Gross Hours in the Reporting Period Data Source: Monthly Operating Report Accountability: Chase Positive Trend 24

Monthly EAF Year-to-Date Average Monthly EAF 4 lGOODI Industry Median Value (76.7% for a

-B Three Year Average) 100 % - y 7 _ _ ,

nr.4 1 ..... .y

[h '

', 'r <

85.6 E : T '

s, C " h 4 #

- E ;

4' l", k 5: b $g:

! G bk 76.2 80%- A, h h 52 E I N I b-gh.f - - - - - _ - - - - - -

W RR '

$ C T (: V IR fk $ d

?

% QV u:s W ,,- 'n, -

h F M

@ 60.8 it si M g

d R E {' < M!

y$

$ h y

- $# 60%- Cycle 15 +

r n w[RF c ;f ifgg WU shp 1 EEE Refueling *6 w-W g f :l 2 "J r

ff a M y

M; w 5'p i il jg h45 Outage k lis; j, ; ; '

g g M

%p ! r W ~

$ i, u

l[;" %

$ey sk '.

~

sat .

$gf.i .

40% ~ s C '

, : 3 $;

e.t 2

$ $n?!?

s,j. fi gt '.~ ;g v,

v

^

g y d , '

g iW

,,h kbf h$ "

k' N

.

E
$$$ RE M R $ r 65 y - -
Qi ' %
&p W
~,.
p g n $ ~
V ,:
L y y
n m
y i i , ,0% , , , , , , , , , , , ,
'91 '92 '93 Oct93 Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep94 )
I EQUIVALENT AVAILABILITY FACTOR i l
This indicator shows the plant monthly Equivalent Availability Factor (EAF), the year-to- !
date average monthly EAF, and the year-end average monthly EAF for the previous 3 1 years.
The EAF for September 1994 was reported as 98.17%. The year-to-date monthly average EAF was 96.6% at the end of the month.
Energy losses for the month of February were due to a generator and reactor trip that occurred following the failure of the relay for the Containment High Pressure Signal Supervisory Circuit. Energy losses for the month of January were due to derates for condenser tube repair and a failed level control valve on a heater drain tank.
The Fort Calhoun average monthly EAF for the three years prior to this report was 77.3%. 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 25
O Month:y Unit Capability Factor
--et-- Year-to-Date Unit Capability Factor
--+- 36 Month Average Unit Capability Factor 4
O Fort Calhoun Goal l GOOD l 1995 INPO Industry Goal ( 80%)
Industry Upper 10% (89.9% for a Three Year Average) 100% -
_ y __
r 7@ 7 ,. , ., , ,
80%- K- E # '
M M & M #f U --(
60%- M N M hj k k k Nk N
$d b
E Y
h Y
40%- Refueling i g M E i8 @ # A L '
20%- Outage %. C d [$% '
$, *['
~
4 .h .
0% , , , , , , , , , , , i Oct93 Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep94 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 i
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 peliod, expressed as a percentage.
The UCF for September 1994 was reported as 100%. The year-to-date UCF was 97.8%, the UCF for the last 12 months was 81.4%, and the 36 month average UCF was reported as 78.0% at the end of the month.
Energy losses for the month of February ",994 were due to a generator and reactor trip that occurred following the failure of the relay for the Containment High Pressure Signal Supervisory Circuit. Energy losses for the month of January were due to derates to repair condenser tubes and a failed level control valve on a heater drain tank.
Energy losses for the month December 1993 were due to rampup from the Cycle 15 Refueling Outage and a plant trip that occurred on December 6 during testing of the EHC system.
The 1995 INPO 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 l Calhoun year-end goal for this indicator is a minimum of 96.03%.
i Data Source: Generation Totals Report & Monthly Operating Report i Accountability: Chase l
Positive Trend 26 I.
l O Monthly Unplanned Capability Loss Factor '
50%- - Year-to-Date Unplanned Capability Loss Factor O Fort Calhoun Goal lGOODI 40%- 1995 INPO Industry Goal ( 4.5%) t Industry Upper 10% (1.36% for a Three Year Average) 30%-
Cycle 15 Refueling 20%- Outage 8
10%- 3 $
^ ^ ^ ^
C 0%
e i
n i i
w a , i i
i i
i i
=
i Q
i Oct93 Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep94 l 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 September 1994 was reported as 0%. The year-to-date UCLF was 2.1%, the UCLF for the last 12 months was 3.6%, and the 36 month average UCLF was reported as 6.4% at the end of the month.
Unplanned energy losses for the month of February 1994 were due to a generator and reactor trip that occurred following the failure of the relay for the Containment High Pressure Signal Supervisory Circuit. Unplanned energy losses for the month of January were due to derates to repair condenser tubes and a failed level control valve on a heater drain tank.
Unplanned energy losses for the month of December 1993 were the result of a plant trip that occurred during EHC testing.
The 1995 INPO industry goal is 4.5% and the industry upper ten percentile value (for the three year period from 7/91 through 6/94) is approximately 1.36%. The 1994 Fort Calhoun year-end goal for this indicator is a maximum value of 3.97%.
Data Source: Generation Totals Report & Monthly Operating Report Accountability: Chase Positive Trend 27
- FCS Reactor Scrams Per 7,000 Hours Critical Year-to-date
-+- FCS Reactor Scrams Per 7,000 Hours Critical for the last 36 months
--O- 1994 & 1993 Fort Calhoun Goals
- 1995 INPO Industry Goal d
6- -O- Industry Upper 10% (0.48 per 7,000 hours0 days 0 hours 0 weeks 0 months critical over a 36 month time period) 5- l 4-3-
^
2- a .
^
0 0 0 ? ? ?
~
I 0- . , . , . r ~r r-~ ~r - i - i - i - i -
[ i d
~l Oct93 Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep94 Cycle 15 E Number of FCS Reactor Scrams 3 4- Refueling Q2 Outage 0 0 f,01- 0 0
0 0
0 0
0 0
0 0
90 91 92 93 Oct93 Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep94 4
UNPLANNED AUTOMATIC REACTOR SCRAMS PER 7,000 HOURS CRITICAL The upper graph shows the number of unplanned automatic reactor sc'ams per 7,000 hours0 days 0 hours 0 weeks 0 months critical (as defined in INPO's 12/93 publication " Detailed Descriptic,ns 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 1.07 at the end of September 1994. The value for
, the 12 months from October 1,1993 through September 30,1994 was 1.89. The value i for the last 36 months was 1.95.
i 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 hours0 days 0 hours 0 weeks 0 months critical. The industry upper ten percentile value is approximately 0.48 scrams per 7,000 hours0 days 0 hours 0 weeks 0 months 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 1
d
3-E Safety System Actuations (INPO Definition)
O Fort Calhoun Goal O Industry Upper 10 Percentile 1
2- 1 l
l 1
1-. 1 Cycle 15 Refueling Outage 0 0 i s i i 0 C ,O,O i O , u i O , O i O , O , O , O , O ,
'91 92'93 Oct93 Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep94 UNPLANNED SAFETY SYSTEM ACTUATIONS -(INPO DEFINITION)
There were no INPO unplanned safety system actuations during the month of Septem-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 resulted in tripping relay 86B/CPHS. The CPHS relay trip actuated the Safety injection Actuation Signal, Containment Isolation Actuation Signal, Ventilation Isolation Actuation Signal and Steam Generator Isolation Signal. The Steam Generator Isolation Signal automatically closed both main steam isolation valves, which resulted in a concurrent turbine and reactor trip.
An INPO unplanned safety system actuation occurred during the month of July 1992. It ,
was due to the loss of an inverter and the subsequent reactor trip on 7/3/92.
The 1994 Fort Calhoun goal for this indicator is 0.
Data Source: Monthly Operations Report & Plant Licensee Event Reports (LERs)
Accountability: Jaworski/Foley/Ronning Adverse Trend: None 20 l
12 Month Running Total SSAs (NRC Definition)
--+-- Critical Hours
@ Safety System Actuations (NRC Definition) 10- - 1000
- 900 E 8- Cycle 15 - 800
$ Refueling _700 6- - 600 E -500 E 4- - 400
- 300 g 2- 200
, , , , 0 .
'91 '92 '93 ONDJ FMAMJJASONDJFMAMJJAS 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 equipment is operated and when the logic systems for these safety systems are challenged.
There was 1 NRC unplanned safety system actuation during the month of February 1994. It occurred on February 11 when supervisory relay 86B/CPHSS failed, which resulted in a concur-rent turbine and reactor trip.
There were 3 NRC unplanned safety system actuations in 1993: 1) In December 1993 the main turbine and reactor tripped during Electro-Hydraulic Control pump start testing; 2) in June 1993 the inadvertent jarring of a 345 KV fault relay in the switchyard caused a turbine and reactor trip; I and 3) In April 1993 a non-licensed operator mistakenly opened the wrong potential fuse drawer, causing a low voltage alarm on bus 1 A1, a loadshed on bus 1 A1 and an auto start of an EDG.
1 There were 4 unplanned safety system actuations in 1992: 1) In August, due to the failure of an AC/DC converter in the Turbine Electro Hydraulic Control system, pressurizer safety valve RC-142 opened prior to reaching design pressure during a plant transient and trip; 2) On July 3 l there was an inverter failure and the subsequent reactor trip; 3) On July 23 there was an l unplanned diesel generator start when an operator performing a surveillance test inadvertently pushed the normal start button instead of the alarm acknowledge button; and 4) In May the turbine generator tripped on a false high level moisture separator trip signal which caused a simultaneous reactor trip and subsequent anticipatory start signal to both diesel generators. ,
l There have been 2 unplanned safety system actuations in the last 12 months. The 1994 Fort Calhoun goal for this indicator is 0.
Data Source: Monthly Operations Report & Plant Ucensee Event Reports (LERs)
Accountability: Jaworski/Foley/Ronning Adverse Trend: None 30
1 . .
i, l E Monthly Gross Heat Rate
-M- Year to-Date Gross Heat Rate I V j O 1994 &1993 Fort Calhoun Goals l 10.5-l 1
)
Cycle 15 Refueling f 10223 10.25-j 10177 I O
! O i m j 4 10-3
's t
i --
9.75-
, , , i
'91 '92 '93 Oct93 Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep94 i
i GROSS HEAT RATE This indicator shows the Gross Heat Rate (GHR) for the reporting month, the year-to-date GHR, the goals and tha year-end GHR for the previous 3 years.
! The gross heat rate for Fort Calhoun Station was 10,271 for the month of September 3
1994. The 1994 year-to-date GHR was 10,207 at the end of the month.
! The GHR was not calculated for the months of October and November 1993 because of l the Cycle 15 Refueling Outage.
i i 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.
l The 1994 Fort Calhoun year-end goal for this indicator is s10,190.
l
] Data Source: Holthaus/ Gray (Manager / Source)
! Accountability: Chase /Jaworski i Adverse Trend: None i
31 I
j
Monthly Thermal Performance
-et-- Year-to-Date Average Monthly Thermal Performance 4
--G- 1994 & 1993 Fort Caihoun Goals l GOOD l
--+-- 1995 INPO Industry Goal ( 99.5%)
Industry Upper 10% (99.9%)
~
A i i 6 i i a i o i
^
Cycle 15 -
O O O O O. O O 2 O Refueling M _m _
_ $ @ n 7 99%- Outage .
g@
g g% .g 7 b
~~M p A~~
$ $* g$ ?n g NJ g y g +
@ a u o y y Q y Y' g;
^
y,@
y , g m -
98% , , , , , , , , , , , l Oct93 Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep94 '
1 THERMAL PERFORMANCE '
l l
! This indicator shows the Thermal Performance value for the reporting month, the year- ,
l to-date average monthly thermal performance value, the Fort Calhoun goals, the 1995 INPO industry goal and the approximate industry upper ten percentile value.
l The thermal performance value for September 1994 was 99.39%. The year-to-date l average monthly thermal performance value was 99.33% at the end of the month. The average monthly value for the 12 months fr0m October 1,1993 through September, 1994 was 99.35%.
l Thermal Performance improved in May as a result of the backwash valve adjustments on "A" Condenser and improvements in Heater 2A level control.
The low thermal performance value for February 1994 is attributable to level control i problems on heaters 3A and 58, and to spring runoff resulting in screen carry-over and l condenser fouling, improvements made during the month of March were: warm water recirc. was taken off-line; some recovery in condenser performance was achieved due to backwashing at regular intervals; and the level control problems for heater 3A were
~~corrected.~~
The 1994 Fort Calhoun year-end goal for this indicator is a minimum of 99.5%. The 1993 Fort Calhoun goal was a minimum of 99.4%. The 1995 lNPO industry goalis 99.5% and the industry upper ten percentile value (for the one year period from 7/93 through 6/94) is approximately 99.9%.
l
! Data Source: Jaworski/Popek l Accountability: Jaworski/Popek l Adverse Trend: None
! 32 l
l
0 Thermal Output
--O- Fort Calhoun 1495 A'W Goal
- Tech Spec 1500 MW Limit 1500 1499.5-1495-1498.5-1498-149:.5 -
1497-1496.5 -
1496-1495.5-1495< )
1494.5- ,
1494 - ,
1493.5- -
1493- "A 1492.5-1492-- ,
1491.5-1491-1490.5-1490 , , , , , , , , , , , , , , , , , , , , , , , , , , , ,
1 3 5 7 9 11 13 15 17 19 21 23 25 27 29 DAILY THERMAL OUTPUT The thermal output graph displays the daily operating power level during September 1994, the 1500 thermal megawatt average technical specification limit, and the 1495 thermal megawatt Fort Calhoun goal.
Data Source: Holthaus/ Gray (Manager / Source)
Accountability: Chase / Tills Adverse Trend: None 33
i . .
~
, Equipment Forced Outage Rate /1.000 Critical Hours 0 1994 Fort Calhoun Year End Goal (02) 0.75-l GOOD l V
0.5 0.5 -
i i
0.25-C O O O O Q-O
~~O O O O O~~
~~O i i i i 0 , , , , , , , , , , , ,~~
'91 '92 '93 Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 l
EQUIPMENT FORCED OUTAGES PER 1,000 CRITICAL HOURS 3 The equipment forced outage rate per 1,000 critical hours was 0.15 for the months from January through September 1994. The rate for the 12 months from October 1,1993 through September 30,1994 was 0.13.
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 i Containment High Pressure Signal Supervisory Circuit. l 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. I Data Source: Monthly Operations Report & Plant Licensee Event Reports (LERs)
Accountability: Chase /Jaworski Adverse Trend: None l
N
I I
l
- # of Component Categories 40-
-+- # of Application Categories 35-30- -*- Total # of Categories
$ i f 25- ~
?
g 20- >
O j g 15-
~~" " = "~~
10-5- _
0 , , , , , , , , , , , , , , , , , ,
A93 M J J A S O N D J F M A M J J A S94 E WearOut/ Aging @ Other Devices 1 8 Manufacturing Defect O Maintenance / Action ,
4.7%
7.0% 0 Engineering / Design @ Error / Operating Action ;
~~41. 4.7%~~
Percent of Total Failures During
,- the Past 18 Months l
3.7%
{
8.1d'Illll COMPONENT FAILURE ANALYSIS REPORT (CFAR)
~~SUMMARY~~
The top chart illustrates the number of component categories, application categories and total categories in which the Fort Calhoun Station has significantly higher (1.645 standard deviations) failure rates than the industry failure rates during the past 18 months (from December 1992 through May 1994). Fort Calhoun Station reported a higher failure rate in 5 of the 87 compo-nent categories (valves, pumps, motors, etc.) during the past 18 months. The station reported a higher failure rate in 7 of the 173 application categories (main steam stop valves, auxiliary /
emergency feedwater pumps, control element drive motors, etc.) during the past 18 months.
The pie chart depicts the breakdown by INPO cause categories (see the " Definitions" section of this report for descriptions of these categories) for the 99 failure reports that were submitted to INPO by Fort Calhoun Station during the past 18 months. Of these, the failure cause was known for 86. The pie chart reflects known failure causes.
Data Source: Jaworski/ Edwards (Manager / Source)
Accountability: Jaworski/ Edwards Adverse Trend: None 35
1
~~Components With More Than One Failure l GOOD l ;~~
Y 25- X Components With More Than Two Failures l
l 20-15- 14 12 12 12 12 10 10- v 9 8 8 7 -
5- ,4, 4, (2
X 2,
'N' '
1 1 1 Oct93 Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep94 REPEAT FAILURES The Repeat Failures Indicator (formerly called the " Maintenance Effectiveness" perfor-mance indicator) was developed in response to guidelines set forth by the Nuclear Regulatory Commission's Office for Analysis and Evaluation of Operational Data (NRC/
AEOD). The NRC requirement for a Maintenance Effectiveness Performance Indicator has been dropped, but station management considers it useful to continue to track repetitive component failures using the Nuclear Plant Reliability Data System (NPRDS).
This indicator shows the number of NPRDS components with more than 1 failure during the eighteen month CFAR period and the number of NPRDS components with more than 2 failures during the eighteen month CFAR period.
During the last 18 reporting months there were 8 NPRDS components with more than 1 failure.1 of the 8 had more than 2 failures. The tag numbers of the components with 1 failure are: AC-10A, AC-10C, AC-10D, FW-4B, FW-4C, HCV-386-0, NT-001 and RC-374. The tag number of the component with more than 2 failures is AC-10C. Recom-mendations and actions to correct these repeat component failures are listed in the quarterly Component Failure Analysis Report. ,
1 l
l Data Source: Jaworski/ Edwards (Manager / Source) )
Accountability: Chase Adverse Trend: None 36
Calculated Check Valve Failure Rate per Million Component Hours !
l GOOD l l Calculated Industry Check Valve Fa/ure Rate per l Million Cornponent Hours 4 3- -O- Fort Calhoun Goal 2.5 -
2- C O O !
9 15 -
tu I I 1_
0.5 -
l 0 , , , , , , , , , , , ,
( '91'92'93 Oct93 Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep94 I
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 l are based on submitted NPRDS failure reports for an 18 month time interval. They do l 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 September 1994 Component Failure Analysis Report (CFAR) covers the 18 month interval from December 1,1992 through May 31,1994. This delay is due to the time involved in collecting and processing failure report data.
I 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 September 1994, the CFAR provided the following failure rates:
l Fort Calhoun Station 1.17 E-6 l Industry (excluding FCS) 1.62 E-6 l
The recent increase in the FCS failure rate is due to 2 reportable failures of RC-374, Pressurizer RC-4 Spray Line Check Valve; one failure occurred in October and another in November 1993.
The 1994 Fort Calhoun monthly goal for this indicator is 5;1.75 E-6.
l Data Source: Jaworski/ Edwards (Manager / Source)
Accountability: Jaworski/Rollins Adverse Trend: None SEP 43 37
C 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 1995 INPO Industry Goal (3,884 cubic feet) 600 -
-O- Industry Upper 10% (965.3 cubic feet)
C C C C C /O 450-u.
I O 300 -
150 - ~,M
$$ .b, k
$$[ik. '5 'l Gn #$M .
O
'dm -
Jan94 Feb Mar Apr May Jun94 l
l VOLUME OF LOW-LEVEL SOLID RADIOACTIVE WASTE This indicator shows the volume of the monthly radioactive waste buried, the cumulative annual total for radioactive waste buried, the Fort Calhoun and INPO goals, and the approximate industry upper 10%.
Amount of solid radwaste shipped off-site for processing during June (cubic feet) 0.0 Volurne of Solid Radwaste Buried during June (cubic feet) 206.0 Cumulative volume of solid radioactive waste buried in 1994 (cubic feet) 543.6 Amount of solid radioactive waste in temporary storage after July 1,1994 (cubic feet) 0.0
! The 1994 Fort Calhoun goal for the volume of solid radioactive waste which has been
! buried is 500 cubic feet. The goal was exceeded in June because OPPD's 18 month
! goal (established in 1993) allowed the opportunity to further reduce the amount of solid l radioactive waste. The 1995 INPO industry goalis 110 cubic meters (3,884 cubic feet) l 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 l Fort Calhoun was 1,401.4 ft.8 at the end of June 1994.
SEP54 38 L_________-______
i E Primary System Chemistry Percent of Hours Out of Limit l GOOD l
. --O- Fort Calhoun Goal V 3%-
2%- C C C C C C C C C C 1%-
0% ; ; ; ; ; ; i Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 PRIMARY SYSTEM CHEMISTRY PERCENT OF HOURS OUT OF LIMIT The Primary System Chemistry Percent of Hours Out of Limit indicator tracks the pri-mary system chemistry performance by monitoring 6 key chemistry parameters. The key parameters are: lithium, dissolved oxygen, chlorides, fluoride, hydrogen a .d sus-pended solids.100% equates to all 6 parameters being out of limit for the month.
l The Primary System Chemistry Percent of Hours Out of Limit was 0.0% for the month of September 1994.
The 1994 Fort Calhoun monthly goal for this indicator is a maximum of 2% hours out of limit.
Data Source: Smith / Spires (Manager / Source)
Accountability: Chase / Smith Positive Trend 39 1
E Secondary Systern CPI 2- l GOOD l
--O- Fort Calhoun Goal 4
1.9 -
1.8 -
1.7 -
1.6 -
1.5 - O O O O O O O O O O O 1.4 -
1.3 -
1 1 i i i i i i i i i i Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 SECONDARY SYSTEM CHEMISTRY Criteria for calculating the Secondary System Chemistry Performance Index (CPI) are:
~~1) The plant is at greater than 30% power; and 2) the power is changing at less than 5%~~
per day.
The CPI for September 1994 was 1.11. The year-to-date average monthly CPI value was 1.19 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, j and focuses more on specific impurities. j 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.
41
4-Actuais -O- Budget A Plan 3.75-1 -
3.5 -
I IC I 3.25-i E
, b i 3-4 i
! 2.75-1 4 ,
2.5 , , , ,_ , , , , , , , , , , , , , , , j D91 D92 D93 J94 F M A M J J A S O N D94 D95 D96 D97 D98 l j Months CENTS PER KILOWATT HOUR j The purpose of this indicator is to quantify the economical operation of Fort Calhoun l Station. This indicator is one month behind the reporting month due to the time required
) for collecting and processing the data.
l
, The cents per kilowatt hour indicator represents the budget and actual cents per kilowatt
hour on a 12 month rolling average for the current year. The basis for the budget curve i is the approved 1993 and 1994 revised budget. The basis for the actual curve is the Financial and Operating Repod.
i The December 31 amounts are also shown for the prior years 1991,1992 and 1993. In l addition, the report shows the plan amounts for the years 1995 through 1998 for refer- I
~~ence. The basis for the dollars are the Nuclear Long Range Financial Plan and the 1994 Corporate Planning and Budget Review. The basis for the generation is provided by Nuclear Fuels.~~
l The unit price (3.01 cents per kilowatt hour for the reporting month)is averaging lower
.i than budget due to expenses being below budget while generation exceeds the budget.
Data Source: Scofield/Jamieson (Manager / Source)
Accountability: Scofield Positive Trend 42 I
_ _ _ .. - __ _ _ _0
@ Nuclear Services Division Staffing Production Engineering Division Staffing lM Nuclear Operations Division Staffing
+ Total Nuclear Staffing 7 8 7 7
0 7 7 8 9 8 4 2 800- 5 9 y-x ,. _ _
700- k I k $ k, b A 5 i$ 5 7 S g fll ,
y ,
600 - 3 g (( 4 5 4 4 4
~~w w~~
~~6 R 5~~
~~e e gy 5 4 500- S+-~~
b -
u a
+
y ; ig > .,
' g h E h g
400- g g .g i j 2 $ 1 k 2 $ 2 $ 1 g* 1 1 'hkh 0 y 9 h 0 $ 0 y y 9 $ 8 h6 3 S 5 $# 6 "i 13 ^
1 g 1 1 4" 1 8
200- -
j*]*
~~1- !n; 1~~
%gj 1_ g 1 _ 7
's i: 4 LJ 7 6 fi 6
i i i i i i i Jan90 Jan91 Jan92 Jan93 Jan94 Apr94 Jul94 ACTUAL STAFFING LEVEL (UPDATED QUARTERLY)
STAFFING LEVEL The actual staffing levels for the three Nuclear Divisions are shown on the graph above.
The authorized staffing levels for 1994 are:
1994 Authorized Staffing 1
453 Nuclear Operations Division !
I 191 Production Engineering Division 117 Nuclear Services Division l
Data Source: Ponec (Manager & Source)
Accountability: Ponec Adverse Trend: None SEP 24 i 43
- _ = _
i .
- Spare Parts inventory Value ($ Million) 17- Cycle 15 Refueling Outage
^
16- __
15-l 8
_m
]14-O E
,o 13-12-11-10 , , , , , , , , , , , ,
Oct93 Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep94 SPARE PARTS INVENTORY VALUE The spare parts inventory value at the Fort Calhoun Station at the end of September 1994 was reported as $16,204,780.
Data Source: Steele/Huliska (Manager / Source)
Accountability: Willrett/McCormick Adverse Trend: None 44
i DIVISION AND DEPARTMENT PERFORMANCE INDICATORS These indicators may be deleted from this report if the responsible group con-tacts the Manager - Station Engineering to request their removal. Indicators referencing SEP ltems require documentation to ensure that the original intent and scope of the SEP ltem will not to altered by removal of the indicator from this report.
l l
1 1
45 l
l O Corrective Maintenance @ Non-Corrective / Plant improvements B Preventive Maintenance O Fod Calhoun Goal 776 800 - 723 752 720 691 700 - A 626 A
- 581 600 - . . ,
500 -
^ '
400 -
300 - " "
}
y 3 y, y, 3 200-Sh
'/
hh
//
hf
//
~~h'l~~
'/,
)h:
//,
hh
// -
'/ // // '// //, //
R I M i
[771 i
rm i
F71 i
$d i
55 i
d5 i
$d' i
'55' i
l l
Oct93 Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep94 Non-Outage Maintenance Work Order Backlog O TotaiuWos a MWOs Which Exceed Maintenance Completion Goals 400 -
350 - 303 300 - 255 250 -
l 200 -
150 -
100 - >3 " >90 60 45 ~ ~ 180 ,
5 3 days ays days k ~85,h > days l 1 326 xwxi h~87)
, l I
I i i i i I l
Priority 1 Priority 2 Prionty 3 Priority 4 Priority 5 Priority 6 Non-Outage Maintenance Work Order Aging l
1 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:
Goal Priority 1 Emergency N/A Priority 2 Immediate Action 3 days l Priority 3 Operations Concern 14 days Priority 4 Essential Corrective 90 days Priority 5 Non Essential Corrective 180 days l Priority 6 Non-Corrective / Plant Improvements N/A l Data Source: Chase /Schmitz (Manager / Source) l Accountability: Chase /Faulhaber Adverse Trend: None SEP 36 46
O Ratio of Preventive to Total Maintenance 100Y.- _ ,,,,,,,,
90%-
80%- ,
70%- r 9%
~ ~~~
60%- 4 f -
50%- *
~~x -~~
u 40%- $$$i B > >
30%- 7 20%- U .' f: g 3 10% - q , ; ?%
0% , , , , , , , i i i i i Oct93 Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep94 2%- GOOD O Preventive Maintenance items Overdue
-O- Fort Calhoun Goal V 0
1%- Unavailable due to Cycle 15 Refueling O-O-O-O-E _O,,, O __O hO Outage 0% , , , , , , , , , , , ,
Oct93 Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep94 RATIO OF PREVENTIVE TO TOTAL MAINTENANCE &
PREVENTIVE MAINTENANCE ITEMS OVERDUE The top graph shows the ratio of completed non-outage preventive maintenance to total completed non-outage maintenance.
The ratio of preventive to total maintenance was 47.4% for the month of September 1994. The trend of this ratio reflects the revised definition of corrective maintenance I which was implemented in March.
The lower graph shows the percentage of preventive maintenance items overdue.
During September,614 PM items were completed. 3 of these PM items (0.48% of the total) were not completed within the allowable grace period or administrative!y closed.
The 1994 Fort Calhoun monthly goal for the percentage of preventive maintenance items overdue is a maximum of 0.5%.
Accountability: Chase /Faulhaber Data Source: Chase /Schmitz/Meistad (Manager / Sources)
Positive Trend SEP 41 47
E Rework As identified By Planning or Craft
-O- Fort Calhoun Goal 5.2%
5%-
t h4%-
y 3.16%
3%- O O O O O 2.51 % 2.44%
-g 2.43 %
2.06 % )
'o 2% -
E 1.58 % 1 0
1%-
0% ; -;- -i--- ; i- i i Mar 94 Apr May Jun .ht. Aug Sep94 PERCENTAGE OF TOTAL MWOs COMPLETED l PER MONTH IDENTIFIED AS REWORK l
This graph indicates the percentage of total MWOs completed per month identified as j rework. Rework activities are identified by maintenance planning and craft.
The 1994 Fort Calhoun monthly goal for this indicator is <3%.
j Data Source: Faulhaber/Schmitz (Manager / Source) 1
( Accountability: Chase /Fauthaber l Adverse Trend: None O
l
?
)
l I 80%- G Maintenance Overtime l l j --M- 12 Month Average Maintenance Overtime lGOODI
-O- Fort Calhoun "On-Line' Goal I
i
~~60%-~~
50%-
Cyce 15
~~Refueling Outage~~
+
40%-
30%-
i j 20%-
I 0o,o ; ; ; ; ; ; ; j
, i i i i j Oct93 Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep94 MAINTENANCE OVERTIME 4
The Maintenance Overtime Indicator monitors the ability to perform the desired mainte-
[ nance activities with the allotted resources.
i i The percent of overtime hours with respect to normal hours was reported as 7.5% for
. the c.onth of September 1994. The 12 month average percentage of overtime hours I wna respect to normal hours was reported as 12.6% at the end of the month.
The 1994 Fort Calhoun monthly "on-line" goal for this indicator is a maximum value of 10%.
]
! Data Source: Chase /Schmitz (Manager / Source)
Accountability: Chase /Faulhaber Positive Trend i 49
(
4
I
(
- 0 Open irs Related to the Use of Procedures (Maintenance) 4 3- ;
@ Closed irs Related to the Use of Procedures (Maintenance)
E Procedural Noncompliance irs (Maintenance) i 2-1 1 1 1 1- - - -
0 0 000 000 000 000 00 00 000 000 000 000 0 0
, , , , , , , , , , , i Oct93 Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep94 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 was 1 procedural noncompliance incident (IR 940323) for maintenance reported for the month of September 1994. The IR was written to document procedural noncom-pliance that occurred when a mercury thermometer was used, rather than the required alcohol thermometer, during a surveillance test.
Data Source: Chase / Keister (Manager / Source)
Accountability: Chase / Conner Adverse Trend: None SEP 15,41 & 44 50
E Completed Scheduled Activities (All Crafts)
O Numberof Emergent MWOs Completed O Fort Calhoun Goal m 110
~~IE- 100 v 92 o~~
--U 90%- 90 gE l
<C C 80%- :[y 0 0 0 gog l 70%- :hI 70 3
=
jy: o j 60%- / 60 2 51 y 50%- /: m
/// --
46 50 g o
o .
3 40%- 7/- W rempleted //': % Completed 7,'. % Completed 40 E' 3 hk Scheduled :/f' Scheduled $ Scheduled d o 5 M-
'/f Activities Not ;-(( Activities Not fp ;'jj Activities Not , 30 h M
20%- p Availab!9 : Available y Available g E h/. /// '//, /// d 5 10% -
" [I
~~e(( $[$ ;-(( 10 Z~~
'//. /// '//, ///
b 0%-
' ' ' : :- ; :f :, % 0 0 June'94 July August September '94 PERCENT OF COMPLETED SCHEDULED MAINTENANCE ACTIVITIES (ALL MAINTENANCE CRAFTS) l This indicator shows the percent of the number of completed scheduled maintenance activities as compared to the number of scheduled maintenance activities concerning all Maintenance Crafts. Maintenance activities include MWP.s, MWOs, STs, PMOs, cali-brations, and miscellaneous maintenance activities. The number of emergent MWOs completed for the month is also shown.
The percent of the number of completed scheduled maintenance activities as compared to the number of scheduled maintenance activities for the months of July, August and September 1994 are not available due to the software and data collection method changes involved with the implementation of the Integrated Plant Schedule. There were 34 emergent MWOs completed during the month of September.
The 1994 Fort Calhoun monthly goal for completed scheduled maintenance activities is 80%.
Data Source: Chase /Schmitz (Manager / Source)
Accountability: Chase /Faulhaber Adverse Trend: None SEP 33 51
E % of Hours the In-Une Chemistry Instruments are Inoperable 12- -O- 1994 Fort Calhoun Goal ( 10%)
11-10- C C C C C C C C C C C O 9-8-
p 7-E 6-E 5-h0 Jan94 Feb i
Mar i
dIl Apr i
May i
Jun i
Jul IN-LIN" CHEMISTRY INSTRUMENTS OUT-OF-SERVICE i
Aug i
Sep i
Oct
~~i Nov Decs4 i~~
This indicator shows the percentage of hours the in-line chemistry system instruments are inopercble 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 September 1994 the percentage of hours the in-line chemistry system instruments were inoperable was 5.72%.
The major contributors to this month's inoperability were due to a discrepancy between the operating procedure and the drawing for the PASS RCS isotopic sequence, the i feedwater FW-16 hydrazine analyzer sample pressure sensor, and the sodium analyzer
~~for the waterplant cation bed effluent.~~
i 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 l
function associated with the instrument is inoperative. If any of the functions listed J
above are not operational, then the instrument is not performing its iritended function. i 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 /Roneaud (Manager / Source)
Accountability: Chase /Jaworski ,
Positive Trend l 52 I
i
@ Waste Produced Each Month (Kilograms)
Monthly Average Waste Produced During the Last 12 Months (Kilograms)
-O- Fort Calhoun Monthly Average Goal
-B-- Federal & State Monthly Limit (Max. of 1,000 Kg) 1000 - C = = = 2 E E E 2 e,w -
$ 600-G
--E g 400 -
200-C O O O O F M O O O O O i i i i i i , i i i i i Oct93 Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep94 HAZARDOUS WASTE PRODUCED This indicator shows the total amount of hazardous waste produced by the Fort Calhoun Station each month, the monthly average goal and the monthly average total for hazard-ous waste produced during the last 12 months. This hazardous waste consists of non-halogenated hazardous waste, halogenated hazardous waste, and other hazardous waste produced.
During the month of September 1994,0.0 kilograms of non-halogenated hazardous waste was produced,0.0 kilograms of halogenated hazardous waste was produced, and 0.0 kilograms of other hazardous waste was produced. The total for hazardous waste produced during the last 12 months is 161.4 kilograms. The monthly average for hazardous waste produced during the last 12 months is 13.45 kilograms.
Hazardous waste is counted based upon a full drum of waste.
The 1994 Fort Calhoun monthly average goal for hazardous waste produced during the last 12 months is a maximum of 100 kilograms.
Data Source: Chase / Smith (Manager / Source)
Accountability: Chase / Smith Positive Trend 53
i 5
i
~~25% -~~
E Contaminated Radiation Controlled Area Fort Calhoun Goat (non-outage months) l GOOD l
! -O-
! V q -O- Fort Calhoun Goal (outage months) 1
} 20% -
j 15%-
I I
j 2 0% _
e o o l~ lllllllll i
l Wu 4 Jan94 Feb i
Mar i
Apr i
May i
Jun i
Jul CONTAMINATED RADIATION CONTROLLED AREA i
Aug i
Sep i
Oct i i Nov Dec94 l
i 1
! This indicator shows the percentage of the RCA that is contaminated based on the total i square footage. The 1994 monthly non-outage goalis a maximum of 10% contami-
! nated RCA and the monthly outage goalis a maximum of 13% contaminated RCA.
I At the end of September 1994, the percentage of the total square footage of the RCA that was contaminated was 9.5%.
l l Data Source: Chase /Gundal(Manager / Source) i
Accountability

Chase /Lovett 1
Positive Trend SEP 54 l
i i
i 54 i . _ - .
1 i
i Nurnber of identified PRWPs Year-To-Date i
i IGOODI 30- -O- 1994 Fort Calhoun Goal (<25) y 25- C C C C C C C C C C C O
! J
! i i
l g
} E20- j j s '
i 8
. Q 15-
~~.E E~~
~~' ce j g10-O 5-4 i _~~
~~_ s -~~
4 0 , , , , , , , , , , , , l Jan94 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec94 l RADIOLOGICAL WORK PRACTICES PROGRAM 1 The Radiological Work Practices Program Indicator shows the number of Poor Radio-i logical Work Practices (PRWPs) which were identified during the reporting month.
i
~~The number of PRWPs which are identified each month should indirectly provide a means to qualitatively assess supervisor accountability for their workers' radiological~~
! performance.
During the month of September 1994, there were no PRWPs identified.
j There have been 6 PRWPs in 1994.
! The 1994 year-end goal for the number of PRWPs is a maximum of 25.
4 d
Data Source: Chase /Uttle (Manager / Source)
Accountability: Chase /Lovett
~~Adverse Trend: None SEP52~~
.J 55
]
__ _ . . _ . _ . . _ _ ~. _ _ _ _ _. ~ _ _ __. . _ _ _ _.
j . .
i
! Documents Scheduled for Review j
ti Documents Reviewed j n Overdue Documents l 350 -
)
i 300-.
4 i
j 250 -
i, j 200 - -
1 1 E 150-1 :
i _
, 100- -
1 4
{ 50 - -
j 0 i , i i "", , , ,
i i
]
Oct93 Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep94
) DOCUMENT REVIEW 3
i 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 i Security Plan, Maintenance Procedures, Preventive Maintenance Procedures, and the j Operating Manual.
During September 1994 there were 97 document reviews scheduled, while 162 docu-i ment reviews were completed. At the end of the month, there were no document re-
! views more than 6 months overdue. -
4 There were 16 new documents initiated this month.
l Data Source: Chase / Keister (Manager / Source) l Accountability: Chase /Jaworski i
) Adverse Trend: None SEP 46 j
56 I c
.,m.
I E Non-System Failures lGOODI 30-25 - V 20 -
15- 12 10 10- 7 4 4 5- 3 3 2 2 2 3 3
" ,"i "i " "
0 i i i "i i "i i ; l Oct93 Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep94
, 90 - @ System Failures l GOOD l 80- y 70 -
l 60 -
, 50-l 40- 31 32 0 , , i , , , , , , , , ,
Oct93 Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep94 LOGGABLE/ REPORTABLE INCIDENTS (SECURITY)
The Loggable/ Reportable incidents (Security) Indicator is depicted in two separate graphs. The top graph depicts the total number of loggable/ reportable non-system failures concerning Security Badges, Access Control and Authorization, Security Force Error, and Unsecured Doors. The bottom graph shows the total number of loggable/
reportable incidents conceming system failures which occurred during the reporting month.
During the month of September 1994, there were 13 loggable/ reportable incidents identified. System failures accounted for 10 (78%) of the loggable/ reportable incidents.
8 of the 10 system failures were environmental failures due to poor weather conditions.
An ECN to rectify the metal detector spiking problem in the Primary Access Portal was completed during the reporting month. The new X-ray machine has arrived on site and is scheduled for installation in October 1994. System and non-system failures contin-ued on a downward trend in 1994.
Data Source: Sefick/Woerner (Manager / Source)
Accountability: Sefick l Adverse Trend: None SEP 58 57
E Temporary Modifications >1 cycle old (RFO required for Removal)
O Temporary Modifications >6 months old (Removable on-line)
--O- Fort Calhoun Goal for Temporary Modifications >1 cycle cid
-- O - Fort Calhoun Goal for Temporary Modircations >6 me . s old 8-7- 6
~
4 4 h ',c , ,',
2~
nn nyx b'S% 15S?S 1 S 1 /I 1 1
[ [ j i June '94 July '94 August '94 September '94 TEMPORARY MODIFICATIONS This indicator provides information on the number of temporary modifications greater than one fuel cycle old requiring a refueling outage (RFO) for removal and the number of temporary modifications removable on-line that are greater than six months old. In addition, the 1994 Fort Calhoun monthly goals for this indicator are zero, however, specific temporary modifications have been approved by management to exceed these goals due to cost effectiveness considerations. These are listed below.
There is currently 1 temporary modification that is greater than one fuel cycle old requir-ing a refueling outage to remove: Epoxy repairs to ST-48, which is awaiting completion of MWO 931325, scheduled start date 1995 Refueling Outage. This temporary modifi-cation was previously included in the on-line removable >6 months old classification, but was re-classified as an outage modification to save engineering resources from com-pleting 1 ECN to allow the epoxy repair to remain in place and a second ECN to remove it during the 1995 refueling outage. In addition, at the end of September 1994 there were 6 temporary modifications installed that were greater than six months old that can be removed on-line. These were: 1) Local indication for BAST CH-11 A and CH-118, in which Operations is reviewing a draft FLC. After review, Licensing is to issue an FLC, and the NRC is to approve; 2) LP-30 transformer, in which ECN 93-183 is approved for accomplishment prior to 10/94; 3) Swap leads for DG-1 shutdown solenoid, which is awaiting completion of MWO 941809, scheduled for the next DG-1 outage; 4) FW-2A/
B/C local sample point installation in which ECN 94-054 is approved for accomplish-ment prior to 11/94; and 5) Replace FP-156 with new design plug valve, which is await-ing the completion of MR-FC-92-019, scheduled for completion 12/94.
At the end of September 1994, there was a total of 27 TMs installed in the Fort Calhoun Station.16 of the 27 installed TMs require an outage for removal and 11 are removable on-line. In 1994 a total of 36 temporary modifications have been installed.
Data Source: Jaworski/ Turner (Manager / Source)
Accountability: Jaworski/Gorence ,
Adverse Trend: None SEP 62 & 71 i 58 ;
l
l
@ Total Modification Packages Open 264 250 - --O- Fort Calhoun Year-End Goal i
a$
$ 200 -
)
^
5N 150 - C '
EE 127 b
M E
%' 100
$h 100 -
73 g Q Q k % l l 7 M % % 's l l QN "5
@ idi sa s;n _ E i : t M 6 el "? T E, gy p --
~~, c $ pS $~~
A >
,!)[! I . .: 4 m$ &
Y f"l fh@f(.. _ L L h'k! DIf in M L ;
J khi $
i i i i 0 , , , , , , , , , , , ,
'91 '92 '93 Oct93 Nov Dec Jan Feb Mar Apr May Jun Jul Aug sep94 OUTSTANDING MODIFICATIONS This indicator shows the total number of outstanding modifications (excludina outstand-ina modifications which are orooosed to be cancelled).
Category Reoorting Month Form FC-1133 Backlog /in Progress 2 Mod. Requests Being Reviewed 4 Design Engr. Backlog /in Progress 25 Construction Backlog /In Progress 17 Desian Engr. Uodate Backloa/In Proaress 9 Total - 57 At the end of September 1994,17 additional modification requests had been issued this i year and 41 modification requests had been cancelled. The Nuclear Projects Review I Committee (NPRC) had completed 120 backlog modification request reviews this year.
The Nuclear Projects Committee (NPC) had completed 57 backlog modification request reviews this year.
The 1994 year-end Fort Calhoun goal for this indicator is a maximum of 80 outstanding modifications.
Data Source: Jaworski/ Turner (Manager / Source)
Scofield/Lounsbery (Manager / Source)
Accountability: Scofield/Phelps Adverse Trend: None 59 l
l - _ _ -
I EARS Requiring Engineering Closeout - Not in closeout l O DEN M SE 70-60 -
40- 50 -- _
40- 40-30- 30- 30- - 30-
"""~
20- - 20- _
20- -
20-10- 10- 10- 10-0 , , ,0 , , ,0 , , ,0-- 7 7 ,
Jul Aug Sep Jul Aug Sep Jul Aug Sep Jul Aug Sep 0-3 months 3-6 months 6-12 months >12 months September 44 Overdue EARS O Closeout (SE) O Engineering Response I
~
id4%b I I ,
s i i i i i i Priority 0 Priority 1 Priority 2 Priority 3 Priority 4 Priority 5 Priority 6 l
0 Priority 1 & 2 O Priority 3 Total Open EARS 200 -
150 -
100 - _ _ _ _ - _ _
50 - p ] gi @y t,, ,. 1B (R g g i i i i i I 3 I i i I 8 Oct93 Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep94 O n memue Responses O 57 EARS Resolved and in Closeout E 48 Overdue Closeouts O 113 EARS Requiring Response B 48 EARS on Schedule 28.2 %
33.5 %
IlllllllI 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 10 EARS closed during the month 14 Total EARS open as of the end of the month 170 Data Source: Skiles/McShannon (Manager / Source)
Accountability: Jaworski/Skiles Adverse Trend: None SEP 62 so
E in DEN - 170 E n es - m
~~6. 8.2% O in System Engineering .133 34.7 s , _ , , "~~
~~O in Procurement /Constr. - 140 h3.3% ' 19.3 % 0~~
~~ms - m~~
@ in Closeout = 159 ECN STATUS - OVERALL BACKLOG E ECNs Backlogged O ECNs Received During the Month O ECNs Completed During the Mor'th o
E 0-3 Months - 94 yo l C 3-6 Months - 37
[ I
.8Y.
55.3 %
~~O >6 Months - 39 l May Jun Jul Aug Sep94 Apr94 (Year-to-Date monthly average of ECNs received was 49.8)~~
ECH STATUS - DEN 250 -
25.6% 5 0-3 Months - 34 200 - Q
~
60.9 % 13.5%
50 -
mN O >6 Months = 81 0
i 3 May Jun Jul Aug Sep94 Apr94
[
ECN STATUS - SE 250 -
o E 0-3 Months = 55 200- -
42.8 % 9.3%
150- C 3-6 Months = 25
-- 17.9% 0 >6 Months - 60 0 ,""", , , , ,
Apr94 May Jun Jul Aug Sep94 ECN STATUS - PROC /CONSTR 250-200 - @
~
~~18. E 0-3 Months - 94 150 -~~
50 .
O > Mon hs .
3 i i a i e Apr94 May Jun Jul Aug Sep94 ECH STATUS - CLOSEOUT ENGINEERING CHANGE NOTICE STATUS Data Source: Skiles/McShannon (Manager / Source)
Accountability: Skiles/Jaworski SEP 62 Adverse Trend: None 61
E FC Type = 199 E Priorny 1 & 2 = 100
) y SRI Type = 250 L#
8 Priority 3 & 4 - 321 3
41.5 % O DC Type = 153 '
53.3 %
0 Prionty 5 & 6 = 181 v
TOTAL OPEN ECNS BY TYPE (602 TOTAL)
TOTAL OPEN ECNs BY PRIORITY (602 TOTAL)
D DEN Engineering Not Complete E System Engineering - Response, Confirmation Not Complete
@ Maintenance / Construction / Procurement - Work Not Complete B DEN - Closeout or Drafting Not Complete 250 -
203 205 213 26 200 204 199 150 -
5 M E Priorny 1 or 2 100 -
90 @ Prionty 3 or 4 50- ;
'g---.61.3%7 O Priority 5 or 6 0 j l i ; g 3
Apr94 May Jun Jul Aug Sep94 Facility Change ECNs Open 2 244 241 247 250 230 E Priority 1 or 2 150 -
66 ,
@ Priordy3 or 4 100 -
50- 50 62 M O Priority 5 or 6 0 g %-
~~; j i t i Apr94 May Jun Jul Aug Sep94 Substitute Replacement item ECNs Open 250 -~~
E Priority 1 or 2 200- -
L88 181 182 188 8%
g_ 66.6 %
@ Priority 3 or 4 47 100 - O Priority 5 or 6 50-0-- 7 g i ; ; i Apr94 May Jun Jul Aug Sep94 Document Change ECNs Open ENGINEERING CHANGE NOTICES OPEN Data Source: Skiles/McShannon (Manager / Source)
Accountability: Skiles/Jaworski Adverse Trend: None 62 SEP 62
l I
E in DEN - 170 6.4 E 0-3 Months - 277
~~8. O in System Engineering .133 34 3 l 6MI O 3 6 Months - 116 !~~
I a D3.3% O in Procurement /Constr. - 140 22.1 % O >6 Months = 209 19.3%
@ in Closeout - 159 ;
l ECN STATUS OVERALL BACKLOG E ECNs Backlogged j O ECNs Received During the Month
~~@ ECNs Completed During the Month~~
!, 250 - o E 0-3 Months - 94 22.
l 200 - D I 150 - 1 55.3 %
O 3-6 uontns - 37
_ O >6 Months = 39 i
O , , ', , , ,
Apr94 May Jun Jul Aug Sep94 (Year-to-Date monthly average of ECNs recei red was 49.8)
ECN STATUS - DEN 1
3 250 -
E 0-3 Months = 34 0 6 Mon hs = 81 i i i i i Apr94 May Jun Jul Aug Sep94 j ECH STATUS - SE i 250 -
200 - o . E 0-3 Months - 55 ,
I 42.8 % 39.3 % 3-6 Months = 25 9 17.9% 0 >6 Months - 60 a
r Apr94 May Jun Jul Aug Sep94 j ECN STATUS PROC /CONSTR 2
i 250 -
1 2
200 - g l 150 - 18.2% E 0-3 Months 94 l
100 - O 3-6 uonths . 36
- og .22.6 59.
O , , , , ,
] ,
O >6 Months . 29 d
Apr94 May Jun Jul Aug Sep94 ECN STATUS - CLOSEOUT ENGINEERING CHANGE NOTICE STATUS j Data Source: Skiles/McShannon (Manager / Source)
} Accountability: Skiles/Jaworski
~~Adverse Trend: None SEP 62~~
~~61 i~~
E FC Type - 199 "A
16.6% 3 Priority 1 & 2 = 100 25.4 % 3.1 30.1%
i @ SRI Type = 250 j 8 Priority 3 & 4 - 321 1.5 O DC Type = 153 b 53.3%7 m -
O Prionty 5 a 6 = 181 TOTAL OPEN ECNS BY TYPE (602 TOTAL) TOTAL OPEN ECNs BY PRIORITY (602 TOTAL)
O DEN - Engineering Not Complete
@ System Engineering - Response, Confirmation Not Complete Q Maintenance / Construction / Procurement - Work Not Complete E DEN - Closecut or Drafting Not Complete 205 213 204 199 E Prionty 1 or 2 100 - go ; @ Priorny 3 or 4 50- '
'*, O Priority 5 or 6 51 0 , g i i i i Apr94 May Jun Jul Aug Sep94 Facility Change ECNs Open 241 247 250
, 230 E Priority 1 or 2 150 - 66 .
. 8 Prionty 3 or 4 100 - 62.W.
50 O Priority 5 or 6 50- g w 0 g ; i i ; i Apr94 May Jun Jul Aug Sep94 Substitute Replacement item ECNs Open 250 - 4.6Y E Prionty 1 or 2 200 - -
,,188 181 182 188 - 8.8Y.
j Q Priority 3 or 4 66.6%
3 47 O Priority 5 or 6 100 - '
l 50 -
0-- 7- i ; ; i i Apr94 May Jun Jul Aug Sep94 Document Change ECNs Open ENGINEERING CHANGE NOTICES OPEN Data Source: Skiles/McShannon (Manager / Source)
Accountability: Skiles/Jaworski i Adverse Trend: None SEP 62 62
@ Administrative Control Problem O Licensed Operator Error
@ Other Personnel Error
@ Maintenance Problem 3- 3 Design / Construction / Installation / Fabrication Problem
@ Equipment Failures 2-1- -- -
g g 5 5
? ?
b E 5 5 5 0 , , ,' , , , ,
~
Sep93 Oct Nov Dec Jan Feb Mar Apr May Jun Jul Aug94 LICENSEE EVENT REPORT (LER) ROOT CAUSE BREAKDOWN This indicator shows the LERs by event date broken down by Root Cause Code for each of the past twelve months from September 1,1993 through August 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 descriptions of these codes, see the " Performance Indicator Definitions" section of this report.
There were no events in August 1994 that resulted in an LER.
Data Source: Trausch/Cavanaugh (Manager / Source)
Accountability: Chase Adverse Trend: None 63
l O Totai nequaiirication Training Hours O Simulator Training Hours !
O Non-Requalification Training Hours 50- E Number of Exam Failures 40- y 37 37 3 34
- 32 - -
1 x 30- -
20- 3 37
~
14 14 11 10- 5 6 3. I/,
4 ,,.
,e, 5 5 7 3 ,,
'/ g 3 /, 3 0
0 k ,
?',.
((g
, M, 0 k 1 M, )
Cycle 93-6* , Cycle 93-7 Cycle 94-1 Cycle 94-2 Cycle 94-3 Cycle 94-4 *, Cycle 94 5 '
' Note 1: The Simulator was out-of-service during Cycle 93-6 and Cycle 94-4.

~~Note 2: Includes 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months of General Employee Training.~~
LICENSED OPERATOR REQUALIFICATION TRAINING This indicator provides information on the total number of hours of training given to each crew during each cycle. The Simulator training hours shown on the graph are a subset of the total training hours. Non-Requalification Training Hours are used for AOP/EOP verification & validation, INPO commitments, GET, Fire Brigade, Safety Meetings, and Division Manager lunches.
Exam failures are defined as failures in the written, simulator, and Job Performance Measures (JPMs) segments of the Licensed Operator Requalification Training.
There was 1 crew simulator failure for Cycle 94-5. The crew that failed the simulator evaluation was remediated without impacting the Operations Department Shift Sched-ule.
Data Source: Gasper /Gyliani (Manage,r/ Source)
Accountability: Gasper /Guliani Adverse Trend: None SEP 68 64 1
O SRO Exams Administered l 0 SRO exams Passed l l
E RO Exams Administered O RO Exams Passed 20 -
15-10- 7
/
5-f 0 I I I i i i i i i i i i Oct93 Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep94 LICENSE CANDIDATE EXAMS This indicator shows the number of Senior Reactor Operator (SRO) and Reactor Opera-tor (RO) quizzes and exams taken and passed each month. These internally adminis-tered quizzes and exams are used to plot the SRO and RO candidates' monthly progress.
In September 1994 there were 10 SRO exams administered and 9 of these exams were passed. In addition, there were 19 RO exams administered and all 19 of the exams were passed.
i Data Source: Gaspor/Guliani(Managor/Sourco)
Accountability: Gasper /Guliani Adverse Trend: None SEP 68 65 l
1
O Total Open CARS B Total Open irs O Open CARS > six Months Old Q Open irs > Six Months Old 400- -400 360- _
- 360 320- Cycle 15 : : : : 320 280- f _ f 280 _
240- [ [ [ [ [ [ [ [ [ 240 200 - : : : : : : : : : 200
~
160- : : : : : : : : 160
~
120- } } }
~
}
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Oct93 Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep94 i
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 September 1994 there were 62 open CARS.11 of these CARS were greater than 6 months old. There were 6 Open Significant CARS at the end of the month.
Also, at the end of September there were 378 open irs. 200 of these irs were greater l than 6 months old. There were 72 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 Accountaoility: 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 completion of all corrective actions prior to closing irs.
_ ___ - . .- . .. _ _ _ _ _ - _ - _ _ _ _ _ _ . _ . _~
-+- Engineering Hold -+- Planning Complete
-O- Planning Hold --6(- Ready
--V- Part Hold --4-- Total 800 -
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DecS3Jan94 Feb Mar Apr May Jun Jul 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 1 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 engineenng 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 xpport 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 Adverse Trend: None SEP 31 67
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1995 OUTAGE MODIFICATIONS l l
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--+-- Baseline Schedule for PRC Approval g_ -- Projected / Actual Schedule for PRC Approval 7 Final Design Package issued
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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 September 1994 no modifications were deleted and 1 was 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
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1994 ON-LINE MODIFICATIONS a
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-*- Baseline Schedule for PRC Approval
-- Projected / Actual Schedule for PRC Approval Final Design Packa0e issued (7 FD DCPs issued prior to 1/14/94) y g20-Total Modification Packages (17) (2 are Close Out Only) (1 Added after 1/14/94)
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~~PROGRESS OF 1994 ON-LINE MODIFICATION PLANNING~~
! (FROZEN SCOPE OF 14 MODIFICATIONS)
This indicator shows the status of modifications approved for on-line installation during 1994. The data is represented with respect to the baseline schedule (established 1/14/
~~i. 94) and the current schedule. This information is taken from the Modification Variance i Report produced by the Design Engineering Nuclear group.~~
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i in September 1994 no modifications were deleted and none were added.
l The goal for this indicator is to have all modification packages identified prior to 1/14/94 l 1 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 a~~
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.
1 Data Source: Skiles/Ronne (Manager / Source)
Accountability: Phelps/Skiles Adverse Trend: None 70 j
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ACTION PLANS This section lists action plans that have been developed for the performance indicators cited as Adverse Trends during the month preceding this report. Also included are Action Plans for indicators that have been cited in the preceding month's report as Needing increased Management Attention for 3 consecutive months.
In accordance with Revision 3 of NOD-OP-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 Per 7,000 Critical Hours
. Unplanned Safety System Actuations (INPO and NRC)
The Plant Manager and Station Engineering Manager have reviewed the daily and ongoing actions being taken to return these performance indicators to meeting the goals. This review indicates appropriate action is being taken and no explicit action plan is required.
The action plan for Industrial Safety Accident Rate Sage 2) follows:
This performance indicator has shown crn.tinued improvement since May 1994. Management will continue to reinforce among employees the importance of safety in the workplace, and will take an active role in developing improved safety programs.
The action plan for Fuel Reliability Indicator (page 14) follows:
l
1) The prediction that there is a potential for 1 or 2 defective fuel rods in the core is based on a change in the Xe-133 to 1-131 ratio. A more definitive disposition will be possible when a significant power change is made and specific chemistry data can be collected.
~~2) A specification will be prepared for Ultrasonic Testing,if required, during the next refueling outage.~~
~~The action plan for Violations Per 1,000 Inspection Hours (page 18) follows:~~
1) The number of inspections (and thus exposure to potential violations) i currently scheduled for the remainder of the year is much less than the l first half of 1994 (SALP period ended 7/31/94). Only the SWOPI and Resident inspections are currently scheduled.
~~2) Pursuit of Resident Irispector concerns / problems / issues will be ;~~
thorough to preclude them from becoming violations. )
l 72
4-- - A y l . .
l l
ACTION PLANS (continued)
~~3) Preparation for scheduled inspections (e.g. SWOPI) will be thorough~~
, and comprehensive.
l 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 should be installed by the end of September.~~
~~3) Investigate the effects of adding Ethanolamine to secondary chemistry to clean system and possibly reduce S/G blowdown.~~
I i
1 73
PERFORMANCE INDICATOR DEFINITIONS AUXILIARY FEEDWATER SYSTEM SAFETY SYSTEM CENTS PER KILOWATT HOUR PERFORMANCE The purpose of this indicator is to quantify the economi-The sum of the known (planned and unplanned) unavail- cal operation of Fort Calhoun Station. The cents per able hours and the estimated unavailable hours for the kilowatt hour indicator represents the budget and actual auxiliary feedwater system tor the reporting period di- cents per kilowatt hour on a 12 month rolling average 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 feedwater approved 1993 budget. The basis for the actual curve is system. the Financial and Operating Report.
CHECK VALVE FAILURE RATE CLEAN CONTROLLED AREA CONTAMINATIONS Compares the Fort Calhoun check valve failure rate to 21,000 DIS 1NTEGRATIONS/ MINUTE PER PROBE i the industry check valve f ailure rate (failures per 1 million AREA '
component hours). The data for the industry failure rate The personnel contamination events in the clean con-is three months behind the PI Report reporting month. trolled area. This indicator tracks personnel perfor-This indcator tracks performance for SEP #43. mance for SEP #15 & 54.
COLLECTIVE RADIATION EXPOSURE CONTAMINATED RADIATION CONTROLLED AREA Collective radiation exposure is the total external whole- The percentage of the Radiation Controlled Area, which body dose received by all on-site personnel (includin9 includes the auxiliary building, the radwaste building, and contractors and visitors) during a time period, as mea- areas of the C/RP building, that is contaminated based sured by the thermoluminescent dosimeter (TLD). Col- on the total square footage. This indcator tracks perfor-lective radiation exposure is reported in units of person- mance for SEP # 54.
rem. This indicator tracks radiological work performance for SEP #54. DAILY THERMAL OUTPUT This indicator shows the daily core thermal output as COMPONENT FAILURE ANALYSIS REPORT (CFAR) measured from computer point XC105 (in thermal mega-
~~SUMMARY~~
watts). The 1500 MW Tech Spec limit, and the unmet The number of INPO categories for Fort Calhoun Station portion of the 1495 MW FCS daily goa! for the reporting with signdicantly higher (1.645 standard deviations) fail- month are also shown.
ure rates than the rest of the industry for an eighteen month time period. Failures are reported as component DIESEL GENERATOR RELIABILITY (25 DEMANDS)
(i.e. pumps, motors, valves, etc.) and applcation (i.e. This indicator shows the number of failures occurring for charging pumps, main steam stop valves, control ele- each emergency diesel generator during the last 25 start ment dnve motors, etc.) categories. demands and the last 25 load-run demands. !
Failure Cause Categories are:
Wear Out/ Aging - a failure thought to be the conse- DISABLING INJURY /lLLNESS FREQUENCY RATE quence of expected wear or aging. (LOST TIME ACCIDENT RATE)
Manuf acturing Defect - a f ailure attributable to inad- This indicator is defined as the number of acridents for equate assembly or initial quality of the responsible com- all utility personnel permanently assigned to the station, I ponent or system. involving days away from work per 200.000 man-hours EngineerinpDesign - a failure attributable to the inad- worked (100 man-years). This does not include contrac-equate design of the responsible component or system. tor personnel. This indicator tracks personnel perfor-Other Devces - a f ailure attributable to a f ailure or mance for SEP #25 & 26.
misoperation of another component or system, including associated devices. DOCUMENT REVIEW (BIENNIAL)
Maintenance / Testing - a f ailure that is a result of im- The Document Review Indicator shows the number of proper maintenance or testing, lack of maintenance, or documents reviewed, the number of documents sched-personnel errors that occur during maintenance or test- uled for review, and the number of document reviews ing activities performed on the responsible component or that are overdue for the reporting month. A document system, including f ailure to follow procedures. review is considered overdue if the review is not com-Errors - failures attributable to incx rrect procedures that plete within 6 months of the assigned due date. This were followed as written, improper installation of equip- indicator tracks performance for SEP #46.
ment, and personnel errors (including f ailure to follow procedures properly). Also included in this category are EMERGENCY AC POWER SYSTEM SAFETY SYSTEM failures for which the cause is unknown or cannot be as- PERFORMANCE signed to any of the preceding categories. The sum of the known (planned and unplanned) unavail-able and the estimated unavailable hours for the emer-gency AC power syctem for the remrting psriod divided by the number of hours in the reporting period multiplied by the number of trains in the emergency AC power sys-tem.
74 l l
I i
PERFORMANCE INDICATOR DEFINITIONS EMERGENCY DIESEL GENERATOR UNIT RELIABIL- EMERGENCY DIESEL GENERATOR UNRELIABILITY ITY This indicator measures the total unreliability of emer-This indicator shows the number of failures that were gency diesel generators. In general, unreliabihty is the reported during the last 20,50, and 100 emerger.:y die- ratio of unsuccessful operations (starts or load-runs) to sei generator demands at the Fort Calhoun Station. Also the number of valid demands. Total unreliability is a shown are trigger values which correlate to a high level combination of start unreliabihty and load-run of conf dance that a unit's diesel generators have ob- unreliability.
tained a reliability of greater than or equal to 95% when j the demand f ailures are less than the tngger values. ENGINEERING ASSISTANCE REQUEST (EAR) l
} 1) Number of Start Demands: All vald and inadvertent BREAKDOWN l start demands, including all start-only demands and all This indicator shows a breakdown, by age and priorrty of I
start demands that are followed by load-run demends. the EAR, of the number of EARS assigned to Design En-whether by automatic or manual initiation. A start-ordy gineering Nuclear and System Engineering. This indica-demand is a demand in which the emergency generator tor tracks periormance for SEP #62.
is started, but no attempt is made to load the generator.
2) Number of Start Failures: Any failure within the emer- ENGINEERING CHANGE NOTICE (ECN) STATUS gency generator system that prevents the generator from The number of ECNs that were apened, ECNs that were achieving specified frequency and voltage is classified as completed, and open backlog ECNs awaiting comp;ation a vald start failure. This includes any condition identified by DEN for the reporting month. This indcator tracks in the course of maintenance inspections (with the emer- performance for SEP 862.
~~gency generator in standby mode) that definitely would have resulted in a start failure if a demand had occurred. ENGINEERidG CHANGE NOTICES OPEN~~
3) Number of Wd-Run Demands: For a valid load-run This indicator breaks down the number of Engineering demand to t c wted the load-run attempt must meet Change Notices (ECNs) that are assigned to Design one or more cune following enteria: Engineering Nuclear (DEN), System Engineering, and A) A load-run of any duraton that results from a real au- Maintenance. The graphs provide data on ECN Facihty tomatic or manual initiaton. Changes open, ECN Substitute Replacement Parts B) A load-run test to satisfy the plant's load and duration open, and ECN Document Changes open. This indcator as stated in each test's specifications. tracks performance for SEP #62.
C) Other special tests in which the emergency generator is expected to be operated for at least one hour while EQUIPMENT FORCED OUTAGES PER 1,000 CRITI-loaded with at least 50% of its Casign 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 outages gency generator does not pick up toad and run as pre- caused by equipment failures. The mean time is equal dcted. Failuro are counted dunng any valid bad-run to the number of hours the reactor is enticalin a perod demands. (1000 hours0.0116 days 0.278 hours 0.00165 weeks 3.805e-4 months ) divided by the number of forced outages
~~5) Exceptions: Unsucx:essful attempts to start or load-run caused by equipment failures in that perod.~~
should not be counted as vahd demands or failures when l they can be attributed to any of the following: EQUIVALENT AVAILABILITY FACTOR A) Spurious inps that would be bypassed in the event of Tnts indicator is defined as the ratio of gross available !
i an emergency. generation to gross maximum generation, expressed as i
B) Malfuretion of equipment that is not required dun.n9 a percentage. Available generaton is the energy that an amergency. can be produced if the unit is operated at the maximum C)Intentionaltermination of a test because of abnormal power level permitted by equipment and regulatory limi-conditons that would not have resulted in major diesel tations. Maximum generation is the energy that can be generator damage or repair. produced by a unit in a given priod if operated continu-D) Malfunctions or operating errors which would have not ously at maximum capacrty.
prevented the emergency generator from being restarted and brought to load within a few minutes. FORCED OUTAGE RATE E) A f ailure 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 unft was unavailable due to forced events comparW cessf ul start with the starting system in its normal ahgn- to the time planned for electrical generation. Forcee ment. events are failures or other unplanned conditions that Each emergency generator f ai'ure that results in the gen- require removing the unit from service before the end of erator being declarsd inoperabie should be counted as the next weekend. Forced events include start-up fail-one demand and one failure. Exploratory tests dunn9 ures and events instiated while the unit is in reserve shut-corrc:tive maintenance and the sucx:essfultest that fol- down (i.e., the unit is available but not in service).
lows repair to venfy operabikty should not be counted as demands or f ailures when the EDG has not been de-clared operable again.
75 l l
PERFORMANCE INDICATOR DEFINITIONS FUEL REUABILITY INDICATOR UCENSE CANDIDATE EXAMS 4
This indicator is defined as the steady-state primary cool- This indicator shows the number of SRO and/or RO quiz-ant 1-131 activity, corrected for the tramp uranium contri- zes and exams that are administered and passed each bution and normalized to a common purifcc: ion rate. month. This indicator tracks training performance for Tramp uranium is fuel which has been deposited on re- SEP #68.
actor core internals from previous defective fuel or is present on the surface of fuel elements from the manu- LICENSED OPERATOR REQUALIFICATiON TRAIN-facturing process. Steady state is defined as mntinuous ING operation for at least three days at a power level that The total number of hours of training given to each crew does not vary more than + or - 5%. Plants should collect during each cycle. Also provided are the simulator train-data for this indicator at a power level above 85%, when ing hours (which are a subset of the total training hours),
1 possible. Plants that did not operate at steady-state the number of non-requalification training hours and the power above 85% should collect data for this indcator at number of exam failures. This indcator tracks training the highest steady state power level attained during the performance for SEP #68.
month.
. The density corredion f actor is the ratio of the specific LICENSEE EVENT REPORT (LER) ROOT CAUSE j volume of coolant at the RCS operating temperature BREAKDOWN 4
(540 degrees F., Vf . 0.02146) divided by the specific This indicator shows the number and root cause mde for volume of coolant at normal letdown temperature (120 Licensee Event Reports. The root cause codes are as degrees F at outlet of the letdown cooling heat ex- follows:
changer, Vf - 0.016204), which results in a density cor- 1) Administrative Control Problem - Management and rection f actor for FCS equal to 1.32. supervisory deficiencies that affect plant programs or activities (i.e., poor planning, breakdown or lack of ad-GROSS HEAT RATE equate managernent or supervisory control, incorrect Gross heat rate is defined as the ratio of total thermal procedures, etc.)
energy in Bntish Thermal Units (BTU) produced by the 2) Licensed Operator Error - This cause code captures reactor to the total gross electrical energy produced by errors of omission / commission by licensed reactor opera-the generator in kilowatt-hours (KWH). tors during plant activities.
, 3) Other Personnel Error - Errors of omission /commis-HAZARDOUS WASTE PRODUCED sion committed by non-lconsed personnel involved in The total amount (in Kilograms) of non-halogenated haz- plant activities.
wious waste, halogenated hazardous waste, and other 4) Maintenance Problem - The intent of this cause hazardous waste produced by FCS each rnonth. code is to capture the full range of problems which can j be attributed in any way to programmatic deficiencies in HIGH PRESSURE SAFETY INJECTION SYSTEM the maintenance functional organization. Activities in-SAFETY SYSTEM PERFORMANCE cluded in this category are maintenance, testing, surveil-The sum of the known (planned and unplanned) unavail- lance, calibration and radiation protection, able hours and the estimated unavailable hours for the 5) Design / Construction / Installation / Fabrication Problem high pressure safety injection system for the reporting - This cause code covers a full range of programmatic period divided by the entical hours for the reporting pe- deficiencies in the areas of design, construction, installa-4
^
fiod multiplied by the number of trains in the high pres- tion, and f abrication (i.e., loss of control power due to sure safety injection system. underrated fuse, equipment not qualified for the environ-ment, etc.).
INDUSTRIAL SAFETY ACCIDENT RATE - INPO 6) Equipment Failures (Electronic Piece-Parts or Envi-This indicator is defined as the number of accidents per ronmental-Related Failures) - This code is used for spuri-200,000 man-hours worked for all utility personnel per- ous failures of electronic piece-parts and failures due to manently assigned to the station that result in any of the meteorological conditions sur,h as lightning, ice, high following: 1) one or more days of restrcted work (ex- winds, etc. Generally, it includes spunous or one-time ciuding the day of the accident); 2) one os more days failures. Electric components included in this category away from work (excluding the day of the accident); and are circuit cards, rectifiers, bistables, fuses, capacitors,
~~3) f atalities. Contractor personnel are not included for diodes, resistors, etc.~~
this indcator.
LOGGABLE/ REPORTABLE INCIDENTS (SECURITY)
IN-LINE CHEMISTRY INSTRUMENTS OUT OF SER- The total number of security incidents for the reporting VICE month depicted in two graphs. This indicator tracks so-Total number of in-hne chemistry instruments that are cunty performance for SEP #58.
out-of-service in the Secondary System and the Post Accident Sampling System (PASS). MAINTENANCE OVERTIME The % of overtime hours compared to normal hours for maintenance. This includes OPPD persor. net as well as contract personnel.
76
i PERFORMANCE INDICATOR DEFINITIONS l MAINTENANCE WORKLOAD BACKLOGS NUMBER OF CONTROL ROOM EQUIPMENT DEFi-This indicator shows the backlog of non-outage Mainte- CIENCIES l nance Work Orders remaining open at the end of the A control room equipment deficiency (CRD)is defined as reporting month. Maintenance classifications are de- any component which is operated or controlled from the i fined as: Control Room, provides indication or alarm to the Control Room, provides testing capabilities from the Control Corrective Repair and restoration of equipment or com- Room, provides automatic actions from or to the Control ponents that have f ailed or are malf unctioning and are Room, or provides a passive function for the Control not performing their intended function. Room and has been identified as deficient, i.e., does not perform under all conditions as designed. This definition Preventive - Adions taken to maintain a piece of equip- also applies to the Alternate Shutdown Panels Al-179, ment within design operating conditions, prevent equip. Al-185, and Al-212.
ment failure, and extend its Ide and are performed prior A plant component which is deficient or inoperable is to equipment failure. considered an " Operator Work Around (OWA) ltem* if some other action is required by r.n operator to compen-Non-Corrective / Plant Improvements - Maintenance ac. Sate for the condition of the component. Some examples tivities performed to implement statios 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-tor out in the plant; 2) A deficient pump cannot be re-Maintenance Work Prionties are defined as: paired because replacement parts require a long lead time for purchase / delivery, thus requiring the redundant Emergency - Conditions which significantly degrade sta- pump to be operated continuously; 3) Special actions ton safety or availability. are required by an Operator because of equipment de-sign problems. These actions may be described in Op-Immediate Adon - Equipment def ciencies which signifi. erations Memorandums Operator Notes, or may require cantly degrade station reliabiltty. Potential for unit shut- changes to Operating Procedures. 4) Deficient plant down or power reduction. equipment that is required to be used during Emergency Operating Procedures c,r Abnormal Operating Proco- i
. Operatons Concern - Equipment deficiencies which dures. 5) System indication that provides entical infor.
hinder staton operation. mation during normal or abnormal operations.
Essential - Routine mrrectNe maintenance on essantial NUMBER OF MISSED SURVEILLANCE TESTS RE-station systems and equipment. SULTING IN LICENSEE EVENT REPORTS The number of Surveillance Tests (STs) that result in Non-Essential- Routine corrective maintenance on non. Licensee Event Reports (LERs) during the reporting essential station systems and equipment. month. This indicator tracks missed STs for SEP #60 &
61, Plant improvement - Non-corrective maintenance and plant improvements. OFEN CORRECTIVE ACTION REPORTS & INCIDENT REPORTS This indicator tracks maintenance performance for SEP This indicator displays the total number of open Correc-
36. tive Action Reports (CARS), the number of CARS that are older than six months and the number of open significant MAXIMUM INDIVIDUAL RAD (ATION EXPOSURE CARS. Also displayed are the number of open incident The total maximum amount of radiation received by an Reports (irs), the number of irs that are greater than six individual person working at FCS on a monthly, quarterly, months old and the number of open signifcant irs.
and annual basis.
OUTSTANDING MODIFICATIONS i MWO PLANNING ST ATUS (CYCLE 16 REFUELING The number of Modification Re, quests (MRs)in any state I l
OUTAGE) between the issuance of a Modificaton Number and the The total number of Maintenance Work Orders that have completson of the drawing update.
been approved for inclusion in the Cycle 15 Refueling 1) Form FC-1133 Backlog /In Progress. This number rep-Outage and the number that are ready to work (parts resents modification requests that have not been plant staged, planning mmplete, and all other paperwork approved during the reporting month, ready for field use). Also included is the number of 2) Modification Requests Being Reviewed. This category MWOs that have engineering holds (ECNs, procedures includes:
and other miscellaneous engineering holds), parts hold, A.) Moddcation Requests that are not yet reviewed.
(parts staged, not yet inspected, parts not yet arrived) B.) Modification Requests being reviewed by the Nuclear and planning hold (job scope not yet completed). Main- Projeds Review Committee (NPRC).
tenance Work Requests (MWRs) are also shown that C.) Modification Requests being reviewed by the Nuclear have been identified for the Cycle 15 Refueling Outage Projects Committee (NPC) and have not yet been converted to MWOs. These Modificaton Requests may be reviewed several times before they are approved for accomplishment or 77
PERFORMANCE INDICATOR DEFINITIONS cancelled. Some of these Modification Requests are years of the " Event Date* specified in the LER (e.g., an returned to Engineering for more information, some ap- event for which the cause is attributed to a problem with
~~proved for evaluation, some approved for study, and the orginal design of the plant would not be mnsidered sorr.e approved for planning. Once planning is com- preventable).~~
~~pleted and the scope of the work is clearly defined, these For purposes of LER event classifcaton, a " Personnel Modifcation Requests may be approved for accomplish- Error~~
LER is defined as follows: An event for which the ment with a year assigned for construction or they may root cause is inappropriate action on the part of one or be cancelled. All of these different phases require re- more individuals (as opposed to being attributed to a de-view. partment or a general group). Also, the inappropriate ~
~~3) Design Engineering Backlog /in Progress. Nuclear action must havo occurred within approximately two Planning has assigned a year in which construction will years of the~~
~~Event Date" specified in the LER.~~
~~be completed and design work may be in progress. Additionally, each event classified as a~~
Personnel Error *
4) Construction Backlog /In Progress. The Construction should also be classified as " Preventable." This indicator Package has been issued or construction has begun but trends personnel performance for SEP ftem #15.
~~the rnodification has not been accepted by the System Acceptance Committee (SAC). PRIMARY SYSTEM CHEMISTRY % OF HOURS OUT~~
~~5) Design Engineering Update Backlog /in Prograss. PED OF UMIT has received the Moddication Completon Report but the The % of hours out of limit are for six primary chemistry i~~
drawings have not been updated, parameters divided by the total number of hours possible l The above mentoned outstanding modificatons do not for the month. The key parameters used are: Lithium, I include modificatons which are proposed for cancella- Chloride, Hydrogen, Dissolved Oxygen, Fluoride and tion. Suspended Solids. EPRIlimits are used.
l OVERALL PROJECT STATUS (REFUELING OUTAGE) PROCEDURAL NONCOMPLIANCE INCIDENTS l This indicator shows the status of the projects which are (MAINTENANCE)
~~in the scope of the Refueling Outage. The number of identified incidents concerning mainte-~~
! nance procedural problems, the numoer of closed irs l PERCENTAGE OF TOTAL MWOs COMPLETED PER related to the use of procedures (includes the number of MONTH IDENT3FIED AS REWORK closed irs caused by procedural noncompliance), and The percentago of total MWOs completed per month the number of closed procedural noncompliance irs.
identified as revork. Rework activities are identified by This indicator trends personnel performance for SEP maintenance phnning and craft. Rework is: Any main- #15,41 & 44.
tenance work irepeated to correct a defciency which has re-omurred within 60 days following similar work activi- PROGRESS OF CYCLE 16 OUTAGE MODIFICATION ties. Any additional work required to correct defciencies PLANNING (FROZEN SCOPE OF 15 MODIFICA-discovered during a failed Post Maintenance Test to on- T10NS) sure the component / system passes subsequent Post This indicator shows the status of modifcations ap-Maintenance Tests. This definition can be found in S. O. proved for completion during the Refueling Outage.
M-101.
PROGRESS OF 1994 ON-LINE MODIFICATION PLAN-PERCENT OF COMPLETED SCHEDULED MAINTE- NING (FROZEN SCOPE OF 14 MODIFICATIONS)
NANCE A0TIVITIES This indcator shows the status of modificatons ap-The % of the number of completed maintenance activi- proved for completion dunng 1994.
ties as compared to the number of scheduled mainte-nance activr!ies each month. This % is shown for all RADIOLOGICAL WORK PRACTICES PROGRAM maintenance crafts. Also shown are the number of The number of identified poor radiological work practices emergent MWOs. Maintenance activities include MWRs, (PRWPs) for the reporting month. This indicator tracks MWOs, STs, PMOs, calibrations, and other miscella- radiological work performance for SEP #52.
neous activities. This indcator tracks Maintenance per-formance for SEP #33. RATIO OF PREVENTIVE TO TOTAL MAINTENANCE &
PREVENTIVE MAINTENANCE ITEMS OVERDUE PREVENTABLE / PERSONNEL ERROR LERs The ratio of preventive maintenance (including surveil-This indicator is a breakdown of LERs. For purposes of lance testing and calibration procedures) to the sum of LER event classification, a preventable LER is defined non-outage corrective maintenance and preventive main-as: An event for which the root cause is personnel error tanance completed over the reporting period. The ratio, (i.e., inappropriate acton by one or more individuals), expressed as a percentage, is calculated based on man-inadequate administrative controls, a design /construc- hours. Also displayed are the % of preventive mainte-tion /installaton/f abrication problem (involving work com- nance items in the month that were not completed or ad-pleted 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 perod 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
l 4 9 PERFORMANCE INDICATOR DEFINITIONS RECORDABLE INJURY /lLLNESS CASES FRE- SIGNIFICANT EVENTS QUENCY RATE Significant events are those events identified by NRC The number of injuries requiring more than normal first staff through detailed screening and evaluation of operat-aid per 200,000 man-hours worked. This indicator ing experience. The screening process includes the trends personnel performance for SEP #15,25 & 26. daily review and discussion of all reported operating re-actor events, as well as other operational data such as REPEAT FAILURES special tests or construction actrvities. An event identi-The number of Nuclear Plant Reliabihty Data System 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 f ailures or potential threat to the health and safety of the public for the last eighteen months. was involved. Specific examples of the type of crneria are summarized as follows: 1) Degradaten of important SAFETY SYSTEM FAILURES safety equipment; 2) Unexpected plant response to a Safety system failures are any events or conditons that transient; 3) Degradation of fuelintegray, primary mol-could prevent the fulfillment of the safety functions of ant pressure boundary, important associated features; structures or systems.1; a cystem consists of multple 4) Scram with complication: 5) Unplanned release of redundant subsystems or trains, failure of all trains con. radioactivity; 6) Operaton outside the limits of the Tech-sinutes a safety system failure. Failure of one of two or nical Specifications; 7) Other.
more trains is not counted as a safety system failure. INPO signifcant events reported in this indicator are The definition for the indicator parallels NRC reporting SERs (Significant Event Reports) which inform utilities of requirements in 10 CFR 50.72 and 10 CFR 50.73. The significant events and lessons learned identified through following is a list of the major safety systems, sub- the SEE IN screening process.
systems, and components monitored for this indicator:
Accident Monitoring instrumentation, Auxiliary (and SPARE PARTS INVENTORY VALUE Emergency) Feedwater System, Combustible Gas Con- The dollar value of the spare parts inventory value for trol, Component Cooling Water System, Containment FCS during the reporting perod.
and Containment isolation, Containment Coolant Sys-tems, Control Room Emergency Ventilation System, STAFFING LEVEL Emergency Core Cooling Systems, Engineered Safety The actual staffing level and the authorized staffing level Features Instrumentation, Essential Compressed Air for the Nuclear Operations Division, the Production Engi-Systems, Essential or Emergency Service Water, Fire neering Division, and the Nuclear Services Division. This Detection or Suppression Systems, Isolation Condenser, indicator tracks performance for SEP #24.
Low Temperature Overpressure Protection, Main Steam Line Isolaton Valves, Onsite Emergency AC & DC STATION NET GENERATION Power w! Distribution, Radiation Monitoring instrumenta. The net generation (sum) produced by the FCS during ton, Reactor Coolant System, Reactor Core isolation the reporting month.
Cooling System Reactor Trp System and Instrumenta-tion, Recirculaton Pump Trip Actuation instrumentation. TEMPORARY MODIFICATIONS Residual Heat Removal Systems, Safety Valves, Spent The number of temporary mechanical and electrical con-Fuel Systems, Standby Liquid Control System and Ulti- figurations to the plant's systems, mate Heat Sink. 1) Temporary configurations are defired as electrical jumpers, electrical blocks, mechanical jumpers, or me-SECONDARY SYSTEM CHEMISTRY PERFORMANCE chanical blocks which are installed in the plant operating INDEX systems and are not shown on the latest revision of the The Chemistry Performance index (CPI) is a calculation P&lD, schemate, connection, wiring, or flow diagrams.
based on 1:.0 concentration of key impunties in the sec- 2) Jumpers and blocks which are installed for Surveil-ondary side of the plant. These key impurities are the lance Tests, Maintenance Procedures, Calibration Pro-most likely cause of deterioraton of the steam genera- cedures, Special Procedures, or Operating Procedures tors. Criteria for calculating the CPI are: 1) The plant is are not considered as temporary modrfications unless the at greater than 30 percent power; and 2) The power is jumper or block remains in place after the test or proce-changing less than 5% per day. The CPIis calculated dure is complete. Jumpers and blocks installed in test or using the following equation: CPI - (sodium /0.90) + lab instruments are not considered as temporary modifi-(Chloride /1.70) + (Suttate/1.90) + (Iron /4.40) + (Copper / cations.
0.30)/5. Where: Sodium, sulf ate and chloride are the 3) Scaffolding is not considered a temporary modifica-monthly average blowdown concentrations in ppb, iron ton. Jumpers and blocks which are installed and for and copper are monthly time weighted average which MRs have been submitted will be considered as feedwater concentrations in ppb. Tha denominator for temporary modifcations until final resolution of the MR each of the 5 f actors is the INPO median value, if the and the jumper or block is removed or is permanently monthly average for a specific parameter is less than the recorded on the drawings. This indcator tracks tempo-INPO median value, the median value is used in the cal- rary modifications for SEP #62 & 71.
culation.
79
l PERFORMANCE INDICATOR DEFINITIONS
(
j THERMAL PERFORMANCE UNPLANNED SAFETY SYSTEM ACTUATIONS-(INPO The ratio of the design gross heat rate (wrrected) to the DEFINITION)
' adjusted actual gross heat rate, expressed as a percent- This indicator is defined as the sum of the following safety age. system actuations:
1) The number of unplanned Emergency Core Cooling UNIT CAPABILITY FACTOR System (ECCS) actuations that result from reaching an The ratio of the available energy generation over a given ECCS actuation setpoint or from a spurious / inadvertent time period to the reference energy generation (the on- ECCS signal.
ergy that could be produced if the unit were operated 2) The number of unplanned emergency AC power system continuously at full power under reference ambient con- actuations that result from a loss of power to a safeguards ditions) over the same time period, expressed as a per- bus. An unplanned safety system actuation occurs when contage. an actuation setpoint for a safety system is reached or when a spurious or inadvertent signalis generated (ECCS UNIT CAPACITY FACTOR only), and major equipment in the system is actuated.
The not electrical energy generated (MWH) divided by Unplanned means that the system actuation was not part the product of maximum dependable capacity (not MWe) of a planned test or evolution. The ECCS actuations to be times the gross hours in the reporting period expressed counted are actuations of the high pressure injection sys-as a percent. Net electrical energy generated is the tem, the low pressure injection system, or the safety injec-gross electrical output of the unit measured at the output tion tanks.
terminals of the turbine generator minus the normal sta-tion service loads during the gross hours of the reporting UNPLANNED SAFETY SYSTEM ACTUATIONS(NRC period, expressed in megawatt hours. DEFINIDON)
The number of safety system actuations which include UNPLANNED AUTOMATIC REACTOR SCRAMS PER (g&) the High Pressure Safety injection System, the Low 7,000 CRITICAL HOURS Pressure Safety injedion System, the Safety injection This indicator is defined as the number of unplanned au- Tanks, and the Emergency Diesel Generators. The NRC tomatic scra.1s (reactor protection system logic actua- classification of safety system actuations includes actua-tions) that occur per 7,000 hours0 days 0 hours 0 weeks 0 months of critical operation. tions when major equipment is operated Aad when the The value for this indicator is calculated by multiplying logic systems for the above safety systems are chal-the total number of unplanned automatic reactor scrams lenged.
in a specific time period by 7,000 hours0 days 0 hours 0 weeks 0 months , then dividing that number by the total number of hours entical in the VIOLATIONS PER 1,000 INSPECTION HOURS same time period. The indicator is further defined as This indicator is defined as the number of violations sited follows: in NRC inspection reports for FCS per 1,000 NRC inspec-
~~1) Unplanned means that the scram was not an antici- tion hours. The violations are reported in the year that the l~~
pated part of a planned test. inspection was actually performed and not based on when l 2) Scram means the automatic shutdown of the reactor the inspection report is received. The hours reported for by a rapid insertion of negative reactivity (e.g., by control each inspection report are used as the inspection hours.
rods, liquid injection system, etc.) that is caused by ac-tuation of the reactor protection system. The scram sig- VOLUME OF LOW-LEVEL SOLID RADIOACTIVE
, nal may have resulted from exceeding a setpoint or may WASTE l have been spurious. This indicator is defined as the volume of low-level solid
, 3) Automatic means that the initial signal that caused radioactive waste actually shipped for burial. This indica-l actuation of the reactor protection system logic was pro- tor also shows the volume of low-level radioactive waste vided from one of the sensors monitoring plant param- which is in temporary storage, the amount of radioactive l
! eters and cranditions, rather than the manual scram oil that has been shipped off-site for processing, and the switches or, in manual turbine trip switches (or push-but- volume of solid dry radioactive waste which has been tons) provided in the main control room. shipped off-site for processing. Low-level solid radioactive
4) Cntical means that during the steady-state condition of waste consists of dry active waste, sludges, resins, and l the reactor prior to the scram, the effective multiplication evaporator bottoms generated as a result of nuclear power l factor (k,) was essentia'ly equal to one. plant operation and maintenance. Dry radioactive waste includes contaminated rags, cleaning materials, dispos-UNPLANNED CAPABlUTY LOSS FACTOR able protective clothing, plastic containers, and any other The ratio of the unplanned energy losses during a given material to be disposed of at a low-level radioactive waste period of time, to the reference energy generation (the disposal site, except resin, sludge, or evaporator bottoms.
, energy that could be produced if the unit were operated Low-level refers to all radioactive waste that is not spent I continuously at full power under reference ambient con- fuel or a by-product of spent fuel processing. This indica-drtions) over the same time period, expressed as a per- tor tracks radiological work performance for SEP #54.
centage.
80 l
l SAFETY ENHANCEMENT PROGRAM INDEX The purpose of the Safety Enhancement Program (SEP) Performance Indicators Index is to list perfor-mance indicators related to SEP items with parameters that can be trended.
SEP Reference Number 15 EAQ11 Increase HPES and IR Accountability Through Use of Performance Indicators ,
Procedural Noncompliance incidents (Maintenance) . .. .. . .. . 50 l Clean Controlled Area Contaminations 21,000 Disintegrations / Minute Per Probe Area.. .5 i Recordable injury / illness Cases Frequency Rate . . . .4 l Preventable / Personnel Error LERs . . . .6 ]
SEP Reference Number 24 Complete Staff Studies Staffing Level . . . . . 43 SEP Reference Number 25 Training Program for Managers and Supervisors implemented Disabling injury / Illness Frequency Rate . .3 Recordable injury / Illness Cases Frequency Rate . . . .4 :
SEP Reference Number 28 Evaluate and implement Station Standards for Safe Work Practice Requirements Disabling injury / illness Frequency Rate .. .3 Recordable injury /lliness Cases Frequency Rate . . .4 SEP Reference Number 27 Implement Supervisory Enforcement of Industrial Safety Standards Disabling injury /lliness Frequency Rate . . . . .3 Recordable injury / Illness Cases Frequency Rate . . . . .4 SEP Reference Number 31 Develop Outage and Maintenance Planning Manual and Conduct Project Management Training MWO Planning Status (Cycle 16 Refueling Outage). . . 67 Overall Project Status (Cycle 16 Refueling Outage) . . . 68 Progress of Cycle 16 Outage Modification Planning . . . . 69 SEP Reference Number 33 Develop On-Line Maintenance and Modification Schedule Percent of Completed Scheduled Maintenance Activities (All Maintenance Crafts) . . 51 SEP Reference Number 36 l Reduce Corrective Non-Outage Backlog Maintenance Workload Backlogs (Corrective Non-Outage). . . .46 SEP Reference Number 41 Develop and implement a Preventive Maintenance Schedule Ratio of Preventive to Total Maintenance & Preventive Maintenance items Overdue. .47 Procedural Noncompliance incidents. . 50 SEP Reference Number 43 Implement the Check Valve Test Program Check Valve Failure Rate. . .37 l
l 81
l I
SAFETY ENHANCEMENT PROGRAM INDEX (continurd)
SEP Reference Number 44 EaQA Compliance With and Use of Procedures Procedural Noncompliance Incidents (Maintenance) . . 50 SEP Reference Number 46 Design a Procedures Control and Administrative Program Document Review . . . . . . .. . 56 SEP Reference Number 52 Establish Supervisory Accountability for Workers Radiological Practices Radiological Work Practices Program . . . .. . . . 55 l
SEP Reference Number 54 '
Cornplete implementation of Radiological Enhancement Program
, Collective Radiation Exposure . . . . . . . . . 16 i l Volume of Low-Level Solid Radioactive Waste. ... .. . .38 l Clean Controlled Area Disintegrations 21,000 Counts / Minute Per Probe Area . . .. . ..5 Contaminated Radiation Controlled Area. . . . . . 54 l
SEP Reference Number 58 Revise Physical Security Training and Procedure Program l Loggable/ Reportable incidents (Security) . .. . . 57 SEP Reference Number 60 Improve Controls Over Surveillence Test Program Number of Missed Surveillance Tests Resulting in Licensee Event Reports. . 20 SEP Reference Number 61 Modify Computer Program to Correctly Schedule Surveillance Tests Number of Missed Surveillance Tests Resulting in Licensee Event Reports. . . 20 SEP Reference Number 62 Establish Interim System Engineers Temporary Modifications . . . .. . . 58 Engineering Assistance Request (EAR) Breakdown.. . . . . 60 Engineering Change Notice Status . . . . . . . 61 Engineering Change Notices Open. .. . . . 62 SfP Reference Number 68 Assess Root Cause of Poor Operator Training and Establish Means to Monitor Operator Training Licensed Operator Requalification Training . . 64 License Candidate Exams.. . . . . 65 i
SEP Reference Number 71 Improve Controls over Temporary Modifications Temporary Modtfications . . . . 58 82
l l . .
REPORT DISTRIBUTION LIST R. L. Andrews L T. Kusek G. L. Anglehart M. P. Lazar K. L Belek B. R. Livingston B. H. Biome D. L. Lovett C. E. Boughter J. H. MacKinnon >
C. J. Brunnert J. W. Marcil G. R. Cavanaugh N. L. Marfice J. W. Chase R. D. Martin A. G. Christensen T. J. Mcivor O. J. Clayton K. G. Melstad R. P. Clemens K. A. Miller R. G. Conner P. A. Mruz J. L. Connolley Nuclear Licensing G. M. Cook & Industry Affairs S. R. Crites J. T. O'Connor D. W. Dale W. W. Orr -
D. C. Dietz T. L. Patterson M. L. Ellis R. T. Pearce H. J. Faulhaber R. L. Phelps M. T. Frans W. J. Ponec D. P. Galle C. R. Rice S. K. Garnbhir A. W. Richard J. K. Gasper D. G. Ried W. G. Gates G. K. Samide S. W. Gebers M. J. Sandhoefner L V. Goldberg F. C. Scofield D. J. Golden H. J. Sefick R. H. Guy J. W. Shannon
}
A. L Hale C. F. Simmons l
' J. B. Herman E.L.Skaggs T. L. Herman J. L. Skiles K. C. Holthaus F. K. Smith
L. P. Hopkins R. L Sorenson C.K. Huang K. E. Steele T. W. Jamieson M. A.Tesar R. L. Jaworski J. J. Tesarek R.A.Johansen J. W. Tills J. W. Johnson D. R. Trausch '
W. C. Jones J. M. Waszak l
' J. D. Keppler G. R. Williams D. D. Kloock S. J. Willrett l
I l
i 83 l
" - FORT CALHOUN 8TATION OPERATING CYCLES AND REFUELING OUTAGE DATES Event Date Ran0s Production (MWH) Cumulative (MWH)
Cycle 1 09/26/73 -02/01/75- 3,299,630 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/'7 . 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 Refuellag 10/14/78-12/24/78 Cycle 5 12/24/78 - 01/18/80 3,882,734 16,868,454 5th Refueling 01/18/80 - 06/11/80 Cycle 6 06/11/80 - 09/18/81 3,899,714 20,768,168 6th Refueling 09/18/81 -12/21/81 Cycle 7 12/21/81 -12/06/82 3,561,866 24,330,034 7th Refueling 12/06/82 - 04/07/83 i Cycle 8 04/07/83 - 03/03/84 3,406,371 27,736,405 i 8th Refue8ng 03/03/84 - 07/12/84 l
Cycle 9 07/12/84 - 09/28/85 4,741,488 32,477,893 'l 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
~~i Cycle 11 06/08/87 - 09/27/88 4,936,859 41,771,505 11th Refueling 09/27/88 - 01/31/89~~
~~Cycle 12 01/31/89 - 02/17/90 3,817,954 45,589,459 12th Refueling 02/17/90 - 05/29/90~~
Cycle 13 05/29/90 - 02/01/92 5,451,069 51,040,528 13th Refueling 02/01/92 - 05/03/92 Cycle 14 06/03/92 09/25/93 4,981,485 56,022,013 14th Refueling 09/25/93 -11/26/93 Cycle 15 11/26/93 - 03/11/95 15th Refueling 03/11/95 - 04/29/95 (Planned Dates)
FORT CALHOUN STATION CURRENT PRODUCTION AND OPERATIONS " RECORDS" First Sustained Reaction August 5,1973 (5:47 p.m.)
First Electricity Supplied to the System August 25,'1973 Commercial Operation (180,000 KWH) September 26,1973 Achieved Full Power (100%) May 4,1974 Longest Run (477 days) June 8,1987-Sept. 27,1988 Highest Monthly Not Generation (364,468,800 KWH) October 1987 Most Productive Fuel Cycle (5,451,069 MWH)(Cycle 13) May 29,1990 Feb.1,1992
." - FORT CALHOUN STATION OPERATING CYCLES AND REFUELING OUTAGE DATES i Event Date Range Production (MWH) Cumulative (MWH) l Cycle 1 09/26/73 -02/01/75 3,299,639 3,299,639 1st Refueling 02/01U5 -05/09/75 Cycle 2 05/09/75 -10/01n6 3,853,322 7,152,961 2nd Refueling 10/01/76-12/1376 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 10/14778 -12/24/78 Cycle 5 12/24/78 - 01/18/80 3,882,734 16,868,454 5th Refueling 01/18/80- 06/11/80 Cycle 6 06/11/80 - 09/18/81 3,899,714 20,768,168 ,
6th Refueling 09/18/81 -12/21/81 1 1
Cycle 7 12/21/81 -12/06/82 3,561,866 24,330,034 7th Refueling 12/06/82 04/07/83 l l
Cycle 8 04/07/83 03/03/84 3,406,371 27,736,405 l 8th Refueling 03/03/84 - 07/12/84 Cycle 9 07/12/84 09/28/85 4,741,488 32,477,893 l 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 11th Refueling 09/27/88 01/31/89 *
Cycle 12 01/31/89 - 02/17/90 3,817,954 45,589,459 12th Refueling 02/17/90 - 05/29/90 *
Cycle 13 05/29/90 - 02/01/92 5,451,069 51,040,528 13th Refueling 02/01/92- 05/03/92 *
Cycle 14 05/03/92 -09/25/93 4,981,485 56,022,013 14th Refueling 09/25/93 -11/26/93 *
~~Cycle 15 11/26/93 - 03/11/95~~
~~15th Refueling 03/11/95 04/29/95 (Planned Dates)~~
FORT CALHOUN STATION CURRENT PRODUCTK)N AND OPERATIONS " RECORDS" First Sustained Reaction August 5,1973 (5:47 p.m.)
First Electricity Supplied to the System August 25,1973 Commercial Operation (180,000 KWH) September 26,1973 Achieved Full Power (100%) May 4,1974 Longest Run (477 days) June 8,1987-Sept. 27,1988 Highest Monthly Not Generation (364,468,800 KWH) October 1987 Most Productive Fuel Cycle (5,451,069 MWH)(Cycle 13) May 29,1990-Feb.1,1992
- _ _ . _ , - . _ . _, ___ _ _ . _ _ _ _ _ _ - _

ML20076J723

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