ML20091L100

Performance Indicators Jul 1995

ML20091L100
Person / Time
Site:	Fort Calhoun
Issue date:	07/31/1995
From:	OMAHA PUBLIC POWER DISTRICT
To:
Shared Package
ML20091L098	List: LIC-95-0161, Forwards Fort Calhoun Station Performance Indicators Jul 1995 ML20091L100
References
NUDOCS 9508280301
Download: ML20091L100 (99)

Text

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l OMAHA PUBLIC POWER DISTRICT FORT CALHOUN STATION 1

PERFORMANCE INDICATORS REPORT

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Prepared By:

l Production Engineering Division System Engineering l

Test and Perfom1ance Group i

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JULY 1995 I'

FORT CALHOUN STATION JULY 1995 MONTHLY OPERATING REPORT OPERATIONS

SUMMARY

During the month of July, FCS operated at a nominal 100% power. Normal plant maintenance, surveillance, and equipment rotation activities were performed during the month, in addition to scheduled on-line modification activities. During the mid-July record-setting peak demand period, additional precautions were taken to ensure station availability by postponing non-essential maintenance and testing activities on some plant systems. Modifications for the Diesel Generator No. 2 Starting Air and for the Control Room Ventilation Units VA-46A and VA-46B were completed.

Emergency Diesel Generator (EDG) hot-weather testing was completed on both diesel generators. The EDG hot-weather testing, performed after ambient temperatures reached 95'F, confirmed diesel generator operability at higher temperatures than previously allowed.

j To assist in meeting the FCS as-low-as-reasonably-achievable (ALARA) radiation exposure goals, a hot spot (1 Rem /hr) was removed from one of the liquid waste tanks.

The general radiation levels in the area were reduced to normal values (5-20 mrem /hr).

On July 28, during monthly surveillance testing, problems with the turbine-driven auxiliary feedwater pump FW-10 inlet valve YCV-1045 and throttle valve MS-361 resulted in unexpected pump operating characteristics.

Pump operability was verified through evaluation. Administrative controls are in place to prevent recurrence until a long-term solution can be implemented during the next available cold shutdown.

The NRC Resident Monthly inspection, inspection No. 95-09, was completed during this 4

reporting period.

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FORT CALHOUN STATION PERFORMANCE INDICATORS REPORT JULY 1995 -

SUMMARY

POSITIVE TREND REPORT POSITIVE TREND REPORT (continued)

A performance indicator with data representing three

% of Total MWOs Comoleted per month identiQgLgg consecuWe months of improving performance or three rework consecuWe months of performance that is superior to the (Page 48) stated goal is exhibiting a pookve trend per Nuclear Operselons DMeion Qualty Procedure 37 (NOD-QP-37).

Hazardous Waste Produced The fokwng performance indicators exhabited poestive trends for the reporting month:

Contaminated Radiation ControNed Area (Page 54)

Safetv System Falures (Page 7)

End of Positive Trend Report Hiah Pressure Safety inlection System Safety Sygign Performance ADVERSE TREND REPORT (Page 8)

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' * ***" "O Emeroency AC Power System Safetv System consecutive months of declining performance or three Performance consecutive months of performance that is trending (Page 10) toward dedrung as determined by the Manager - Station Engineering, constitutes an adverse trend por Nuclear Emeroency Diesel Generator Unit Reliabdity Operations DMaion Quality Procedure 37 (NOD-QP-37).

(Page 11)

A supervisor whose performance indicator exhibits an "I

• Diesel Generator Reliability (25 Demands)

(to be pubirshed in this report) why the trend as not (Page 12) adverse.

Emeroency Diesel Generator Unreliability The foRowing performance indicators exhibited adverse (Page 13) trends for the reporting month:

4 Sen#ficant Events Maintenance Workload Backloos (Page 20)

(Page 46)

Missed SurveiRance Tests Results in Licensee Event End of Adverse Trend Report Rooorts (Page 21)

INDICATORS NEEDING INCREASED Unoianned Auto Scrams oer 7.000 Hours Critical MANAGEMENT ATTENTION REPORT (Page 29)

A performance indcator with data for the reporting period Unolanned Safety System Actuations (INPO Definition) that is inadequate when compared to the OPPD goal is (Page 30) defined as *Needing increased Management Attention

• i per Nuclear Operati:ns Division Quality Procedure 37 Unolanned Safety System Actuations (NRC Definition)

(NOD-QP-37).

(Page 31)

The foRowing performance indicators exhibited positive Primant Svutom Chemistry Percent of Hours Out of UmR trends for the reporting month:

(Page 39)

Industrial Safety Accident 3gtg Secondary System Chegsgh (Page 3)

(Page 40)

Fuel Reiability Indiestor Cents Per Kiowatt Hour (pag,14)

(Page 42) 2 l

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FORT CALHOUN STATION PERFORMANCE INDICATORS REPORT JULY 1995 -

SUMMARY

P INDICATORS NEEDING INCREASED MANAGEMENT ATTENTION REPORT (continued)

Comcave fladiaton EXDosure (Pa0e 17)

Forced Outaae Rats (Page 24)

Unt CapabRtv Factor (Pape 27)

Unit Canabilty Loos Factor (Page 28)

Eautoment Forced Outaae Rate (Page 35)

Temporary Modrheatons (Page 58)

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PERFORMANCE INDICATOR REPORT IMPROVEMENTS / CHANGES This sechon bats signi6 cant changes made to the report and to speclRc indicators within the report since the previous month.

Procedural Noncompliance incidents (Maintenance) -

Page 49 has been revised to ro6ect human performance related to its assigned to the maintenance func6onal 4

area.

A computer system automation is currenty underway to i

more of6ciently utiRze computer equipment to colect, analyze and produce data for the performance indicator report End of Report improvements / Changes Report t

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4 Table of Contents / Summary l

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induseini Safety Aceks.nt Rai. - INPO..................................................... 2 Disabiine injuryniin.es Ca s Fr.qu.ncy Rate............................................... 3 1

Recordable injuryAsiness Cases Frequency Rate............................................. 4 i

Clean Controlled Area Contaminations l

11,000 Disintegrations 44nute per Probe Area............................................. 5 0

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l Preventable / Personnel Error LERs........................................................ 6 4

Safety System Failures................................................................. 7 4

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Safety System Performance:

High Pressure Safety injection System.............................................. 8 Auxillery Feedwater Systern...................................................... 9 Emergency AC Power System

...................................................10 i

Emergency DieselGenerator Unit Reliability................................................................ 1 1 Reliability (25 Demands)

........................................................12 Unreilability.................................................................. 13 i

Fuel Relisbility Indicator................................................................ 14 i

Control Room Equipment Deficiencies.................................................... 15 4

On-Une and Outage Control Room Deficiencies............................................. 16 Colloclive Radiation Exposure........................................................... 17 3

Maximum individual Radiation Exposure................................................... 18 4

Violation Trend....................................................................... 19 '

i Significant Events.................................................................... 20 3

nessed Surveillance Tests Resulting in LERs............................................... 21 4

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Siamon Not Genwamon................................................................. 23 Forced Outa0e Rata..............................................................

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Unit Capacity Factor................................................................... 25 Equivalent Availability Factor............................................................ 26 unit Capanimy Factor.................................................................. 27 Unplanned CapabWty Loss Factor........................................................ 28

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k Unplanned Automatic Reactor Scrams por 7,000 Hours critical......................................................... 29

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Unplanned Safety System Actuations INPO Definition................................................................ 30 l

NRC Definition................................................................ 31 Gross Heat Rate...................................................................... 32 i

i Thermal Performance................................................................. 33 Daily Thermal Output.................................................................. 34 Equipment Forced Outa0es per 1,000 Critical Hours......................................... 35 Component Failure Analysis Report (CFAR) Summary....................................... 36 Repeat Failures...................................................................... 37 Volume of Low-Level Solid Radioactive Weste............................................. 38 Primary System Chemistry Percent of Hours Out of Limit..................................... 39 i

Secondary System Chemistry........................................................... 40 t

Cents Per Kilowatt Hour............................................................... 42 Staffing Level....................................................................... 4 3 Spare Parts inventory Value............................................................ 44 viii F

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l Table of Contents / Summary DMSiON AND DEPARTMENT PERFORMANCE INDICATORS PME Maintenance Workload sacklogs (Correceve Non-Outage)........................................ 46 Ratio of Preventive to Total Maintenance & Preventive Maintenance items Overdue......... 47 Percentage of Total MWOs Completed por month identified as Rework

. 48 I

Overtime..................................................................... 49 Procedural Noncompliance incidents.............................................. 50 Daily Schedule Performance - Percent of Completed Scheduled Actwities................ 51 1

• i in-Line Chemistry instruments Out-of-Service.............................................. 52 f

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i Hazardous Weste Produced............................................................ 53 1

4 Contaminated Radiation Controlled Area.................................................. 54

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Radiological Work Practices Program

...................................................55 4

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Document Review.................................................................... 56 4

i LoggableMoportable Incidents (Security).................................................. 57 i

Modifications Tempora ry.................................................................... 58 outstanding................................................................... So i

j Engineering Assistance Request (EAR) Breakdown

........................................60 Engineering Change Notices Status...................................................................... 61 Open.......................................................................62 l

Licensee Event Report (LER) Root Cause Breakdown....................................... 63 Ucensed Operator Requalification Training............................................... 64 i

License Candidate Exams.............................................................. 65 i

j Open incident Reports................................................................. 66 Cycle 17 Refueling Outage MWO Planning Status

..........................................................67 4

Outage Modification Planning

...................................................68 i

On-Une Modification Planning.................................................... 70 1

• I Progress of 1995 On-Une Modification Planning.......................................... 69 l

ACTION PLANS. DEFINITIONS. SEP INDEX & Dl3TRIBUTION LIST i

Action Plans....................................................................... 72 i

i Performance Indicator Definitions........................................................ 74 i

Safety Enhancement Program Inder.................................................... 82 4

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Repo 1 Destribubon List................................................................. 84 ix 5

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OPPD NUCLEAR ORGANIZATION GOALS Vice President-1995 Priorities MlII.LQN The safe, reliable and cost effective generation of electricity for OPPD customers through the professional use of nuclear technology. The Company shall conduct these operations prudently, efficiently and effectively to assure the health, safety and protection of all personnel, the general public and the environment.

GOALS 93 _1_:

SAFE OPERATIONS 1

Supports: April 1994 Corporate Strategic Plan Goal 3, Obj: 3 & 4 A proactive, self-critical and safety conscious culture is exhibited throughout the nuclear organization. Individuals demonstrate professionalism through self-ownership and personal

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initiative and open communication.

1995 Priorities:

Improve SALP ratings.

Improve INPO rating.

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

No unplanned automatic reactor scrams or safety system actuations.

Objectives to support SAFE OPERATIONS.

OBJECTIVE 1-1:

No challenges to a nuclear safety system.

OBJECTIVE 1-2:

Conduct activities in accordance with applicable policies, technical specifications, procedures, standing orders and work instructions.

Less than 1.4 NRC violations per 1,000 inspection hours.

Fewer significant Corrective Action Documents (CADS) originating from activities.

OBJECTIVE 1-3:

Identify conditions BEFORE they affect plant safety and reliability.

GBJECTIVE 1-4:

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Achieve all safety-related 1995 performance indicator goals in the Performance Indicator Report.

OBJECTIVE 1-5:

Zero Lost Time injuries and recordable injuries rate BELOW 1.5 percent.

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OPPD NUCLEAR ORGANIZATION GOALS Vice President-1995 Priorities j

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PERFORMANCE Supports: April 1994 Corporate Strategic Plan Goal 3, Obj: 2 and Goal 4, Obj: 1 i

l Achieve high standards of performance at Fort Calhoun Station resulting in safe, reliable and cost effective power production.

l 1995 PRIORITIES:

Improve Quality, Professionalism and Teamwork.

Improve Plant Reliability.

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

j Reduce the number of Human Performance errors.

e Identify Programmatic performance problems through effective self assessment.

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Objectives to support PERFORMANCE:

OBJECTIVE 2-1:

Achieve an annual plant capacity factor of 70% and a unit capability factor of 81%.

OBJECTIVE 2-2:

Execute the 1995 refueling outage in 49 days; emphasize shutdown plant safety.

OBJECTIVE 2-3:

Achieve all performance related 1995 performance indicator goals in the Performance Indicator Report.

]

OBJECTIVE 2-4:

All projects and programs are planned, scheduled, and accomplished according to schedules, 3

resource constraints, and requirements.

OBJECTIVE 2-5:

i Team /Indudualownership, accountability, performance and teamwork is evident by improved plant reliability; improved ratings for both INPO and NRC; reduced number of human performance errors and identification of performance problems by effective self assessment and for 4

Indudvals as measured by the successful completion of department goals & objectives and other speci5c measures.

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I OPPD NUCLEAR ORGANIZATION GOALS l

Vice President - 1995 Priorities i

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COSTS Supports: April 1994 Corporate Strategic Plan Goal 2, Obj: 1, 2 and 3, and Goal 6, Obj: 1 l

Operate Foet Calhoun in a manner that cost effectively maintains nuclear generation as an economically viable contribution to OPPD's " bottom line". Cost consciousness is exhibited at alllevels of the organization.

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1995 Priorities:

i Maintain total O&M and Capital Expenditures within budget.

Streamline work process to improve cost effectiveness.

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. Objectives to support COSTS:

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OBJECTIVE 3-1:

Conduct the nuclear programs, projects, and activities within the approved Capital and O&M budgets.

OBJECTIVE 3-2:

Implement nuclear related Opportunity Review recommendations according to approved schedules and attain the estimated cost savings.

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1 Goals Source:

Scofield (Manager) xh i

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l SAFE OPERATIONS 1

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l Goal: A proactive, self-critical and safety conscious culture is i

exhibited throughout the nuclear organization.

Individuals 1

demonstrate professionalism through self-ownership and per-sonal initiative and open communication.

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--*-- Year-to Date FCS Industrial Safety Accident Rate (IPPO DeAnstion)

-e-FCS Average Rate (Last 12 Months)

-*- FCS Year-End Goal (4.50) l GOOD l

-e-Industry Cunent Best Quartile (.24)

-e-1996 IPPO Industry Goal (<0.00) 2-1.5 -

0.59 !' 5 1

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l Jan Feb Mar Apr May Jun

.lul Aug Sep Oct Nov Dec INDUSTRIAL SAFETY ACCIDENT RATE As stated in INPO's December 1993 publication ' Detailed Descriptions of World Associa-tion of Nuclear Operators (WANO) Performance Indicators and Other Indicators for Use at U.S. Nuclear Power Plant': "The purpose of this indicator is to monitor progress in improv-ing industrial safety performance for utility personnel permanently assigned to the station."

The INPO industrial safety accident rate value year to date was 1.61 at the end of July 1995. The value for the 12 months from August 1,1994, through July 31,1995,was 1.07.

There were no restricted-time and no lost-time accidents in July 1995.

The values for this indicator are determined as follows:

(number of restricted-time accidents + lost-time accidents + fatalities) x 200.000

~

4 (number of station person-hours worked)

The 1995 Fort Calhoun year-end goal is 50.50. The 1995 INPO industry goal is 50.50.

i The approximate industry upper ten percentile value (for the period from 7/93 through 6/94) is 0.12.

l Data Scurce:

Sorensen/Skaggs (Manager / Source)

Chase / Booth (Manager / Source)

Accountability:

Chase / Conner Adverse Trend:

Needs increased Management Attention 4

2

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-+-- 1M6 Disabling injuryAliness Frequency

-x-1M4 Disabling injuryAliness Frequency

-*- Average Rate (Last 12 Months) l000Dl

-e-1M6 Goal (0.80) i Y

2-d 1.8-1,6-1.4-1.2-

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0 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec l1H6 l DISABLING INJURY / ILLNESS FREQUENCY RATE (LOST-TIME ACCIDENT RATE)

This indicator shows the 1995 disabling injury / illness frequency rate. The 1994 disabling injury / illness frequency rate is also shown.

The disabling injury / illness frequency rate year to date was 1.61 at the end of July 1995.

There were no disabling injury / illness cases reported for the month.

The disabling injury / illness frequency rate for the 12 months from August 1,1994, through July 31,1995, was 1.07.

The 1995 Fort Calhoun year-end goal for this indicator is a maximum value of 0.5.

Data Source:

Sorensen/Skaggs (Manager / Source)

Accountability:

Chase / Conner Adverse Trend:

None SEP 25,26 & 27 3

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-*- 1995 Recordable injury / Illness Frequency

- ++-- 1994 Recordable injury /lliness Frequency lGOOol

-*- Average Rate (Last 12 Months)

+ Fort Calhoun Goal 2.5 -

2.25 -

2-1 75 -

1.5 :

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Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec l1995l RECORDABLE INJURY /lLLNESS FREQUENCY RATE This indicator shows the 1995 recordable injury / illness frequency rate. The 1994 record-able injury / illness cases frequency rate is also shown.

A recordable injury / illness case is reported if personnel from any of the Nuclear Division are injured on the job and require corrective medical treatment beyond first aid. The recordable injury illness cases frequency rate is computed on a year-to-date basis.

There have been seven recordable injury /illnass cases in 1995. The recordable injury /

illness cases frequency rate year to date was 1.61 at the end of July 1995. There was one recordable injury / illness case reported for the month of July. These injuries were the result of tryino to hold onto a twisted cable causing a strained shoulder.

The recordable injury / illness cases frequency rate for the 12 months from August 1, 1994, through July 31,1995, was 1.34.

The 1995 Fort Calhoun year-end goal for this indicator is a maximum value of 1.5.

I Data Source:

Sorensen/Skaggs (Manager / Source)

Accountability:

Conner Adverse Trend; None SEP 15,25,26 & 27 l

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m Contamination Events (Monthly) l GOOD l

-*-- Contamination Events (YTD)

I f 50 -

42 40 p

31 30 -

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CLEAN CONTROLLED AREA CONTAMINATIONS 21,000 DISINTEGRATIONSI MINUTE PER PROBE AREA This indicator shows the Personnel Contamination Events in the Clean Controlled Area for contaminations 11,000 disintegrations / minute per probe area for the reporting month.

f There were 4 contamination events in July 1995. There has been a total of 46 con-L tamination events in 1995 through the end of July. This compares to 38 at this time last year.

Data Source:

Chase /Cartwright (Manager / Source)

Accountability:

Chase /Lovett Adverse Trend:

None SEP 15 & 54 l

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m Personnel Errors (Each Month)

--+- Preventable (18-Month Totals)

-e-Personnel Error (18-Month Totals) 20 -

15 -

10 -

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5-0 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb Mar Apr May June l1994l l1995 l PREVENTABLE / PERSONNEL ERROR LERs This indicator depicts 18-month totals for numbers of " Preventable" and " Personnel Error" LERs.

The graph shows the 18-month totals for preventable LERs, the 18-month totals for Personnel Error LERs and the Personnel Error totals for each month. The LERs are trended based on the LER event data as opposed to the LER report date.

in June 1995, there were no events which were subsequently reported as an LER. No LERs were categorized as Preventable or as a Personnel Error for the month of June.

The total LERs for the year 1995 (through June 30,1995) is three. The total Personnel Error LERs for the year 1995 is zero. The total Preventable LERs for the year is one.

The 1995 goal for this indicator is that the year-end values for the 18-month totals be no more than 12 Preventable and 5 Personnel Error LERs.

Data Source:

Trausch/Cavanaugh (Manager / Source)

Accountability:

Chase Adverse Trend:

None SEP 15 6

Startup Shutdown l GOOD l Operations

- Industry Average Trend 5 ~

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=l 93-4 94 94-2 94-3 94-4 95-1 92-2 92-3 92-4 93 1 93-2 93-3 Year-Quarter l SAFETY SYSTEM FAILURES This indicator illustrates the number of NRC Safety System Failures as reported by the Nuclear Regulatory Commission's Office for Analysis and Evaluation of Operational Data in the biannual " Performance indica-tors for Operating Commercial Nuclear Power Reactors" report. First Quarter 1994 through First Quarter 1995 are projected.

The following NRC safety system failures occurred between the second quarter of 1992 and the first quarter of 1995:

1st Quarter 1993: The SG low pressure scram signal block reset values, for all 4 channels of both SGs, were greater than the allowed limits, rendering this scram input inoperable during certain operating condi-tions.

2nd Quarter 1993: A section of the piping configuration for the borated water source of the safety injection system was not seismically qualified. This could have resulted in a failure of the system to meet design requirements during a seismic event.

l 4th Quarter 1993: 1) During surveillance testing, both PORVs for the LTOP system failed to open during multiple attempts. The failures were a result of differential expansion caused by a loop seal, excessive venting line back pressure, and cracked valve disks; 2) Calibration errors of the offsite power low signal 3

relays could have prevented offsite power from tripping and the EDGs from starting in the required amount i

of time during a degraded voltage condition; 3) Both AFW pumps were inoperable when one was removed l

from service for testing and the control switch for the other pump's steam supply valve was out of the auto 1

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.

1st Quarter 1994: A design basis review determined that an ESF relay could result in loss of safety injection and spray flow, due to premature actuation of recirculation flow.

4th Quarter 1994: An accident scenario was identified that could result in the inoperability of both control room air conditioning units. Following certain accident conditions, CCW temperature could rise causing i

compressor rupture disc failure and a release of freon.

Data Source:

Nuclear Regulatory Commission Accountability:

Chase j

Positive Trend 7

c_ - _ _ _ _ _ _ _ - ____________ - _

i m Monthly High Pressure Safety injection System Unavailability Value

-*- Year-to-Date High Pressure Safety inject!on System Unavailability Value

-*- Fort Calhoun Goal (0.004) l GOOD l

-*- INPO Industry Goal (0.02)

-m-Industry Upper 10% (0.0011) 0.02 -

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0.015 -

t 0.01 0.005 c

3 0

- - -1 1994 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec l1996l 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 reporting month.

The High Pressure Safety System unavailability value for the month of July 1995 was 0.004. There was 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> of planned unavailability, and 0 hours0 days <br />0 hours <br />0 weeks <br />0 months <br /> of unplanned unavailabil-ity, during the month. The 1995 year-to-date HPSI unavavailability value was 0.0003 at the end of the month. The unavailability value for the last 12 months was 0.00028.

There has been a total of 2.83 hours9.606481e-4 days <br />0.0231 hours <br />1.372354e-4 weeks <br />3.15815e-5 months <br /> of planned unavailability and 0.0 hours0 days <br />0 hours <br />0 weeks <br />0 months <br /> of unplanned unavailability for the high pressure safety injection system in 1995.

The 1995 Fort Calhoun year-end goal for this indicator is a maximum value of 0.004. The 1995 INPO industry goalis 0.02 and the industry upper ten percentile value (for the three-I l

year period from 1/92 through 12/94) is approximately 0.001.

Data Source:

Jaworski/Schaffer Accountability:

Jaworski/Schaffer Positive Trend 8

M Monthly Auxillary Feedwater system Unavailability

+ Year to Oste Emergency AC Power unavailability

+ Fort Calhoun Goal (0.01) l GOOD l

+ INPo industry Goal (0.025) f

+ Industry Upoor 10% (0.0021) y 0.03 -

0.025 -

0.02 -

0.015-l 0.01 0.008 -

amans 0

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I Year Jan Feb Mar Apr May Jun Jul Aug sep Oct Nov Dec 1W l1996l l

AUXILIARY FEEDWATER SYSTEM SAFETY SYSTEM PERFORMANCE This indicator shows the Auxiliary Feedwater System Unavailability value, as defined by INPO in the Safety System Performance Indicator Definitions, for the reporting month.

The Auxiliary Feedwater System Unavailability Value for July 1995 was 0.00995. There was 1.88 hours0.00102 days <br />0.0244 hours <br />1.455026e-4 weeks <br />3.3484e-5 months <br /> of planned and 12.92 hours0.00106 days <br />0.0256 hours <br />1.521164e-4 weeks <br />3.5006e-5 months <br /> of unplanned unavailability during the month for FW-10 for the sticking open throttle valve. The year-to-date unavailability value was 0.00581 and the value for the last 12 months was 0.00302 at the end of the month.

There has been a total of 29.56 hours6.481481e-4 days <br />0.0156 hours <br />9.259259e-5 weeks <br />2.1308e-5 months <br /> of planned unavailability and 12.92 hours0.00106 days <br />0.0256 hours <br />1.521164e-4 weeks <br />3.5006e-5 months <br /> of un-planned unavailability for the auxiliary feedwater system in 1995.

The 1995 Fort Calhoun year-end goal for this indicator is a maximum value of 0.01.

The 1995 INPO industry goal is 0.025 and the industry upper ten percentile value is ap-proximately 0.002.

Data Source:

Jaworski/Nay Accountability:

Jaworski/Nay Adverse Trend:

None 9

i m Monthly Emergency AC Power Unavailability value

+ Year-to-Date Ernergency AC Power Unavailability Value

--*- Fort Calhoun Goal (0.024) l GOOD l

--e-1995 INPO Industry Goal (0.025)

-e-Industry Upper 10% (0.0035)

O.03 -

0.025 -

g g

g g

g g

g g

g g

g g

0.02 -

0.015 -

~

0.01 i@

0.005 m

~~

O C

C C

3

_ o_

l N

O b

m 0

Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec d

EMERGENCY AC POWER SYSTEM SAFETY SYSTEM PERFORMANCE i

This indicator shows the Emergency AC Power System unavailability value, as defined by l

lNPO in the Safety System Performance Indicator Definitions, for the reporting month.

The Emergency AC Power System unavailability value for July 1995 was 0.0013. During the month, there were 9.1 hours1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> of planned unavailability for testing, and 0.0 hours0 days <br />0 hours <br />0 weeks <br />0 months <br /> of unplanned unavailability. The Emergency AC Power System unavailability value year-to-date was 0.0043 and the value for the last 12 months was 0.0067 at the end of the month.

There has been a total of 43.5 hours5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br /> of planned unavailability and 0.0 hours0 days <br />0 hours <br />0 weeks <br />0 months <br /> of unplanned unavailability for the emergency AC power system in 1995.

The 1995 Fort Calhoun year-end goal for this indicator is a maximum value of 0.024.

The 1995 INPO industry goal is 0.025 and the industry upper ten percentile value is ap-proximately 0.0035.

Data Source:

Jaworski/Ronning Accountability:

Jaworski/Ronning Positive Trend based on performance better than goal 10

M Failures /20 Demands C"'3 Failures /50 Demands m Failures /100 Demands

- *- Trigger Values /20 Demands l GOOD l

--*-- Trigger Values /50 Demands

-*- Trigger Values-100 Demands l f 8-7-

6 5-a c

e a

a 4

3-a e

e-e e-e e

--*- -- +

+

m.--

a

~

1 1

1 1

11 111 11 11 11 11 11 11 L

n i

L ms as q i

a a

s s

Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun Jul lb l1995j EMERGENCY DIESEL GENERATOR UNIT RELIABILITY This bar graph shows three monthly indicators pertaining to the number of failures that were reported during the last 20, 50, and 100 emergency diesel generator demands at the Fort Calhoun Station. Also shown are trigger values which correspond to a high level of confidence that a unit's diesel generators have obtained a reliability of greater than or equal to 95% when the failure values are below the corresponding trigger values. The Fort Calhoun 1995 goal is to have fewer failures than these trigger values.

The last failure to start was the result of DG-1 damper failure on December 8,1994.

l i

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

(,

of the following criteria: a load-run that is a result of a real load signal, a load-run test i

expected to carry the plant's load and duration as stated in the test specifications, and a special test in which a diesel generator was expected to be operated for a minimum of one hour and to be loaded with at least 50% of design load (see exceptions and other demand criteria in the Definition Section of this report).

Data Source:

Jaworski/Ronning (Manager / Source)

Accountability:

Jaworski/Ronning Positive Trend 11

(

t

1 1

l

)

DG-1 Failures /25 Demands DG-2 Failures /25 Demands l GOOD l

• 1995 Goal 5

I f 4-C 3

3-2-

1 1

1 1

1 1

1 1

0 0 0 0 0 0 0 0 0 0 0

0 0

0 0

0 0

0 -

Jul Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun j

l1994l l1995l 1

DIESEL GENERATOR RELIABILITY (25 DEMANDS)

This indicator shows the number of failures experienced by each emergency diesel generator during the last 25 start demands and the last 25 load-run demands. A trigger value of 4 failures within the last 25 demands is also shown. This trigger value of 4 failures within 25 demands is the Fort Calhoun goal for 1995.

It must be emphasized that, in accordance with NUMARC criteria, certain actions will take place in the event that any one emergency diesel generator experiences 4 or more failures within the

+

last 25 demands on the unit. These actions are described in the Definitions Section of this report.

1 A System Engineering Instruction has been approved for the Fort Calhoun Station to institution-atize and formally approve / adopt the required NUMARC actions.

Diesel Generator DG-1 has experienced one failure during the last 25 demands on the unit. On December 8,1994, DG-1 failed its monthly surveillance test because the inlet air damper would not open. The cause of the failure was found to be ice buildup on the damper louvers from a previous snowstorm.

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

Special diesel testing during hot weather took place during July. This testing enabled the diesel high temperature operability limits to be raised.

Data Source:

Jaworski/Ronning (Manager / Source)

Accountability:

Jaworski/Ronning Positive Trend due to performance better than goal 12 i

l M DG-1 Unreliability Value M DG-2 unreliability Value

-+-- station Unreliability Value l GOOD l

+ 1995 Goal O

Industry Upper 10% (0.002 for a 3-Year Average) 0.07 -

0.06 -

0.05 -

0.04 -

l 0.03 -

f.

0.02 -

f 00 y,o oe oe oo oo oe oo eo eo eo eo oo Aug sep Oct Nov Dec Jan Feb Mar Apr May Jun Jul l1994l l1995l EMERGENCY DlESEL GENERATOR UNRELIABILITY The purpose of this indicator is to monitor the likelihood that emergency AC power gen-erators will respond to off-normal events or accidents. It also provides an indication of the effectiveness of maintenance, operation and test practices in controlling canerator unreliability.

The year-to-date station EDG unreliability at the end of May 1995 was 0.0. The 1995 goal for this indicator is a maximum value of 0.05.

l l

For DG-1:

There were 6 start demands for the reporting month without a failure.

in addition, there was 2 load-run demand without a failure.

I For DG-2:

There were 5 start demands for the reporting month without a failure.

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

Emergency diesel generator unreliability is calculated as follows:

value per DG = SU + LU -(SU x LU) where SU = Start Unreliability = number of unsuccessful starts number of valid start demands LU = Load-run Unreliability = number of unsuccessfulload-runs number of valid load-run demands Station Value = average of DG-1 and DG-2 values Data Source:

Jawerski/Ronning (Manager / Source)

Accountability:

Jaworski/Ronning Positive Trend 13

Fuel Reliability

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

--G-1995 Goal g

25 Y

20 -

g N

cycle is

[

r,15 -

~

A w

C Refuenng Y

j j 10 -

g, g

g "y

d outage 2

[j j

2 T

d A

M r

5 un id E

M8 3

B311E M

h d

DJ,

Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun Jul l1994)

FUEL RELIABILITY INDICATOR The FUEL RELIABILITY INDICATOR (FRI) forJuly 1995 was 17.29 X 10d microcuries/ gram. The purpose of the FRI is to monitor industry progress in achieving and maintaining a high level of fuel integrity. An effective fuelintegrity and performance monitoring program provides a means to detect fuel failures and assess the fuel failure number, physical condition, exposure, mechanism, and location.

l The July FRI value is based on data from July 1 through 31. The days selected are when the plant chemistry values reached equilibrium from steady-state full power operation.

Cycle 16 plant operation started on April 13 and attained 100% power was achieved on April 23. During May, the plant operated at 100% power until May 11th when the plant was tripped and remained at hot shutdown conditions for repairs. The plant commenced power increase on May 15th obtaining 100% power on May 17th. The plant remained at 100% power until May 23rd when the plant was tripped and brought to a cold shutdown condition for replacement of Reactor Coolant Pump lubricant oil coolers. The plant re-mained at cold shutdown through May 28th. The plant commenced a powerincrease on May 29th. During the months of June and July the plant operated at 100% power.

The July FRI value of 17.29 X 10d microcuries/ gram indicated a slight decrease from the June FRI value of 19.15 X 104 microcuries/ gram. This decrease is not significant. The Xenon activity has shown an increase I

through the cycle but has leveled off during July. In May, there were several lodine-131 spikes during the plant trips and also increasing lodine-131 values during 100% operation, indicating failed fuel pins. A recent analysis performed by the fuel vendor indicates four to six failed rods at core average power. The analysis indicates failures in several different batches.

The INPO September 1992 report, " Performance Indicators for US Nuclear Utility Industry" (INPO No.92-011) states that "the 1995 industry goal for fuel reliability is that units should strive to operate with zero fuel defects. A value larger than 5 x 10d 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 10d microcuries/ gram is defined as a " Fuel Defect Reference" number of a "Zero LeakerThreshold." Each utility will evaluate whether the core is defect free or not. The 1995 Fort Calhoun Station FRI Performance Indicator goalis to maintain a monthly FRI below 5.0 x 10d microcuries/ gram.

Data Source:

Holthaus/ Weber Accountability:

Chase /Spijker Trend:

Needs increased Management Attention 14

=. -. _. -

i M Control Room Deficiencies Added Control Room Deficiencies Completed W Completed within Target Completion Date Completion Rate 50 -

- 100.0 %

07.5%

Goal Compieve 80% of C R Deflceencees by Tarpet Completion Date 40 -

88.6%

1) 39.8%

60.0 %

4, 4

30 -

- 40.0%

u u

20 -

20.0 %

is is is 10 -

i I

60 0.0%

May 22-29, '95 Jun-95 Jul-95 Aug-95 Control Room Deficiencies l

'8****'

i NUMBER OF CONTROL ROOM EQUIPMENT DEFICIENCIES This indicator measures the timeliness of closing Control Room Deficiencies.

Target Completion Dates are established by the Emergent Work Committee. The goalis to close at least 80% of all CRD's within the Target Due Paie.

4 l

There were 23 Control Room Deficiencies completed sturing July 1995, and 16 were completed within the target completion date.

A Scheduling Coordinator has been assigned to track performar ce on a weekly basis and identify problem areas.

The 1995 Fort Calhoun goal for this indicator is a completion rate of 80%.

Data Source:

Chase / Walling (Manager / Source)

Accountability:

Chase /Faulhaber Adverse Trend:

None 2

15

i M Overdue

--+- Number of On-Line Control Room Deficiencies M'

so%,e 20 -

15 -

10 -

i i

May45 Jun45 Jul45 Aug45 l Number of On-Line CRD's l Overdue

--+- Number of Outage Control Room Deficiencies 25 -

0 0 8' 20 -

is 15 -

10 -

5-a o..i. w.n. o n.e.

May45 Jun45 Jul45 Aug45 l Number of Outage CRD's l Note: Overdue items are those otoer then 18 months l

NUMBER OF ON-LINE AND OUTAGE i

CONTROL ROOM EQUlPMENT DEFICIENCIES 1

This indicator shows the total number of On-Line and Outage Control Room Deficiencies,,

and the number of overdue Control Room Deficiencies.

There were 23 on-line (9 were overdue) and 21 outage (0 were overdue) Control Room Deficiencies at the end of July 1995.

The 1995 Fort Calhoun goal for these indicators are less than 8 overdue on-line and no overdue outage Control Room Deficiencies.

Data Source:

Chase / Walling (Manager / Source)

Accountability:

Chase /Faulhaber/Clemens Adverse Trend:

None 16

l Elgmi Monthly Personnel Radiation Exposure

-*- Cumulative Personnel Radiation Exposure l Good l

-o-FCS Goal (143.1 Person-Rem) 150

,,,J._.

3 o

o o.

.o 130 -

120 110 -

100 E

g 90 of 80 70 i

60 h

50 40 30 20 10 0 "-

4 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec l1995 l COLLECTIVE RADIATION EXPOSURE The 1995 Fort Calhoun goal for collective radiation exposure is less than 143.1 person-Rem.

The exposure for July 1995 was 2.832 person-Rem (ALNOR).

The year-to-date exposure through the end of June was 134.915 person-Rem (TLD). The biggest contributor to dose in July was the removal of resin from Room 23; however, removal of the resin should result in future dose savings.

The 1995 INPO industry goal for collective radiation exposure is 185 person-rem per year. The current industry best quartile is 145 person-rem per year. The yearly average for Fort Calhoun Station for the three years from 8/92 through 7/95 was 111.16 person-rem per year.

Data Source:

Chase /Cartwright (Manager / Source)

Accountability:

Chase /Lovett Adverse Trend:

Needs increased Management Attention SEP54 17

O Highest Exposure (Month)

B Highest Exposure (Year) 5000-OPPD 4500 mRemlyr. IJmit 4000 -

3000 -

2000-1,266 j

f4 ;fj FCS Goal 1000 -

a as a,m_

e WA WNP&

197 I

0 l July-95l MAXIMUM INDIVIDUAL RADIATION EXPOSURE During July 1995, an individual accumulated 197 mrem, which was the highest indi-vidual exposure for the month.

The maximum individual exposure for the year of 1,000 mrem was exceeded during March 1995 when an individual received 1,266 mrem (875 mrem of this was received during orifice plate repair in a steam generator). However, the OPPD 4500 Mrem /yr limit is not expected to be exceeded.

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

year. The 1995 Fort Calhoun year-end goalis a maximum of 1,000 mrem.

Data Source:

Chase /Cartwright (Manager / Source)

Accountability:

Chase /Lovett Adverse Trend:

None 18

GMB FCS Cited Violations (Monthly)

C-I FCS Non Cited Violations (Monthly) l M ol

-e--

FCS Cited Violations (12-Month Average)

-e - FCS Non-CMed Violations (12-Month Average) g

- m--

Region IV Cited Violations (12-Month Average for Region IV top quartile)

Y 14 12

~

=

e-g 6-(

a o%

4 2

U O C E

E 0

Aug Sep Oct Nov Dec Jan Feb Mar Apr May June July

[,1a4j 11a51 VIOLATION TREND This indicator illustrates a 12-month trend for Fort Calhoun Station Cited Violations, Non-Cited Violations and Cited Violations for the Top Quartile plants in Region IV. Addition-cily, the Fort Calhoun Station cited and non-cited violations for the past 12 months will be illustrated monthly. The 12-month trend for the Region IV top quartile lags 2-3 months behind the Fort Calhoun Station trend. This lag is necessary to compile information on other Region IV plants.

The following inspections were completed during July 1995:

lER No.

Title None To date, OPPD has received five violations for inspections conducted in 1995.

4 Levellli Violations 0

LevelIV Violations 3

l Level V Violations 0

Non-Cited Violations 2

Total 5

The 1995 Fort Calhoun Station Goal for this performance indicator is to be at or below the cited violation trend for the top quartile plant in Region IV.

Data Source:

Trausch/Cavanaugh (Manager / Source) i Accountability:

Trausch Adverse Trend:

None 19

M NRC Significant Events

+ Industry Average Trend l0000l 1-0J -

~

~

=

1 2

I I

~

0 i

i 92-2 92-3 92-4 93 1 93-2 n3 3 es d - 94 1 94-2 94-3 94 4 95-1 (Year - Quarter l INPO Significant Events (SERs) l lo000l l f 2-y 1-0 92-2 92 3 92-4 93 1 93-2 93 3 93 4 94-1 94-2 94-3 94-4 95 1 l Year-Quarter l SIGNIFICANT EVENTS This indicator illustrates the number of NRC and INPO Significant Events for Fort Calhoun Station as re-ported by the Nuclear Regulatory Commission's Office for Analysis and Evaluation of Operational Data in the blannual" Performance indicators for operating Commercial Nuclear Power Reactors" report and lNPO's Nuclear Network.

The following N8Q significant events occurred between the second quarter of 1992 and the first quarter of 1995:

3rd Quarter 1992: The failure of a Pressurizer Code safety valve to reseat initiated a LOCA with the potential to degrade the reactor coolant pressure boundary.

4th Quarter 1994: A potential accident scenario involving a large break loss of coolant accident or a main steam line break inside containment could result in the inoperability of both control room air conditioning units.

The following JNE.Q significant events, as reported in Significant Event Reports (SERs), occurred between the second quarter of 1992 and the First Quarter cf 1995:

2nd Quarter 1992: Intake of Transuranics during Letdown Filter Change-out.

3rd Quarter 1992: 1) RC-142 LOCA; and 2) Premature Lift of RC-142.

1st Quarter 1993: Inoperability of Power Range Nuclear Instrumentation Safety Channel D.

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

First Quarter 1994: Unplanned dilution of Boron concentration in the RCS.

Data Source:

Nuclear Regulatory Commission & INPO Accountability:

Chase Positive Trend 20

i l

Missed STs Resulting in LERs l 3-i i

2-e 1

'1

.s

+

7;g e

l I

g_.

k e

f a

o e

0 0

0 0

i 0

I 93 94 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec d

NUMBER OF MISSED SURVEILLANCE TESTS RESULTING IN LICENSEE EVENT REPORTS This indicator shows the number of missed Surveillance Tests (STs) that result in Lic-ensee Event Reports (LERs) during the reporting month. The graph on the left shows the yearly totals for the indicated years.

There were no missed surveillance tests resulting in LERs during June 1995.

On December 28,1994, during the performance of OP-ST-SHIFT-0001, data was not entered for Steam Generator level per Surveillance Requirements.

The 1995 Fort Calhoun monthly goal for this indicator is 0.

3 Data Source:

Monthly Operating Report & Plant Licensee Event Reports (LERs)

Accountability:

Chase /Jaworski Positive Trend SEP 60 & 61 21

4 W

PERFORMANCE P

Goal: To strive for Excellence in Operations utilizing the high-l est standards of performance at Fort Calhoun Station that 2

result in safe, reliable plant operation in power production.

l l

i i

l l

l i

i l

l

}

l i

?

l Net Generation (10,000 MWh)l 40 i

36.21 36.22 34.14 33.33 34.12 30 -

e g

22.82 21.19 g 20 -

k 16.29 S

r 10 n

f I

5 W

l 1 ll l h}

h i

Il i

a O

-4 Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun Jul l1994l l

STATION NET GENERATION During the month of July 1995, a net total of 347,499.0 MWH was generated by the Fort Calhoun Station. Cumulative net generation for Cycle 16 was 916,974.6 MWH at the end of the month.

Energy losses for May 1995 were attributable to: (1) the component cooling water, which was leaking into the tube oil system of RC-3D reactor coolant pump motor; and (2) the

=

generator and reactor were again manually tripped because of a similar leak. The gen-erator was put on-line after replacement of all of the reactor coolant pump lube oil cooler heat exchangers.

Data Source:

Station Generation Report Accountability:

Chase Adverse Trend:

None 23 l

l

C""] Forced Outage Rate (Monthly)

-+- Forced Outage Rate (12 Months) l GOOD l

-+-- Fort Calhoun Goal (2.4%)

I f 35%

30 %

25% -

20% -

15% -

101%

10% -

5%

Den C

C C

C C

C C

C C

b b

U M

W; 0%

92 93 94 Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun Jul-95 FORCED OUTAGE RATE The forced outage rate (FOR) was reported as 3.0% for the twelve months from August 1,1994, through July 31,1995. The 1995 year-to-date FOR was 5.9% at the end of the month.

Energy losses for May 1995 were attributable to: (1) the component cooling water, which was leaking into the tube oil system of RC-3D reactor coolant pump motor; and (2) the generator and reactor were again manually tripped because of a similarleak. The gen-erator was put on-line after replacement of all of the reactor coolant pump lube oil cooler heat exchangers.

The 1995 Fort Calhoun year-end goal for this indicator is a maximum value of 2.4%.

Date Source:

Monthly Operating Report Accountability:

Chase Trend:

Needs increased Management Attention 24

1 l

L

, Monthly Unit Capacity Factor i

.. m... Year-to-Date Unit Capacity Factor l GOOD l e-Unit Capacity Factor for Cycles 15 & 16 g

_a- _ 36-Month Average Unit Capacity Factor y

x FCS Goal (79.65%)

110%..

100 % _

""~

0 0

90%

~

80% -

p 4

w 3

/

70%.-

y

~

m e..

N [

8' 60%

gng __

40%.-

3" -

cyca ss 20 %

• • a me l

10%

0%

Aug Sep Oct Nov Dec Jan Feb Mar.

Apr May Jun Jul O

O UNIT CAPACITY FACTOR This indicator shows the plant monthly Unit Capacity Factor, the Unit Capacity Factor for the current fuel cycle, year to date and the 36-month average Unit Capacity Factor, j

At the end of the month, the Cycle 16 Unit Capacity factor was 97.71%, and the Unit Capacity Factor for the last 36 months was 80.53%. The 1995 Fort Calhoun annual goal for this indicator is 79.65%. The Fort Calhoun 3-year average capacity factor goal for 1995is 84.05%.

l Energy losses for May 1995 were attributable to: (1) the component cooling water, which was leaking into the lube oil system of RC-3D reactor coolant pump motor; and (2) the 1

generator and reactor were again manually tripped because of a similar leak. The gen-erator was put on-line after replacement of all of the reactor coolant pump lube oil cooler heat exchangers.

The Unit Capacity Factor is computed as follows:

Net Electrical Enerav Generated (MWH)

Maximum Dependable Capacity (Mwe) X Gross Hours in the Reporting Period 1

Data Source:

Monthly Operating Report Accountability:

Chase Adverse Trend:

None 25

1 i MonthlyEAF i

_m Year-toeste Average MonthlyEAF

+ 12 Month Average EAF

+ Industry Median Value (76.7% for a 3-Yoar Average) 100 % -

s r.n y

1. . +

0 g,

y

. 3 /

'N x

\\

4 E-#

80%.

g

..g x

x x

x._

.x x-. _.x x

x.

a

\\

.R II -

g/

60 3 %

40% --

Cycle 16 Refueling outsee 0%

92 93 94 Aug Sep oct Nov Dec Jan Feb Mar Apr May Jun Jul-95 EQUIVALENT AVAILABILITY FACTOR This indicator shows the plant monthly Equivalent Availability Factor (EAF), the year-to-date aver-age monthly EAF, and the year-end average monthly EAF for the previous three years.

The EAF for July 1995 was reported as 95.15%. The year-to-date monthly average EAF was 76.9% at the end of the month.

Energy losses for May 1995 were attributable to: (1) the component cooling water, which was leaking into the lube oil system of RC-3D reactor coolant pump motor; and (2) the generator and reactor were again manually tripped because of a similar leak. The gen-erator was put on-line after replacement of all of the reactor coolant pump lube oil cooler heat exchangers.

The Fort Calhoun average monthly EAF for the three years prior to this report was 87.8%. The industry median EAF value for the three-year period from 7/90 through 6/93 was 76.7%.

Data Source:

Dietz/Kulisek (Manager / Source)

Accountability:

Chase Adverse Trend:

None 26

i Monthly Unit Capability Factor i

.. at.. Year-to-Date Unit Capability Factor 4

36-Month Unit Capability Factor x

Fort Calhoun Goals INPO Industry Goals N ~

T 7:.... A.... y y

... - t m

m m

m m

m 80%.. g g,

_g_

g __ 4f]

-- - - E - ?

5

~ ~ ~

-u

)

60%.

't '

. at

. a Cycl.15 20%._

n.a mio omme.

0%

l Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun Jul

{99]

l1995l UNIT CAPABILITY FACTOR This indicator shows the plant monthly Unit Capability Factor (UCF) value, the year-to-date UCFs, the 36-month average UCFs, and the UCF goals. UCF is defined as the ratio of the available energy generation over a given period of time to the reference energy generation (the energy that could be produced if the unit were operated continuously at full power under reference ambient conditions) over the same time period, expressed as a percentage (refueling periods excluded).

i The UCF for July 1995 was reported as 100%. The year-to-date UCF was 62.1%, the UCF for the last 12 months was 77.6%, and the 36-month average UCF was reported as 84.5% at the end of the month.

Energy losses for May 1995 were attributable to: (1) the component cooling water, which was leaking into the lube oil system of RC-3D reactor coolant pump motor; and (2) the g

generator and reactor were again manually tripped because of a similar leak. The gen-erator was put on-line after replacement of all of the reactor coolant pump lube oil cooler heat exchangers.

The 1995 INPO industry goal is 80% and the industry current best quartile value (for the three-year period ending 12/94) is approximately 85%. The 1995 Fort Calhoun annual goal for this indicator is a minimum of 81.64%. The 3-year average capability factor goal for 1995 is 85.5%.

Data Source:

Generation Totals Report & Monthly Operating Report Accountability:

Chase Trend:

Needs increased Management Attention 27

/

i Monthly Unplanned Capability Loss Factor l Good l

-e-Year-To-Date Unplanned Capability Loss Factor 4

1

--*- 12-Month Average Unplanned Capability Loss Factor i

i

-M-Fort Calhoun Goal (3.97%)

--o-INPO Industry Goal (4.6%)

40% -

-+-- Industry Current Best Quastile

)

36 % ~

~

~~~

1 30% -

25% -

.at i

20 %

/

8-j 15% -

M l

~ ~ ~ ~ '

10% -

3 g f

5% -

0%

3-3 3 -

1.

s.

s Aug-Sep Oct Nov Dec Jan Feb Mar Apr May Jun Jul b

b f

UNPLANNED CAPABILITY LOSS FACTOR This indicator shows the plant monthly Unplanned Capabilit' 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

[

j unit were operated continuously at full power under reference ambient conditions), expressed as l

a percentage.

i Unplanned energy losses for February 1995 were due to a problem with a control element as-sembly seal leakage of reactor coolant. Unplanned energy losses for March 1995 were due to j

the start of the plant's 15th refueling outage,19 days prior to the originally scheduled start date.

i i

The UCLF for the month of July 1995 was reported as 0.0%. Unplanned energy loss is defined l

as the energy that was not produced during the period of unscheduled shutdowns, outage exten-j sions, or load reductions due to causes under plant management control. Energy losses are considered to be unplanned if they are not scheduled at least four weeks in advance. The year-to-date UCLF was 15.01%, the UCLF for the last 12 months was 11.57%, and the 38-month I

average UCLF was reported as 5.70% at the end of the month.

8 l

Energy losses for May 1995 were attributable to: (1) the component cooling water, which was leaking into the lube oil system of RC-3D reactor coolant pump motor, and (2) the generator and reactor were again manually tripped because of a similar leak. The generator was put on-line j

after replacement of all of the reactor coolant pump lube oil cooler heat exchangers.

The 1995 INPO industry goal is 4.5% and the industry current best quartile value is approxi-j

[

mately 3.2% or lower. The 1995 Fort Calhoun year-end goal for this indicator is a maximum value of 3.97%.

Data Source:

Generation Totals Report & Monthly Operating Report j

Accountability:

Chase Trend:

Needs increased Management Attention 28 a

-e-- FCS Reactor Scrams Per 7,000 Hours Critical Year to Date

-+- FCs Reactor Scrams Per 7,000 Hours Critical for last 36 months

-e-Fort Calhoun Goal (0,0) INPO Industry Goal (1)

C Industry Upper 10% (1 per 7,000 hours0 days <br />0 hours <br />0 weeks <br />0 months <br /> critical) 3-a O

0 0

0 p

igi

-3

- g-g A-A A-

-~A -

w 2-0 ".

Aug sep oct Nov Dec Jan Feb Mar Apr May Jun Jul l1994l l1995l FCs Reactor scrams 4.-

3 3_

2 2.

1 1

o o

o e

o o

o o

o o

o o

o 0

l l

l l

l l

l l

l l

91 92 93 94 Aug sep Oct Nov Dec Jan Feb Mar Apr May Jun Jul-95 UNPLANNED AUTOMATIC REACTOR SCRAMS PER 7,000 HOURS CRITICAL The upper graph shows the number of unplanned automatic reactor scrams per 7,000 hours0 days <br />0 hours <br />0 weeks <br />0 months <br /> critical (as defined in INPO's 12/93 publication " Detailed Descriptions of Interna-tional Nuclear Power Plant Performance Indicators and Other Indicators") for Fort Calhoun i

Station. The lower graph shows the number of unplanned automatic reactor scrams that occurred during each month for the last twelve months.

e The year-to-date station value was 0.0 at the end of July 1995. The value for the 12 months from August 1,1994, through July 31,1995, was 0.0. The value for the last 36 months was 1.27.

The 1995 Fort Calhoun goal for this indicator is 0. The 1995 INPO industry goal is a maximum of one unplanned automatic reactor scram per 7,000 hours0 days <br />0 hours <br />0 weeks <br />0 months <br /> critical. The indus-try upper ten percentile value is approximately 0.48 scrams per 7,000 hours0 days <br />0 hours <br />0 weeks <br />0 months <br /> critical.

Data Source:

Monthly Operations Report & Plant Licensee Event Reports (LERs)

Accountability:

Chase Positive Trend 29

EMRI Safety System Actuations (INPO Definition)

~*-- FcS Goal (0)

--+-- Industry Upper 10 Percentile (0) 3-2-

1 1

W lI IN

!I h

u h

L o

0 0

e o

o o

o 0

0 0

0 0

0

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

There were no INPO unplanned safety system actuations during the month of July 1995.

There was one INPO unplanned safety system actuation during the month of February 1994. It occurred on February 11,1994, 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 au-6 tomatically closed both main stam isolation valves, which resulted in a concurrent turbine and reactor trip.

An INPO unplanned safety sytem actuation also occurred during the month of July 1992 due to the loss of an inverter and the subsequent reactor trip on 7/3/92.

The 1995 Fort Calhoun goal for this indicator is 0.

Data Source:

Monthly Operations Report & Plant Licensee Event Reports (LERs)

Accountability:

Jaworski/Foley/Ronning Positive Trend 30

= _. - -

WEB Safety System Actuations (NRC Definition)

C FcS Goal (0)

-+-- critical Hours 10 -

800 cym is cym ie Matvehng Refuehng 0*e*

Ourse*

700 8

~U m

2 6-

s k

g 400 _

1 4

i

~'

300 5

-200 2-100 O

-I,I,

-l

' +: := ;' ;;;= :e 0

92 93 94 JASONDJFMAMJJASONDJFJFMAMJ l1993l 11994l 99 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 Emergency Diesel Generators. The NRC classification of SSAs includes actua-tions when major equipment is operated and when the logic systems for these safety systems are challenged.

An unplanned safety system actuation occurred in December 1993 when the main turbine and reactor tripped during Electro-Hydraulic Control pump start testimg. Also, there was an unplanned Safety system actuation during the month of February 1994 when supervi-sory relay 86B/CPHSS failed, which resulted in a concurrent turbine and reactor trip.

There has been no unplanned safety system actuations in the last 12 months. The 1995 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 31

m Gross Heat Rate

--*-- Year-to-Date Oross Heat Rate l GOOD l

-e-Fort Ca!houn Goal 10.5 -

] f i

~

10.25 so m B

e g

,e m o

,o m _

_g, g

N o

e f

10 - LL y

i ht s

1

?6 f.

(.

cycie is 9.75 -

9 h

f rp g

?

h Ib YS y

y b

l 9.5 I

i 92 93 94 Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun JJ46 GROSS HEAT RATE i

This indicator shows the Gross Heat Rate (GHR) for the reporting month, the year-to-date GHR, the goals and the year-end GHR for the previous three years.

i The gross heat rate for Fort Calhoun Station was 10,427 for the month of July 1995. The 1995 year-to-date GHR was 10,224 at the end of the month.

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

The 1995 Fort Calhoun year-end goal for this indicator is $10,157.

Data Source:

Holthaus/Willett (Manager / Source)

Accountability:

Chase /Jaworski Adverse Trend:

None*

32

m Monthly Thermal Performance O 12-Month Average 8

--M-Year-to-Date Average Monthly Thermal Performance Fort Calhoun Goal (99.6%)

IGOODE

--+-- INPO Industry Goal (99.5%)

I

-e-Industry Upper 10% (99.7%)

100 % -

l*

5 5

5 5

5 5

5 5

5 Eid 5

i a

e f

/;

N 99% -

l cyca ts j

98 %

Aug Sep oct Nov Dec Jan Feb Mar Apr May Jun Jul l1994l l1995l THERMAL PERFORMANCE This indicator shows the Thermal Performance Value for the reporting month, the year-to-j date average monthly thermal performance value, the Fort Calhoun goals, the 1995 INPO j

i industry goal and the approximate upper ten percentile value.

The thermal performance value for July 1995 was 99.41. The year-to-date average monthly thermal performance value was 99.4, at the end of the month. The average monthly value for the 12 months from August 1,1994, through July 31,1995, was 99.3%.

The 1995 Fort Calhoun year-end goal for this indicator is a minimum of 99.6%. The 1994 Fort Calhoun goal was a minimum of 99.5%. The 1995 INPO industry goalis 99.5% and the industry upper 10 percentile value is approximately 99.9%.

Data Source:

Jaworski/Shubert Accountability:

Jaworski/Gorence Adverse Trend:

None 33

I

-+- Thermal Output

-e-Fort Calhoun 1495 MW Goal e Tech Spec 1500 MW Limit 1500,>- w w w-u : +

ic-w

<wv ac tv -u e

1 w-e'

+< w1 1499-1498 -

1497 -

a g1496 1495:

O 1494 1493 1492 1 2 3 4 5 6 7 8 9 10111213141516171819202122232425262728293031 4

i DAILY THERMAL OUTPUT The thermal output graph displays the daily operating power level during July 1995, the 1500 thermal megawatt average technical specification limit, and the 1495 thermal mega-watt Fort Calhoun goal.

Data Source:

Holthaus/Willett (Manager / Source)

Accountability:

Chase / Tills Adverse Trend:

None 34

m Number of Equipment Forced outages (Monthly) l lo000l

- *-- Equipment Forced outage RateI1,000 Critical Mrs. (12-Month Interval)

-*-- Fort Calhoun Year-End Goals (0.2)

] f 2

2-E i

F

\\

rg=>

s e s.:

=

0 92 93 94 Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun Jul-96 EQUIPMENT FORCED OUTAGES PER 1,000 CRITICAL HOURS The equipment forced outage rate per 1,000 critical hours for the 12 months from August 1,1994, through July 31,1995, was 0.409. The year-to-date rate per 1,000 critical hours for the months from January through July 1995 was 0.82.

An equipment forced outoge also occurred on February 20,1995, when the plant experi-enced a problem with a control element assembly motor drive and a related smallleak of reactor coolant.

i l

Two equipment forced outages also occurred during May 1995, which were attributable to the component cooling water, which was leaking into the lube oil system of RC-3D reactor coolant pump motor.

The 1995 Fort Calhoun year-end goal for this indicator is a maximum value of 0.20.

Data Source:

Monthly Operations Report & Plant Licensee Event Reports (LERs)

Accontability:

Chase /Jaworski Adverse Trend:

Needs increased Management Attention 35

i i

-e-Component Categories I

--+- Application Categories

-*- Total Categories 18 -

16 14 s,,,-

s 3

mys=

\\

b b

2 0

F94 M A

M J

J A

S O

N D94 J95 F

M A

M J

J95 Errorloperating Action 9.8%

Maintenance /

Action 26.0%

Wear Out/

Aging 61.9%

g other Percent of Total Failures Devices Engr >

ng 4.9%

Design Defect with known failure causes 3.7%

3.7%

During the Past 18-Month CFAR Period COMPONENT FAILURE ANALYSIS REPORT (CFAR)

SUMMARY

The top chart illustrates the number of component categories, application categories and total categories in which the Fort Calhoun Station has significantly higher (1.645 standard deviations) failure rates than the industry failure rates during the past 18-month Component Failure Analysis Report (CFAR) reporting period (from October 1993 through March 1995). Fort Calhoun Station reported a higher failure rate in 5 of the 87 component categories (valves, pumps, motors, etc.)

during the past 18-month CFAR period. The station reported a higher failure rate in 7 of the 173 application categories (main steam stop valves, auxiliary / emergency feedwater pumps, control element drive motors, etc.) during the past 18-month CFAR period.

The pie chart depicts the breakdown by INPO cause categories (see the " Definitions" section of this report for descriptions of these categories) for the 81 failure reports with known failure causes that were submitted to INPO by Fort Calhoun Station during the past 18-month CFAR period.

The pie chart reflects known failure causes. A total of 99 failure reports were submitted to INPO during the past 18-month CFAR period.

Data Source:

Jaworski/ Frank (Manager / Source)

Accountability:

Jaworski/ Dowdy Adverse Trend:

None 36

m_

f l

-+-- Components with more than one Failure l GOOD l

- *- components with more than Two Failures 15 --

10 -

8 8

8 8

5 6-4 4

4 i

3 a

a i

1 h

h 0

Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun Jul

[

11a41 11a51 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 Regu-latory 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 com-ponent failures using the Nuclear Plant Reliability Data System (NPRDS).

i This indicator shows the number of NPRDS components with more than one failure during the 18-month Component Failure Analysis Report (CFAR) period and the number of NPRDS components with more than two failures during the 18-month CFAR period.

During the last 18-month CFAR period, there were 3 NPRDS components with more than one failure. None of these 3 had more than two failures. The tag numbers of the compo-nents with more than one failure are: Component Cooling Water Heat Exchanger AC-1 B Raw Water Outlet Valve Operator HCV-2881 B-0, Safety injection Tank "D" Level Channel (narrow range) Power Supply LQ-2964Y and Pressurizer Spray Line Check Valve RC-374. Recommendations and actions to correct these repeat failures are listed in the biannual CFAR.

Data Source:

Jaworski/ Frank (Manager / Source)

Accountability:

Chase Artverse Trend:

None 37 l

m

]

i Radioactive Waste Buried This M onth (cu.ft.)

-e-- Year-to Date Cumulative Radioactive Waste Buried l GOOD l

+ Fort Calhoun Goal (900 cu.ft.)

Y 900..

e r.,

c e

c o

i 800.-

f 700.-

600..

]500 _ o o

o o-e u.

I g400.

300 --

4 1

200-.

100 -

1 0

Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun Jul l1994l l1996l 1

VOLUME OF LOW-LEVEL SOLID RADIOACTIVE WASTE This indicator shows the volume of the monthly radioactive waste buried, the cumula-tive year-to-date radioactive waste buried, the Fort Calhoun and INPO goals, and the j

approximately industry upper 10%.

Cu.Ft.

Amount of solid radwaste shipped off-site for processing during current month 1,040 Volume of solid radwaste buried during current month 0

Cumulative volume of solid radioactive waste buried in 1995 0

Amount of solid radwaste in temporary storage 0

4 j

The 1995 Fort Calhoun goal for the volume of solid radioactive waste (buried) is 900 cubic feet. The 1995 INPO industry goal is 110 cubic meters (3,884 cubic feet) per year. The industry upper ten percentile value is approximately 27.33 cubic meters (965.3 cubic feet) i per year.

Data Source:

Chase /Breuer(Manager / Source)

Accountability:

Chase /Lovett Adverse Trend:

None SEP54 1

38 1

5

l 1

1

y.. Primary System Chemistry Percent of Hours Out of Limit l GOOD l Fort Calhoun Goal (0.02) 2% - - C W

3 J!

g f

!,9

'; I e

s 1%

!a

--'ycle 16 C

l Refueling l.l!

i omoe flp kh i

0%

Aug sep Oct Nov Dec Jan Feb Mar Apr May Jun Jul i

l1994l l1995l PRIMARY SYSTEM CHEMISTRY PERCENT OF HOURS OUT OF LIMIT l

The Primary System Chemistry Percent of Hours Out of Limit indicator tracks the primary j

system chemistry performance by monitoring 6 key chemistry parameters. The key pa-rameters are: lithium, dissolved oxygen, chlorides, flouride, hydrogen and syspended sol-ids. 100% equates to all 6 parameters being out of limit for the month.

The Primary System Chemistry Percent of Hours Out of Specification was 0.0% for the month of July 1995.

The 1995 Fort Calhoun monthly goal for this indicator is a maximum of 2% hours our of limit.

Data Source:

Smith / Spires (Manager / Source)

Accountability:

Chase / Smith Positive Trend 39

EBIB Secondary System CPI

--e-12-Month Average l GOOD l

-*-- Fort Calhoun Goal (1.4) 1.6 -

1.s -

)

1.4 -

m 1

Jan Feb Mar Apr May Jun Jul Aug sep Oct Nov Dec l1995l 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 July 1995 was 1.51. The 12-month average CPI value was 1.21 at the end of the month.

The Chemistry Performance Index (CPI) is above the goal due to slightly higher than average sodium and chloride values for July. Also the valves provided as industry aver-ages by INPO for 1995 are considerably lower than FCS historically has been able to achieve for secondary chemistry values. Iron, the one industry average that we are be-Iow, almost by half, does not assist in lowering the CPI because of the way the CPI is calculated.

The 1995 Fort Calhoun monthly goal for the CPI is a maximum value of 1.40.

Data Source:

Smith / Spires (Manager / Source)

Accountability:

Chase / Smith Adverse Trend:

None 40

l i

i l

i l

4.

l COST L

Goal: Operate Fort Calhoun Station in a manner that l

cost effectively maintains nuclear generation as an eco-nomically viable contribution to OPPD's bottom line.

Cost consciousness is exhibited at all levels of the or-l ganization.

L i

)*

1 41 t

I 1

-+- Actual Revised Budget Original Budget

~*- Plan

,e 4

3.75 -

3.5-3.25

\\

u 2.75 -

'g

/g 2.5 -

\\l 2.25 2

D91 D92 D93 D94 J95 F M

A M

J J

A S

O N D95 D96 D97 D98 D99 Months CENTS PER KILOWATT HOUR The purpose of this indicator is to quantify the economical operation of Fort Calhoun Station.

The cents per kilowatt hour indicator represents the budget and actual cents per kilowatt hour on a 12-month rolling average for the current year. The basis for the budget curve is the approved 1994 and 1995 revised budgets. The basis for the actual curve is the Finan-cial and Operating Report.

The December 31 amounts are also shown for the prior years 1992,1993 and 1994. In addition, the report shows the plan amounts for the years 1996 through 1999 for refer-ence. The basis for the dollars are the Nuclear Long Range Financial Plan and the 1995 Corporate Planning and Budget Review. The basis for the generation is provided by Nuclear Fuels.

The unit price (3.01 cents per kilowatt hour for June 1995) averaged lower than budget due to expenses being below budget while generation exceeded the budget. The Unit Price for the current month (July 1995) is not available at this time.

Data Source:

Scofield/Jamieson (Manager / Source)

Accountability:

Scofield Positive Trend due to performance better than goal 42

5 Nuclear Services Olvision U Production Engineering Division EN r o rations Division not m

m m

m m

800 -

i i

i e

i e

i i

i Jar. 92 Jan43 Jan-04 Apr44 Jul44 Oct44 Dec44 Mar 45 Jun4s l Actual stamng Level l l

STAFFING LEVEL l

The actual staffing levels for the three Nuclear Divisions are shown on the graph above.

l The authorized staffing levels for 1995 and 1996 are:

Authorized Staffing i

1995.1_99Q 440 432 Nuclear Operations Division l

l' 181 175 Production Engineering Division 114 113 Nuclear Services Division 735 720 Total l

i Data Source:

Ponec/Kobunski

)

Accountability:

Ponec Adverse Trend:

None SEP 24 43 i

\\

i i

l

+ Spare Parts inventory Value ($ Million) 16.6 -

t 16.6 '

16.4 -

i i

I I

f16.2

.h i

!iE 4

16 -

t 15.6-15.6 Aug sep Oct Nov Dec Jan Feb Mar Apr May Jun Jul l1994l l1995l Spare Parts inventory Value The spare parts inventory value at the Fort Calhoun Station at the end of July 1995 was reported as $15,925,201.

Data Source:

Steele/Huliska(Manager / Source)

Accountability:

Willrett/McCormick Adverse Trend:

None 44

4 i

i i

1 i

l

!c.

l DIVISION AND i

l DEPARTMENT PERFORMANCE i

l INDICATORS l

1 Goal: Achieve high standards at Fort Calhoun Station l

resulting in safe, reliable and cost effective power pro-l duction.

l i.

i 45 l

1 e

Corrective Maintenance m Preventive Maintenance Non-Corrective /Plantimprovements -*- Fort Calhoun Goal

=

i 10e0 -

t Au Sep oct Nov Dec Jan Feb Mar Apr May Jun lNon-Outage Maintenance Work Order Backlog l l

5 MWos Which Exceed Maintenance Completion Goals D Total MWos 500 --

[

oo -

100 --

s,s a.,,,,,

w,,,...,

E=E j

Priority 1 Priority 2 Priority.

Priority 4 Priority 5 Priority 6 i

lNon Outage Maintenance Work Order Backlog l MAINTENANCE WORKLOAD BACKLOGS This indicator shows the backlog of non-outage Maintenance Work Orders remaining open at the i

and of the reporting month. It also includes a breakdown by maintenance classification and i

priority. The 1995 goal for this indicator is 400 non-outage corrective maintenance MWOs. To j

ensure that the MWO backlog is worked in a timely manner, non-outage maintenance completion j

goals have been established as follows:

l 9.9.d l

Priority i Emergency N/A Priority 2 Immediate Action 2 days Priority 3 Operations Concem 14 days j

Priority 4 Essential Corrective 90 days l

Priority 5 Non-Essential Corrective 180 days Priority 6 Non-Corrective / Plant improvements N/A

!i improvements in the maintenance planning and scheduling process will allow more timely re-sponses to maintenance work requests implementation is scheduled for 8/25/95.

j This indicator is considered an adverse trend. An action plan has been established to identify l

problem areas and reduce the backlog.

Data Source:

Chase /Schmitz (Manager / Source)

- Accountability:

Chase /Faulhaber Adverse Trend SEP 36 46 l

l

Ratio of Preventive to Total Maintenance l 100 % -

90% -

80% -

70% -

~

hh l

~

l 50% -

f BJR E

M G

E Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun Jul l1994l l1995l MER Preventive Maintenance items Overdue

-e-- Fort Calhoun Goal 2%

l f 5

1%

B C

^

O O

O O

O 3

)

^

0%

+

Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun Jul l1994l l1995l 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 was 73.27% for the month of July 1995.

The lower graph shows the percentage of scheduled preventive maintenance items that cre overdue. During July 1995,242 PM items were completed. One of these PM items was not completed within the allowable grace period or were administratively closed.

The 1995 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/Melstad (Manager / Sources)

Adverse Trend:

None SEP 41 47

ElEB Rework as identified by craft

-e-Fort Calhoun Goal (<3%)

6%

5% -

1 Y

8

3 4% -

8 I

g ses 5 3%.

0 0

o t

'a no Q

p h

Od if

t 8

j;)

~

E 2%

rs v:

in f

1%

1 2

J Q) ll l 2

M l

hi%

e M

$8 u

Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct d

linsj PERCENTAGE OF TOTAL MWOs COMPLETED PER MONTH IDENTIFIED AS REWORK This graph indicates the percentage of total MWOs completed per month identified as rework. Rework activities are identified by maintenance planning and craft.

This indicator is calculated from the 15th to the 15th of each month due to delay in closing open MWO's at the end of each month.

The Fort Calhoun monthly goal for this indicator is <3%.

t Data Source:

Faulhaber/Schmitz (Manager / Source)

Accountability:

Chase /Faulhaber Adverse Trend:

None 48

l l

i m MaintenanceOvertime

-N-- 12-Month Average Maintenance Overtime l Goop l

-*- Fort Calhoun "On-Une" Goal (10%)

0A5-q y 0A -

0.35 -

0.3-0.25 -

0.2-a I

0.15 -

0.1

)

0.05 -

M g

{.-

L' T.

Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun Jul l1994l l1995l l

MAINTENANCE OVERTIME I

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

The percent of overtime hours with respect to normal hours was reported as 4.0% for the month of July 1995. The 12-month average percentage of overtime hours with respect to normal hours was reported as 12.26% at the end of the month.

The 1995 Fort Calhoun monthly "on-line" goal for this indicator is a maximum value of 10%.

Data Source:

Chase /Schmitz (Manager / Source)

Accountability:

Chase /Faulhaber Adverse Trend:

None 49

T i

i l

t Human Performance irs (Maintenance) i H-gg.

I 16 -

14 -

12 -

i 10 -

t i

li l

$*~

6-4..

i 1

2-l 4

0 I

I I

I i

i Jul-95 Aug Sep Oct Nov Dec-95 PROCEDURAL NONCOMPLIANCE INCIDENTS (MAINTENANCE)

This indicator shows the number of human performance irs related to procedural non-compliance incidents assigned to the Maintenance Department.

2 There was 10 human performance related irs assigned to the maintenance functional area in July 1995.

5 3

)

Data Source:Faulhaber Accountability:

Chase /Faulhaber Adverse Trend:

None 50 i

l

i 4

IIEllB Completed Scheduled Activities (All Crafts) Fort Calhoun Goal (85%)

100.0 % -

90.0 %

c e

o 80.0% -

> 70.0% -

h g 60.0% -

s 1

] 50.0% -

an on g

1

• 0%

\\

}

2 g 30.0% -

20.0% --

10.0% -

l 0.0%

' ~

Jun-95 Jul-95 Aug-95 Sep-95 Oct-90 Nov-95 Dec-95 DAILY SCHEDULE PERFORMANCE PERCENT OF SCHEDULED ACTIVITIES COMPLETED This indicator shows the percent of Integrated Plant Schedule activities completed on schedule. Allwork groups and activities are included. Measurement of daily performance was initiated in June.

The Plant Manager has established schedule performance as a high priority. Daily schedule performance is discussed at the 7:15 A.M. and 12:30 P.M. plant meetings. Weekly cri-tique meetings will be held to identify problem areas.

The 1995 Fort Calhoun monthly goal for completed scheduled maintenance activities is 85%.

Data Source:

Chase /Schmitz (Manager / Source)

Accountability:

Chase /Faulhaber Adverse Trend:

None SEP 33 51

i

% of Hours the in-4.ine Chemistry instruments are Inoperable

+ 1995 Fort Calhoun Goal (10%)

te% -

f 14% -

12% -

10% -

8% -

E ll s i m u l

.I Ill H

+

0%

1 I

i I

I I

I I

I I

I Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun Jul d

l1995l lN-LINE CHEMISTRY INSTRUMENTS OUT-OF-SERVICE i

This indicator shows the percentage of hours the in-line chemi. fry system instruments are inoperable for the reporting month. The chemistry systems involved in this indicator include the Secondary System and the Post Accident Sampling System (PASS).

At the end of July 1996, the percentage of hours the in-line chemistry system instruments were inoperable was 18.2%. The following instruments were out of service during the month of July 1995:

• CD-1582A - B Cation Bed Conductivity i

+ YE-1535 - Primary Water Storage Tank Dearated Dissolved Oxygen l

l

'Ihe in-line instrument indicator is above the goal because of four Martek instruments that are out of service long I

term due to age and parts availability. In addition eight instruments at the AI-125 panel are out of service due to an annunciator malfunction.

The entire instrument channel is considered inoperative if; 1) the instrument is inoperative, 2) the chart

[

recorder associated with the instrument is inoperative, or 3) the alarm function associated with the instru-ment is inoperative. if any of the functions listed above are not operational, then the instrument is not performing itsintended function.

The 1995 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, "The out of-service instruments have been consistently between 4 and 8%. As was stated above, this month's performance was higher than the goal due primarily to a single failure on Al-125, causing a substan-tial number of out-of-service instruments. Given the previous month's indicators, it was concluded that the trend was none though, by definition, need's increased management attention.

Data Source:

Chase /Reneaud (Manager / Source)

Accountability:

Chase /Jaworski Adverse Trend:

None*

52 m

m Waste Produced Each Month (Kilograms)

+ Monthly Average Waste Produced During the last 12 Months (Kilograms)

-*- Fort Calhoun Monthly Average Goal (150 kilograms)

-M-- Federal & State Monthly Limit (Max. of 1,000 kg) 1000 =

x x

x x

x x

x x

x x

x

. goo 600 --

1 X: 400 -

m g-M.

ll:

~

c O

y 2

2 2

_7 e

y Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun Jul l1994l 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 wast produced during the last 12 months. This hazardous waste consists of non-halogenated hazardous waste, halogenated hazardous waste, and other hazardous waste produced.

During the month of July 1995,0.0 kilograms of non-halogenated,0.0 kilograms of halo-genated and 0.0 kilograms of other hazardous waste was produced. The total hazardous waste produced during the last 12 months is 654.1 kilograms.

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

j The 1995 Fort Calhoun monthly average goal for hazardous waste produced is a maxi-mum of 150 kilograms.

Data Source:

Chase /Carlson (Manager / Source)

Accountability:

Chase / Smith Positive Trend 53

EEE Contaminated Radiabon ControNed Area lNl Fort Calhoun Goal (10%)

irk -

c o

n s

ys -

.I 4

i

^:ii F4 Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun Jul d

d CONTAMINATED RADIATION CONTROLLED AREA This indicator shows the percentage of the RCA that is contaminated based on the total square footage. The 1995 monthly non-outage goalis a maximum of 9.5% contaminated RCA.

At the end of July 1995, the percentage of the total square footage of the RCA that was contaminated was 9.4%.

Data Source:

Chase /Gundal(Manager / Source)

Accountability:

Chase /Lovett Positive Trend SEP 54 54

+ Identified PRWPs (Year to Date) l GOOD l

+ Fort Calhoun Goal (<20) 20 :

O C

0 2

2 2

2 2

2

=

18 -

i j

6-14

,4

~

13 13 g,

12 E 12 -

1 10 -

8 6

4 4-2 a

1 0

Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec l1994l RADIOLOGICAL WORK PRACTICES PROGRAM The Radiological Work Practices Program Indicator shows the number of Poor Radiologi-cal Work Practices (PRWPs) which were identified during the reporting month.

The number of PRWPs which are identified each month should indirectly provide a means to qualitatively assess supervisor accountability for their workers' radiological performance.

During the month of July 1995, there weru 0 PRWPs identified.

There have have 14 PRWPs in 1995.

The 1995 year-end goal for PRWPs is a maximum of 20.

Data Source:

Chase /Cartwright (Manager / Source) i Accountability:

Chase /Lovett i

Adverse Trend:

None SEP 52 55 d

O Documents Scheduled for Review A Documents Reviewed W Documents Overdue 350 -

l

)

300 -

j, 1

250

)'

200 -

l i

I

~

i 150 -

0 Aug sep Oct Nov Dec Jan Feb Mar Apr May Jun Jul j

l1994l l1995l 1

i DOCUMENT REVIEW i

i This indicator shows the number of completed, scheduled, and overdue (greater than 6 l

months past the scheduled due date) biennial reviews for the reporting month. These i

document reviews are performed in-house and include Special Procedures, the Site Se-l curity Plan, Maintenance Procedures, Preventive Maintenance Procedures, and the Op-erating Manual.

l During' July 1995, there were 156 document reviews scheduled, while 60 reviews were j

completed. At the end of the month, there were 5 document reviews more than 6 months overdue. There were 5 new documents initiated during July.

I l

Data Source:

Chase /Plath Accountability:

Chase /Jaworski Adverse Trend:

None 56 d

L

=

r

n. -,

i B System Failures l GOOD l D Non-System Failures I f 35 -

30 -

25 -

n n

20 1e 17 17 15 -

4 4

^

=

0 Aug Sep oct Nov Dec Jan Feb Mar Apr May Jun Jul l1994l l1995l LOGGABLE/ REPORTABLE INCIDENTS (SECURITY)

This graph shows the Loggable/ Reportable incidents (Security) Indicator and depicts (1)

)

the total number of loggable/ reportable incidents concerning system failures which oc-curred during the reporting month, and (2) the total number of loggable/ reportable inci-l dents non-system failures concerning Security Badges, Access Control and Authoriza-tion, Security Force Error, and Unsecured Doors.

l During the month of July 1995, there were 21 loggable/ reportable incidents identified j

I compcred to 17 for the previous month. System failures accounted for 19 (90%) of the loggable/repo' table incidents. One (1) microwave zone, the security building X-ray ma-chine and metal detector, accounted for thirteen (13) of the loggable system failures.

There were also two unplanned security system computer failures during this reporting period. The non-system failures were a result of two (2) security force errors.

I Data Source:

Sefick/Woerner(Manager / Source)

Accountability:

Sefick Adverse Trend:

None 57 I

a Temporary Modifications >1 cycle old (RFO required for removal) m Temporary Modifications >6 months old (Removable on-line)

+ Fort Calhoun Goals for >1-cycle and >6 months old Jan Feb Mar Apr May Jun Jul Aug sep (bt Nov Ibc 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 tem-porary modifications removable on-line that are greater than six months old. The 1995 Fort Calhoun monthly goals for this indicator are zero. However, one temporary modifica-tion (BAST level indication) has been approved by management to exceed these goals due to cost effectiveness considerations (reference PED-STE-94-042).

There is currently 1 temporary modification that is greater than one-fuel cycle old requiring a refueling outage to remove: RC-3D cover gasket pressure indicator, which is awaiting completion of MWO 941450, which is scheduled for a future refueling outage whenever cover gaskets are replaced. In addition, at the end of July 1996, there were 6 temporary modifications installed that were greater than six months old that can be removed on-line.

These were: 1) Local indication for BAST CH-11 A and CH-118, in which Licensing sent FLC 94-001 to the NRC 6/27/95 for approval; 2) Control system for intensifier on HCV-2987, which is awaiting completion of ECN 94-280, scheduled for completion 8/95; 3) brace to IA header "T" to water plant, which is awaiting completion of ECN 94-482, sched-uled for issue from DEN-Mechanical 8/25/95; 4) braces on main instrument air header, which is awaiting completion of ECN 94-482, scheduled for issue from DEN-Mechanical 8/25/95; 5) intake raw water securiity cage, which is awaiting completion of ECN 94-454, scheduled for completion 8/95; and 6) sleeving of HCV-403F connecting rod, which is awaiting completion of MWO 943620, scheduled completion date 10/15/95.

At the end of July 1995, there was a total of 19 TMs installed in the Fort Calhoun Station.

6 of the 19 installed TMs require an outage for removal and 13 are removable on-line. In 1995, a total of 23 temporary modifications have been installed.

Data Source:

- Jaworski/ Turner (Manager / Source)

Accountability:

Jaworski/Gorence Trend:

Needs Increased Management Attention SEP 62 & 71 58 I

b 4

i m Total Modification Packages ope i

--*-- Fort Calleoun Year-End Goal j

4 140 -

i 120 -

j 100 -

l n

go.

n u

o g

j so -

a u

./

J 9

j

.y 1

i 40 L,

y i

'E I

M/:

?

l t'-

20 -

~:

0

~

j._

q Q

fy n

.J u

l 92 93 94 Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun Jul-95 OUTSTANDING MODIFICATIONS 1

i i

This indicator shows the total number of outstanding modifications (excludino outstandina modi-

]

fications which are proposed to be cancelledt i

Reporting i

Cateoorv

'93

'94

'95

'96

'97

'98 Month s

Form FC-1133 Backlog /In Progress 0

0 0

0 0

0 0

Mod, Requests Being Reviewed 0

0 1

0 0

0 1

Design Engr. Backlog /in Progress 0

0 2

25 1

7 35 Construction Backlog /In Progress 5

3 24 2

0

')

34 Design Engr. Update Backlog /in Progress 1

4 3

0 0

0 8

l

{

Totals 6

7 30 27 1

7 78

]

(out*9e + onune)

(3+3)

(o+7) (19+11) (1s+9) (o+1) (7+o)

(47+31)

At the end of July 1995,12 additional modification requests had been issued this year and 5 modification requests had been cancelled. The Nuclear Projects Review Committee (NPRC) had completed 39 backlog modification request reviews this year. The Nuclear Projects Committee (NPC) had completed 4 backlog modification request reviews this year.

• A review of the reports used to determine the total number of outstanding modifications and their various stages of accomplishment was undertaken at the request of the Nuclear Planning De-partment. The results of the review determined that the reports were not providing complete /

cccurate data. The reports have been corrected. The revised totals beginning with the March 1995 data are reflected in the current graph.

The 1995 year-end Fort Calhoun goal for this indicator is a maximum of 63 outstanrEng modifica-i tions.

{

Data Source:

Skiles/Ronne (Manager / Source)

Scofield/Lounsberry (Manager / Source)

Accountability:

Scofield/Phelps i

Adverse Trend *:

None i

4 59

80 -

EARS Requiring Engineerh:3 Closeout - Not in Closcout M'

N SE O DS! ;

~

40 20 -

i O

C'"

U'U U

B 0

May Jun Jul May Jun Jul May Jun Jul May Jun Jul 0-3 Months 3-8 Months 6-12 Months

>12 Months July 1995 Overdue EARS O Engineering Response N Closeout (SE) 80 -

60 -

I A

IEEIBE4 Priority 0 Priority 1 Priority 2 Priority 3 Priority 4 Priority 5 Priority 6 100 -

A R B-i J

Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun Jul

{

1994 1995 29EARson 72 overdue 99 EARS 75 EARS um P penses

~

Roepering Resolved en 17 %

42.1%

Response

en Closeout

$$.1"-

43.9 %

g h=_.__:.=.___

b1 siihi wed i-

% 70 overdue

-es._

====._

==

m._.

y===

40.9 %

ENGINEERING ASSISTANCE REQUEST BREAKDOWN This indicator shows a breakdown of the number of EARS assigned to Design Engineer-ing and System Engineering. The 1995 year-end goal for this indicator is a maximum of 140 outstanding EARS.

Total EAR breakdown is as follows:

t EARS opened during the month 12 EARS closed during the month 13 Total EARS open at the end of the month 171 Data Source:

Skiles/ Parsons (Manager / Source)

Accountability:

Jaworski/Skiles l

Adverse Trend:

None SEP 62 60

i DEN = 167

>4 Mott1hs =

o 3 Months

• Clos.out = 146 284%

231 til 28.6%

41.

1%

sy, eu,r..

Procur.a.ni u monei. -

c.n.v.-iso 106 I

20.0%

l.

ECN Status -Overall Backlog

$8 m 7'

l D Backlogged O Received a Congleted

>e u

. s2

1. 7%

n,%

i.

2no.

167 167

,,3 gy

,47

• ~

I "a no

'E. h H M=*=

27 d

17.2%

Fet>45 Mar Apr May Jme

.hA45 Design Engineering o.s manow.

m-

,,m,,,,,,

'e too -

u 160 -

~

I 5

I so.

E s= "

E i

t au 5

E nn O

^

~ M "EfI '

Feb46 Mar Apr May June Jul-06 2s.n i

System Engineering zuo -

Sa

= sa

>s monum = 7s 200 -.

its

$a 47.es 1

150 -

I J

i i

5 e

a z

w e

s i

~

? *t 5

5 i

1 T

1

~

d ",4

[

M

} 21 to

q is 23 i N gto 5

5 5T 5

- 5 u mano.

0 31 l

Febe5 Mar Apr May June Jul45 1sA%

Procurement / Construction

.... er n os e.a..

oo.

f 489%

l50 -

ses

\\,-

m 5

8 x

~

h b

h5 8'

so -

3,,,n i

e,,G 3 9 i-E it '3 3

u..

Feb45 Mar Apr May June Jul46 22 15.1%

Draftina/ Closeout ENGINEERING CHANGE NOTICE STATUS Data Source:

Skiles/ Parsons (Manager / Source)

Accountability:

Skiles/Jaworski Adverse Trend:

None SEP 62 61 1

1

Priority 5 &

Priority 1 &

Dc Type = se rc type.1er 4 = 114 2 = 110 t 3%

san lll 11llll l

l 11111111 11 1111111 Priority 3 &

4 m,typ,,

4 =325 esM es.4%

,m' i

Total Open ECNs by Type (562 Total)

Total Open ECNs by Priority (552 Total)

D DEN -Clooeout or Drafthy Not Complete Priorities

)

5 Maintenance / Construction / Procurement. Work Not Complete -

Prioritiea 1AI E System Engineering Response, Confirmation Not Complete s&g 15.8%

E DEN. E.n.__ _ d., Not Complete 18.7 %

j 200-em ut 0

i i

t i

i PriorNes Feb46 Mar Apr May Jun Jul48 3&4 85.8%

Facility Change ECNs Open l

M' see Priortues priortges

,,7 300 -

5&6 1&2 280 -

es tot 13.5%

26.9%

e,,,117l'u'uluuuuu m

200 -

s.

v RWW!E Feb46 Mar Apr May Jun Jul-95 Prioriges 3&4 Substitute Replacement item ECNs Open 89.8 %

l Priorities 160 g.,

1&2 140 1.6%

l 120 st 81 7

l Feb46 Mar Apr May Jun Jul46 5 S l

Document Change ECNs Open 57.3%

ENGINEERING CHANGE NOTICES OPEN Data Source:

Skiles/ Parsons (Marager/ Source)

Accountability:

Skiles/Jaworski Adverse Trend:

None SEP 62 62

O Administrative Control Problem W Licensed Operator Error E Other Personnel Error 5 Maintenance Problem O Design / Construction / Installation /Fabriation Problem E Equipment Failures 2-d 1

j l

l i

0 Jul Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun Im41 Im51 LICENSEE EVENT REPORT (LER) ROOT CAUSE BREAKDOWN i

This indicator shows the LERs by event date broken down by Root Cause Code for each of the past twelve months from July 1,1994, through June 30,1995. To be consistent with the Preventable / Personnel Error LERs indicator, this indicator is reported by the LER cvent date, as opposed to the LER report date.

The cause codes are intended to identify possible programmatic deficiencies. For de-tailed descriptions of these codes, see the " Performance Indicator Definitions" section of this report.

There were no events in June 1995 that resulted in an LER.

i J

Data Source:

Trausch/Cavanaugh (Manager / Source)

Accountability:

Chase Adverse Trend:

None 63

i O Total Requalification Training Hours I

e 8emulatorTraining Hours E Non Requalification Training Hours e Number of Exam Failures i

n n

n 35 8 3(g 35 -

g 30 t

30 -

2s i

N.

l 20 -

7 l

5 g

2 11.5 g

i 10 "

10 -

.5 5

5 6

5-3 33 3

15 3

Og0 0

0 0-1 I-I I

I-I I

Cycle Cycle Cycle Cycle Cycle Cycle Cycle Cycle 94 4*

S45 944 94-7 95-1 95-2 95 3 95 4

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

" Note 2: Includes 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> 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 APO/EOP verification & validation, INPO commitments, GET, Fire Brigade, Safety Meetings, and Division Manager lunches.

Exam failures are defined as failures in the written, simulator, and Job Performance Measures (JPMs) segments of the Licensed Operator Requalification Training.

There were three (3) written exam failures during rotation 95-4. All individuals were remediated without impacting the operations schedule.

Data Source:

Gasper /Guliani(Manager / Source)

Accountability:

Gasper /Guliani Adverse Trend:

None SEP 68 64

A SRO Exams Administered O sRO Exams Passed D Ro Exams Administered B Ro Exams Passed 20

j

=

l 15 -

?

?

?

4 10 -

s 0

4 E

5 3

-n n

i i

i

==

a

=

S l

9 i

5-g M

5

)

e i

i i

i i

s

=

O Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun Jul l1994l l1995l LICENSE CANDIDATE EXAMS This indicator shows the number of Senior Reactor Operator (SRO) and Reactor Operator (RO) quizzes and exams taken and passed each month. These internally administered quizzes and exams are used to plot the SRO and RO candidates' monthly progress.

For the month of July 1995,4 RO and 4 SRO exam l nations were administered. All candidates passed their exams.

Data Source:

Gasper /Guliani(Manager / Source)

Accountability:

Gasper /Guliani Adverse Trend:

None SEP 68 65

MilB Open irs >6 Months Old C Open significantIRs

-+- Total Open irs 600 -

500-300-228 231 171 170 tri 163 l

148 143 j

l l

g

}

W M

W l

l' l

gg "j,

100 -

p rs g

l 72 7

74 is l

7, o

~

l j

l 0

Aug sep Oct Nov Dec Jan Feb Mar Apr May Jun Jul l1995l OPEN INCIDENT REPORTS This indicator shows the total number of Open irs, irs greater than 6 months old, and the number of open significant irs.

Also, at the end of July 1995, there were 481 open irs.171 of these IRS were greater than 6 months old. There were 100 Open Significant irs at the end of the month. These numbers have been restated to reflect the elimination of CARS from the system. As of April 21,1995, CARS are no longer being issued. All future corrective actions will be documented on irs.

Data Source:

Conner /Plott (Manager / Source)

Accountability:

Andrewc!Phe@s/Patterson Adverse Trend :

None 66

l i

1 O

]

Data for the 1996 Refueling Outage will not be available until the summer of 1995.

i MWO PLANNING STATUS (CYCLE 16 REFUELING OUTAGE)

This indicator shows the total number of Maintenance Work Requests (MWRs) and Main-tonance Work Orders (MWOs) that have been approved for inclusion in the Cycle 16 Refueling Outage. This graph indicates:

- Parts Holds (Part hold removed when parts are staged and ready to use) i

- Engineering Holds (Engineering hold removed when appropriate engineering paper work or support is received for the package) t

- Planning Holds (Planning hold removed when planning is completed to the point when package is ready or other support is necessary to continue the planning process) i 4

- Planning Complete (status given when only items keeping thejob from being ready to work are parts or engineering tapport)

)

- Ready (status when all planning, supporting documentation, and parts are ready to go) 1 Data Source:

Chase /Schmitz Accountability:

Chase /Faulhaber Adverse Trend:

None 67

l

-+- Baseline Schedule for PRC Approval

-m-Projected / Actual Schedule for PRC Approval Total Modification Packages (18)(4 Added Late,3 review for Cancel)

_s h

as-2 1f7 6-

a. d 5-g ll' ~

2-0

!f!$f.

!;!!$h e !!fs gI s'.

s ss j

PROGRESS OF CYCLE 17 OUTAGE (1996 OUTAGE MODIFICATION PLANNING)

~

(FROZEN SCOPE OF 9 MODIFICATIONS)

This indicator shows the status of Modifications approved for installation during the Cycle 17 Refueling Outage. Modifications added to the outage list after May 1,1995, are not part of this indicator. The data is represented with respect to the baseline schedule (es-tablished June 16,1995) and the current schedule. This information is taken from the modification variation report produced by Design Engineering Nuclear.

~

The goal for this indicator is to have all modification packages identified prior to May 1, 1995 PRC approved by March 22,1995. 4 Modifications added after May 1,1995, not included.

July 1995 Modifications added: 0 Deleted = 1 FC86-039 moved to '98 outage.

Data Source:

Skiles/Ronne (Manager / Source)

Accountability:

Phelps/Skiles Adverse Trend:

None SEP 31 68

-+- Baseline Schedule for PRC Approval

-e-Projected / Actual Se.edule for PRC Approal Total Modification Packages (11) (1 is Close Out Only) 12 -

g 10 -

S a-

"g

- :::::/:::::::::::::_ m eo y

8 ShE W

8 f I> 4 -

E si e.

2 0

+-+

EEEEEEElllEEEEE$$EEEEEE

$8S REE SamES8E5a:. E E. G. E G E a

n n 4 s

g g e

PROGRESS OF 1995 ON-LINE MODIFICATION PLANNING (FROZEN SCOPE OF 10 MODIFICATIONS)

This indicator shows the status of modifications approved for on-line installation during 1995. The data is represented with respect to the baseline schedule (established 1/13/

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

The goal for this indicator is to have all modification packages identified prior to 1/13/95 PRC approved by October 30,1995.

July 1995 Modifcations Added: 0 Deleted = 1 FC87-002 cancelled.

Data Source:

Skiles/Ronne (Manager / Source)

Accountability:

Phelps/Skiles Adverse Trend:

None SEP 31 69 l

~

- *-- Baseline Schedule for PRC Approval

-e-Projected / Actual Schedule for PRc Approval Total Modification Packages (9) (2 Added Late,1 review for cancel) 6

^

5-

~

1Jt 4 -

gs.

2-

^: :

1 0

g gg g gg e

m e e e e m e

$ls$$gmssslllfe m m m

$$$$'d M R m ils gegis

$s e

- s s.

PROGRESS OF 1996 ON-LINE MODIFICATION PLANNING (FROZEN SCOPE OF 6 MODIFICATIONS)

This indicator shows the status of modifications approved for on-line installation during 1996. Modifications added to the on-line list after May 1,1995, are not part of this indica-tor. The data is represented with respect to the baseline schedule (established June 16, 1995) and the current schedule. This information is taken from the modification variation

~

report produced by Design Engineering Nv

r.

The goal for this indicator is to have all modification packages identified prior to May 1, 1995 PRC approved by March 25,1996. 2 Modifications added after May 1,1995, not included.

July 1995 Modifications Added: 0 Deleted = 0 Data Source:

Skiles/Ronne (Manager / Source)

Accountability:

Phelps/Skiles Adverse Trend:

None SEP 31 70

4 s

1 4

4 i

k l

i i

1 1

4 1

4 4,

t 4

i f

)j a

l, 1

J l

ACT ON PLANS J

4 I

4 i.

i I

i e

i a

i f

e I

e l

I i

e e

1 e

4 i

(

i I

l I'

71 i

J r

(

F

l

?

ACTION PLANS i

This section lists action plans that have been developed for the performance indicators i

cited as Adverse Trends during the rnonth preceding this report. Also included are Action Plans for indicators that have been cited in the preceding month's report as Needing

~

increased Management Attention for three (3) consecutive months.

In accordance with Revision 3 of NOD-QP-37, the following performance indicators would require action plans based on three (3) consecutive months of performance cited as "Needing increased Management Attention":

. Industrial Safety Accident Rate (page 2)

. Maintenance Workload Backlogs (page 46)

The action plan for Industrial Safety Accident Rate (page 2) is as follows:

REVERSING THE INDUSTRIAL SAFETY ADVERSE TREND Even though the goal of zero lost-time accidents will not be met in 1995, the emphasis on safety and the reporting of potential safety hazards are still high prioirities. The standards for safety will be raised by making the following items part of the station's daily operations:

Promptly resolve safety problems.

Promptly follow-up safety training to supervisors / crew leaders, Use the Near Miss forms to resolve potential safety concerns.

a b

72

i ACTION PLANS (continued)

The action plan for Maintenance Workload Backlogs (page 46) is as follows:

A detailed review is being conducted to determine which stage of the maintenance 3

process has a higher than expected backlog. Areas being reviewed are:

l I

Planning Scheduled Maintenance Bulk Work Package closeout Corrective actions will be initiated based on the results of that review.

The action plan for Temporary Modifications (page 57) is as follows:

The Temporary Modification program needs to have its program goals revised to reflect current NPRC scheduling practices. This will be completed by October 1,1995.

i i

i 4

l f

73

(

)

1 4

PERFORMANCE INDICATOR DEFINITIONS

]

AUxawtY FEEDWATER SYSTEM SAFETY SYSTEM CLEAN CONTROLLED AREA CONTAMWATIONS 11,000 PERFORMANCE DISINTEORATIONS/ MINUTE PER PROSE AREA i

i I

The sum of the imown (planned and unplanned) unevesable The personnel cordaminanon everde h the cimen conkeRed was.

hours and me eselmsted unevetalde hours for the entiary This indicator treeks personnei performanco for 8EP f15 4 54.

foodwater system for the reporting perted dMded by the creical hours for the reporting ported mumpted by the number of trains CONTAh41NATED RADIATION CONTROt.12D AREA in the madnery feedeuter system The pemensage of the Ra$shon ControGed Area, which incdudes COLLECTWE RADIATION EXPOSURE the entery butdlng, the redomets bubding, and erees of the j

C/RP buuding, that le cordeminated bened on the total aquere CatecSeseducenoposureisthe totaledemed L_ r;does foologe This indicator tracks performance for SEP 854.

j received by el on she personnel (inclueng contractors and vtallers) durin0 e time perted, as measured by the DAILY THERMAL OUTPUT j

thermoluminescard doelmster (TLD). Cotochve radiation j

oposise is reported h unts of persorwem. This indicolor tracks This indcator shows the dsHy core thermal output es meneured redological work performance for SEP 854.

from compdor point XC106 (in thermal megewome). The 1500 d

)

MW Tee Spec bre, and the unmut portion of the 1405 MW FCS i

COMPOfENT FAILURE ANALYSIS REPORT (CFAR) deity posi for the reporting month are eleo shown.

SUMMARY

DIESEL OENERATOR RELIABlWTY (25 Demands)

The summary of INPO categortes for Fort Calhoun Stamon with elgrdAcantly higher (1.645 standard devisNons) feture roles then This indicolor shows the number of indures occurring for each l

the rest of the industry for en eigtdoorwnonth time period.

emergency dseel gunandar durtne the lmet 25 start demands end Failures are reported as component (i.e., pumps, motors, mein the last 25 lood-run demands i

eteem stop valves, control elemord motors, etc.) categottes DISABLING INJURY / ILLNESS FREQUENCY RATE j

Fedure Cause Categortes are:

(LOSS TIME ACCIDENT RATE)

Wear OidlAging e fagure thought to be the consequence of This indicator is defined as the number of accidents for es utsty i

eMPoceed weer or aging, personnel permanently sosigned to the station, invoMng days sway from serk per 200,000 mardhours worked (100 man-years).

j Manufacturing Defect a feture attributable to inadequate This does not halude contractor personnel. This indicator tracks eseembly or initial quauty of the C; _

L. component or personnel performance for SEP #25,26 & 27.

l system l

DOCUMENT REVIEW (BIENNLAL) l Enghteeringcesign - a fagure attrtbWeble to the irma.9-e.

}

design of the,_ ;

" component or system The Documart Review indcolor shows the number of documents i

rewtomed, tu msnber of documente scheduled for review, and the Other Devicoe a fagure attributsbie to a feture or number of document reviews that are overdue for the reporting I

s '-

e,, of another component or system, inclueng more. A dommert review is considered overdue if the review is j

a n.,edevloes not complete wthin ok months of the seei ned due date. This 0

indcator tracks perfomance for SEP S46.

l Maintenanceffecting a future that is e result of improper i

mairdenence or lesune, lack of mairdenence, or personnel l

errors that occur durtn0 meintenance or testing actMties EMERGENCY AC POWER SYSTEM SAFETY SYSTEM l

pstormed on the responende component or system, including PERFORMANCE femure to fonow procedures.

i The sum of the known (planned and unplanned) unevetable and Evvers. IsBures auributable to incorrect procedures that were the eenmated unevegetdo hours for the emergency AC power e

j foNowed as written, improper insteustion of equipment, and eyelem for tw reporting period dMded by the number of hours in personnel errors (including Ibbure to famow procedures the reporting perted muniplied by the number of trains in the property). Also included in this category are fenures for which emergency AC power system.

cause le unknown or cannot tu eseigned to any of the I

precedng colegertes i

CENTS PER KS.OWATT HOUR i

The purpose of this indcator is to quantify the economical j

operation of Fort Calhoun Simmon. The cente por kilowatt hour hdcelar represords he budget and actual cents per knowett hcw l

en a heelse<nere merage for the current year. The beeis for the budget curve is me approved yearly budget The basis for the j

estuel curve is tw Financel and Opensting Report.

74 r

i

PERFORMANCE INDICATOR DEFINITIONS EMERGENCY DIESEL GENERATOR UNIT REUA88UTY E) A failure to start because a portion of the eterting system was disabled for test purpose, if fotowed by a succeaeful This indicator shows the number of fouures that were reported start with the etertng system in its normal alignmerd during the last 20, 50, and 100 emergency diesel generator demands et the Fort Calhoun Station. Also shown are trtoper Each emergency generator failure that resues in the generador wiues which correiste to a high level of conAdence that a unirs bein0 decdmed inoperable should be counted as one demand and dieesi generators how obtained a retabety of poster then or one hkse. Emploratory tests during cormcew maintenance and ogJul to 95% oben the demand failures are less then the trig 0er me =-8ut teet that fotows repair to vertry operabally should values.

not be counted as demands or fasures when the EDG has not been deciered operabie again.

1) Nurster of Start Demands: AI valid and inadverterd start i

demands, includlng ad etertenly demands and as etert EMERGENCY DIESEL GENERATOR UNREUABIUTY

)

demands that are fossand by loada demenos, whether by automanc or manuel intiedon A start only demand is a Thle hdoutor maseures me total unrohetelty of emergency diesel demand h which me emergency panorator is eterled, but no generators. In general, unrahmy is the ratio of ur--ful setempt is made to load the generator operauons (starts or lanckuns) to the number of valid demands Total unreliebaty is a combination of etert unrebebNity and lood-

2) Number of Start Failures: Any feture within the run unrelistMty emergency generator system that pmverds the generator tem schleut1g spacined frequency and volte0s is closalfied ENGINEERING ASSISTANCE REQUEST (EAR) as a weld etert imitse. This includes any condition identified BREAKDOWN h the couros of maintenance irar=*ms (with the emergency generator in atendby mode) that donnitely would This indicator shows a breakdown, by a0e and priortly of the have remuned in a start fegure if a demand had occurred EAR, of the number of EARS seeigned to Design Engineertne Nuclear and System Engineering This indicator tracks

3) Number of Lond4 tun Demands: For a valid load 4un perfomience for SEP #62.

demand to be counted the loed<un attempt must meet one or more of the fotoudn0 creeria:

ENGINEERING CHANGE NOTICE (ECN) STATUS A) A lood-run of any durabon that results from a real The number of ECNs that were opened ECNs that were automenc or manuelinihetkn completed, and open bacidag ECNs eweiting complebon by DEN for the reportmg month. This indicalv tracks performance for B) A load-run test to estisfy the pierd's load and duration SEP #62.

i as stated in each tears specificahons ENGINEERING CHANGE NOTICES OPEN l

C) Other special tests in which the emergency generator is expected to be operated for et least one hour whHe Thas indicator breaks down the number of Ergpneering Chan64 loaded with at least 50% of its design loed.

Notces (ECNs) the are assigned to Design Engineering Nucieer j

(DEN), System Engineenng, and Maintenance The graphs 1

4) Nisnber of Load 4 tun Failures: A iced 4un failure should provide data on ECN Facmty Changes open, ECN SubstRute l

be counted for any reason in which the emergency Replacemert items open, and ECN Document Changes open.

ponerolor does not pick up load and run as predicted.

This indicator tracks performance for SEP 062.

Fatures are counted during any valid lood-run demands l

EQUIPMENT FORCED OUTAGES PER 1,000 CRITICAL Ur=-r t ettempts to stort or lood-run HOURS

5) Enceptions u

should not be counted as valid demands or failures when e

EcN pmerd forced outages per 1,000 critical hours is the inverse i

they can be attributed to any of the fonowmg of the mean time between forced outages caused by equipment i,

A) Spurious trips that would be bypeseed in the event of feitures. The moon time is aquel to the number of hours the an emergency.

reactor is crescal h a penod (1,000 hours0 days <br />0 hours <br />0 weeks <br />0 months <br />) dMded by the number of forced outages caused by equipment fouures in that period.

i B) Mulltruman of e:Nipmerd that is not requred during an emergency EQUIVALENT AVAILABluTY FACTOR I

C) Intentoned termination of a test because of abnormal TNs hecator is denned as the rado of groes aveRoble generation i

concAlone tuut would not have resumed in major diesel to groes monimum generation, supressed as a percentage generator damage or repair.

Awegable genershon le me energy that can be produced if the unit l

le operated at the maximum power level permitted by equipmerd l

D) Musisictions or operahng errors which wedd not have and regidatory kntamons. Maximum genershon is the energy that piavented the emergency generator from being can be produced by a unit in a given period if operated j

restarted and t: fought to loed within a few minutes.

conhnuously at maximum capecRy i

n 4

75 i

i

i PERFORMANCE INDICATOR DEFINITIONS I

PORCEo OuTAoE RATE mouSTR AL SArETY AccioENT RATE.np0 l

This indesler is delhed es the percentage of time that Wie unit TNe hdoekr le denned as the number of sociderde per 200,000 wee unevadelde due to forced events compared to the time morWiours wortead for si utsty personnel permanengy eseigned pionned for electriosi generation. Forced overde are feauros or to the station that reeut in any of the fotowing-

)

other unplanned condtlons tiet require removin0 tie unit from servios before the end of the ned weekend. Forced events

1) One or more days of restricted work (esclueng the day of include etert-up istures and events inulated whus the unt le h the accident);

reserve shLedown (i.e., the unit is evenshie but not in service).

2) One or more days seey from work (sucludng the der of the a

j FUEL P8's tasse syy pgl4CATOR eccident); and

}

This hdosteris deked as the steady state primary cooiert 6131

3) Fatesties 4

octMiy, corrected for Die tramp uraniurn conirthubon end nemutsed to e common purtnostion rate. Tramp uranium is fuel Contractor personnel are not included for this hdicator 4

j uNah fue been deposted on reador core intomals from previous defective fuel or is present on the surface of fusi elements from W4.INE CHEMISTRY WSTRUMENTS OUT OF SERVICE i

the ;.rM-;, process Steady state le deAnod as conunuous opendon for et least three doye et a power level that Total number of in-line chemistry instruments that are out-of-does not tery more then + or -6%. Piones should cotect dets for service h Die Secondary System and the Post Accident Sempung Ms hiketor et a power level above 86%, when possible Plants System (PASS).

that did not operate et _-

power etme 86% should collect date for this indicator et the highest steady-etste power LICENSE CANDIDATE EXAMS i

level attained during the rhonth.

1 This hdoster shoes the number of SRO and/or RO quizzes and l

The denety conecten factor is the rado of the spacenc volume of exams that ers administered and poseed each month. This coolant et the RCS operethig temperature (540 degrees F., Vf =

indicator tracks training performance for SEP966.

0.02149) dMded by the speaanc volume of cooiert et normal 4

hedem temperese (120' F et ouget of the letdown cootng heet UCENSED OPERATOR REQUALIFICATION TRAINWG eschenger, vf = 0.016204), which reeuas in a denemy correcuan J

fedor for FCS equel to 1.32.

The tasel number of hours of training given to each crew durin0 each c@. Aino prmided are the simulator trainine hours (which l

OROSS HEAT RATE ere a subset of the total training hours), the number of non-i REQUALIFICATION trainin0 hours and the number of enom Gross host rete is denned es the ratio of totsi thermal energy in istures. This indicator tracks training performance for SEP #66.

Bettish Thermed Unbs (BTU) produced by the reactor to the totet l

9 toes electrical energy produced by the generator in idiowett-hours (KWH).

HAZARDOUS WASTE PftODUCED The total amount (in Kliograms) of nordningensted hazardous i

easte, heingensted hesentous weste, and other hazardous weele produced by FCS each rnenth.

t HIGH PftESSURE SAFETY WJECTION SYSTEM SAFETY SYSTEM PERFORMANCE The sum of v known (pionned and unpienned) unevehbio hours and the seemsted unevenable hours for the high pressure safety tr(edian erstem for the reporting period dMded by the i

cratel hours for the reparung period tre by the numter of trame in the Ngh pressure esfoty Ir(ecuan system i

l l

)

76 l

PERFORMANCE INDICATOR DEFINITIONS 1

I LICENSEE EVENT REPORT (LER) ROOT CAUSE Preventive Actions tehon to meNein a pleos of equipment l

BREAKDOWN wdNn doelen operstm0 concellone, prevent equipmert fedure, and seend as se and me performed prior to equipment sneure.

1his indicator shows the number and root cause code for j

Uoensee Evert Reports. The root cause codes are as fotows:

Non4errocevelPlant improvements Maintenance j

actMeios performed to implemord station Lm._..

._ or to i

4

1) Administrative Centrol Proedom Managemord and repair non.pient equipment i

ogenteory danciencies met arrect piant programs or enemies (l.a., peer planning, breeletown or look of adequate Maintenance Work Priorities are defined as:

managemord or supervisory control, incorrect procedures, e

etc).

Emergency Conditions which signincently degrade sintion enfaty or evadebally 4

2) a w Operator Error TNs oeuse code captures Equipmert danciencies wNoh eners of omimmiendoommission by Scensed roedor operators immedleGe Acuan during plant actMuss signincently degrade station reinbitty Potenhal for unit j

shutdown w power reducson 4

i

3) Other Personnel Error - Errors of ominatorvoommiselon commuted by non4oensed personnel involved h plant Operations Concem - Equipment donciencies which hinder actMeios station opersbort

4) Mehdenence Petdem The hierd of this cause code is to Essential - Routine correcuve meintenance on essential capture the fut range of problems which con be attributed station systems and equipment

]

h any umy to proyammene danciencies in the memtenance funcelonel orpenization. ActMties included in this category Non Essential - Rouune correcove maintenance on non-i l

are mainionence, testin0. survetlance, cellbrebon and essenmal station eyelems and T 3.

radiation protection Plant improvement - Norsorreceve memtenance and plant l

5) rW6abrication Proidem-Improvements This oeuse code covers a ful range of propremmebc l

1 dmaciencias h me mens of design, construction, instadsuon, This indicator tracks maintenance performance for SEP #36.

and Intstmalan (i.e., lose of control power due to underreled j

fuse, equipment not queRRed for the environment, etc.).

MAXIMUM INDAflDUAL RADIATION EXPOSURE i

6) Equipment Failures (Electronic PleWarte or The total medmum amourt of radsbon received by an indMdual EnvemrenantalJtelated Failures) This code is used for person wortdng at FCS on a monthly, quarterly, and annual basis.

l spurtous feMuros of mectronic piece-parte and failures due l

to rrMoorological condibons such as bghtning, ice, high MWO PLANNING STATUS (CYCLE is REFUELING

.I winds, etc. Genersey, t includes spurtous or one time OUTAGE) j Imbnes. Electric components included in tNo category are cerad cente, rectiners, -, fuses, cepecitors, diodes, The total number of Maintenance Work Orders that have boon resistors, etc.

approved for inclusion h the Cycle 16 Refuehn0 Outogs and the nuritier that are ready to work (parts ste0ed, planning complete, LOceAaLEMEPORTABUE INCIDENTS (SECUfUTY) and se adher paperwork ready for Asid use). Also included to the number of MWOs that have been engineering holds (ECNs, The total number of securuy incidents for the reportin0 month procedures and other miscetaneous engineering holds), parts depicted h two graphs. TNs indicator tracks escuray hold, (parts staged, not yet treM parts not yet arrhed) and performance for SEP 858.

plannmG hold (Job ecope not yet completed) Maintenance Work Requests (MWRs) are eleo shown that have been identlRed for

]y MAINTENANCE OVERTIME he Cycle 16 Refueling Outage and have not yet been converted to MWOs.

.a The percert of overtime houre compared to normal hours for i

monsnance. TNs hchases OPPD personnel as wel as contract pasonnet.

4 l

MAnfTENANCE WORKLOAD RACKLOGS This indicator shows the bacidog of non outage Maintenance Work Orders remaining open et the end of the reporung monm.

1 Maintenance aimesincemons are deaned as fonows:

l Correceve - Repair and restorebon of equipment or componeres that have lated or are malfunceoning and are not performing their intended functon.

77

PERFORMANCE INDICATOR DEFINITIONS 1

NUMBER OF CONTROL RDOM EQUIPMEWT DEFICIPNCES 2) aman,=% Requests Being Rev6ewed. TNs ostegory includes A oorerol room equipment deAoiency (CRD) is deAned as any compenard wNon is operated er controsed from the Cordrol A) % Requests that are not yet rewtowed-Room, peddes haossen w storm to the Control Room, provides testing espetsnies from the Control Room, provides autemenc B) ModAcetion Requests being reviewed by the Nuclear actions Imm or to the Centrol Room, or provides a pesolve Projads Review Commutes (NPRC).

function for the Control Room and has been identilled as i

esAoterd,l.a., does not perform under al corusbons as designed.

c) ModAcetion Requeels being reviewed by the Nucieer

)

TNs deMien also apptes to the Anemste Shutdown Peneis Al-Projede Committee (NPC).

17g, Al-186, and Al-212.

These ModAcellen Requests may be reviewed several times A pierd osmponent which is deAoient or inoperande is considered before they me gpoved for accompmehment er conoeind. some of these home na's Requeels are retumed to Engineering for a

en operuler work Around (OWA) bem r some Wher schon is required by en operaler to componeels for the condbon of the more Miormenon, some approved for evoluohon, some approved compones. Some ammples of oWAs are:

tw study, and some approved for pionning once pionning is completed and the scope of the work is oleerty deAnod, these

1) The control room level indicater does not work ind a local Modacollon Rap eats may be approved for accomphehment wth eight glass een be reed by en operator out in the piant; a year sempiad for construohon or they may be conosted As of these efferent phases require review.

2) A dsAoient pump cannot be repaired because.

.24 parts require e long lead time for pW _

r_ti, thus

3) Design Engineering Backlog 4n Progrees Nuoleer 1

reqdring the redundant pump to to operded conhnuously; Planning has assigned a year in which construohon we be compassed and design work may be in progrees

3) Special actions are required by an Operaler beoeuse of equipment design probioms These adens may be

4) Construction Bacidogan Progrees. The ConstrucNon deserted h operimens Memorandums, operator Notes, or Pedage has been issued or constnation has begun but the mor regulre chenges to Operstmg Procedures, modf6 cation has not been accorted by the System

?--

Commulae (SAC).

4) Datolard pierd equipment that is required to be used during j

Emergency Operaung Procedures or Abnormal Operahng

5) DesignEngineering Update Racedogan progrees PED Procedures, has recewed the Modincehon Completion Report but the drawings have not been updated i

5) System indication that provides crGical informehon during j

normalor abnormal operations The above mentioned = *

.A,, modRcehens do not include modificebens which are proposed for concebeNon, i

NUMBER OF INSSED SURVER.uNCE TESTS RESULTWG i

IN UCENSEE EVENT REPORTS OVERALL PROJECT STATUS (REFUELING OUTAGE) i The number of Survesence Tests (STs) that reeut in Ucensee This indicator shows the status of the projeds wNch are in the Everd Reporte (LERs) during the reporting month. This indicator scope of the Refustng Outage.

f tracks missed STs for SEP g60 & 61.

l PERCENTAGE OF TOTAL MW0s COMPLEll!D PER MONTH OPEN CORRECTIVE ACTION REPORTS & INCIDENT IDENTIFIED AS REWORK 1

REPORTS l

1he percardage of total hMOs completed per mordh idenuned as TNs hAceter deploys tie total number of open CorrecWwe Achon reworlt Renerkedivmes areidenbAed bymaintenance pionning Reports (CARS), the number of CARS that are older then ok and creR. Rework is: Any addWonal work required to correct trueis and tie number of signlAcant CARS. Also displayed are deAdendes decovered during a faBed Poet Maintenance Test to the number of open incident Reporte (irs), the number of irs ensure the _.

C,i..

possee =h==t=nt Post that are greater then ok truths old and the number of open Memtenance Test.

i eignincent irs.

i PERCENT OF COMPLETED SC6EDULED MAINTENANCE OUTSTANDING MODIFICATIONS ACTMTIES 1

j The nurrdser of Mommenon Requests (MRs) in any state between The percent of the number of completed maintonence adMbes tioleeuenos of a khama=Han Number and the compiston of the as compared to the number of scheduled maintenance motvtles l

drawing gdele.

each month. This percenlege is shovm for aI melrdenence y

creAs. Also shown are the number of emergent MWOs.

j

1) Form FC 1133 Backlog 4n Progrees. This number Maintenance activlbes include MWRs, MWOs, STs, PMOs, represents modAceton requeels that have not boon plant coutusbons, and other miscellaneous adMuss This indicolor i

af, proved during the reportne month.

tracks Memtenance performance for SEP #33.

78

1 1

i i

" ~

PERFORMANCE INDICATOR DEFINITIONS i

j 1

PREvEmAmuwERSONNEL ERROR LERs

-ai wORx PRACTICES PROaRAM This indicolor is a tweeletousi of LERe. For purposes of LER The number of identined poor redlological teork proceloce

{

event ah==88=a%, e "Prowenteide LER'in deAned es:

(PRWPa) for the reporting month. This indlcator techs radiological work performance for SEP 862.

An event for which the feet cause is personnel error (i.e.,

i inappropriets action by one er more hdMduals), hadequale RADIO OF PREVENTIVE TO TOTAL MAsiTENANCE &

administruelve controls, e design construcIlon, instmustion, PREVENTIVE MAINTENANCE ITEMS OVEftDUE instensson, fetutammen prendem (inveMng work compisted by er egendsed by OPPD personnel) er a maintenance preidem The ruso of peerdive maireenance (holuctng sunemence toebng j

(ellrInuled to inodoquete er hiproper scheeptrepair of plant and cautweNon procedures) to the sum of non outage correcWwe i

es$mard). Also, the cause of the overt must have occurved maintenance end prevenDve mairdenence completed over the weNn appmevotely too peere of the " Event Date* epoedAnd in reporting pertod. The remo, empressed as e percentage, is the LER (e.g., en event for which tie cause is eartmuted to e calcuisted bened on man-houre. Aino dleployed are the percent 3.

problem och vie original design of the plant would not be of preventhe maintenenos name in the #nonth that were not compisted er administratively closed by the scheduled date plus considered preventatde).

s a grace pened equel to 25% of the scheduled stonel TNs For purposes of LER evert classincetion, e " Personnel Errer*

Indmetor tracks preventhe maintenance actMhes for SEP 841, 4

LER is deAnod as fotows:

1 RECOpnaaf F INJURYALLNESS CASES FREQUENCY l

An eierd Ier vdelch Die rest cause is inappropriele scalon on the RATE j

put d one er more indMduela (as opposed to being attributed j

to e department er a general group). Also, the inappropriate The number of injuries requinne more then normal first aid per l

actkm must have occurred within opprodmetely two years of 200,000 men hours worked This indicolor trends personnel f

the

• Event Dele

• epecined in the LER.

performance for SEP $15,25 and 26.

Adialunsuy, each event elseelAed as e " Personnel Error

• should REPEAT FAILURES

}

eine be clemeined as

• Preventable

• This hdicolor trends personnel performance for SEP llem #15.

The number of Nuclear Piert Retabnity Date Syelem (NPRDS) components wth more then one Indure end the number of j

PRIMARY SYSTEM CHERAISTRY % OF HOURS OUT OF NPRDS componeres udh more tien two feilures for the eigMeen.

UMIT month CFAR period.

The percert of hours out of Rmit are for obt primary chemistry SAFETY SYSTEM FAILURES perumstere dMded by the total number of heure posetdo for the j

month. The hoy peremotore used are: Lithium, CNorlds, Safety system fouures are any events or conddions that could

(

Hydrogen Dioeohed Oxygen, Fluoride and Suspended Solids.

prevent the fulnemord of the safety functions of structures or J

EPRI tmas are used.

eystems. If a nyalam consists of muniple redundant subsystems or trains, failure of el trains constitutes e esfety system Inture, l

PROCEDURAL NOJCOMPLIANCE INCIDENTS FeMure of one of two or more trains is not courned as e estety (MAINTENANCE) system failure. The dehnihon for the indmetor pereReis NRC reportrq; regdromeras h 10 CFR 50.72 and 10 CFR 50.73. The j

The number of idenNAnd incidents concomin0 maintonence intowing is e list of the mejor eefety systems,-d rr -,and proceduelpreidemo, Die number of cioned irs related to the use components monRored for this indicador-l of precedures (includes the number of closed IRo caused by pmoedural nencerrqstance), and the number of,,ascJ procedursi Accident Monitorin0 instrumentation, Ateeiery (and j

noncompennoe ire. This hatestor trends personnel performance Emergency) Feedseter System, Combustade Gas Cordrol, for SEP #15,41 and 44.

Companord Cooling Water System, Containment and i*

Cortenmord leciation, Cordainment Comient Systems, Control PftOGftESS OF CYCLE is OUTAGE MOOlFICATION Room Emergency Ventdemon System, Emergency Core PLAMeNG (FROZEN SCOPE OF 18 M00tFICATIONS)

Cocing Systems, Ergpinsered Soluty Features instrumoression, EssenhalC, 4 _

Air Systems, Essonnel or Emergency

}

This indlestor shows the sistus of medlAcshons approved for Service Water, Fire tw-man or Suppression Systems, j

oompiston during the RefuobnB Outage leoishon Condoneer, Low Temperature Overpreneure j

Protection, Mein Steam Une leointion Velves. Onene PROGRESS OF 1996 ON LDIE MOctFICATION PLANNING Emergency AC & DC Power telDiskthution, Redisuon l FROZEN SCOPE OF 12 MOctFICATIONS)

Montortrqiinstrumentation, Reactor Coolert System, Reector i

Core leolation Cooling System, Reactor Trtp System and l

This indicator shows the eastus of medlAcebens apprmed for instrumentation, Recircuishon Pump Trtp Actusbon compiston during 1996.

Instrumentshon, Residual Heat Remotel Systems, Safety Vehes, Spent Fuel Systems, Standby Uguld Control System and Ulbmete Heat Sink.

l 79

~

i PERFORMANCE INDICATOR DEFINITIONS I

SECONDARY SYSTEM CHEMISTRY PERFORMANCE STAFFING LEVEL 1

INDEX j

The acdusi etsffing level and the authortaed atsffing level for the The Chemletry Performance inds (CPI) is e easeme=*iant bened on Nuclear Operations Dwision, The Production Engineering l

the concentraNon of hoy impurtties in the secondary side of the DMelon,and the Nuclear Services DMeion. This indicator tracks plant. These hoy 'A7 are the most likely cause of performance for SEP #24.

j daterteragen of the steem generators. Cruerts for ceiculating the CPI are:

SMTION NET OENERATION I

1) The plant is et peeler then 30 percent power; and Tf.e not generation (sum) produced by the FCS during the reporting month.

i

2) the power is changing less then 5% per day.

TEMPORARY MODIFICATIONS The CPI is coloulated using the followin0 equation 5

The number of temporary mechanical and sisetncal I

CPI = (modlumR80) + (Chloride /1.00) + (Sulfale/1.70) +

configurshone to the plant's systems (iron /5.00) + (Copper &20) + (CPD D0/3.3)E

1) Temporary conrqgurshons are defined as electricaljumpers, 1

4 Where: Sodlum, sullste and chloride are the monthly everage elodrical blocks, mecherucal jumpers, or mechanical blocks blowdown concentrations in ppb, iron and copper are monthly which are instaied h the plant operahng systems and are not time weigNed averses feedwater concentrations in ppb. The shown on the lotest revision of the P&lD, schemahc, denominator for each of the five factors is the IMPO median connection, wiring, or flow disgrams.

value. If me monhly storage for a specsne parameter is less than the INPO medien value, the medlen value is used in the

2) Jumpers and blocks which are insta8ed for Survetence ceiculation Tests, Maintenance Procedures, Calibration Procedures, 1

Special Procedures or Operating Procedures are not SIGNIFICANT EVENTS considered as temporary modracehone unless the jumper or block ramens h piece aner me test or procedure is compiate I

Sipilkard events are the events identified by NRC staff through Jumpers and blocks instaged in test or lab instruments are detailed moreening and evalushon of operating experience. The not considered as temporary modincesons l

acreening process includes the daily review and docussion of au reported operatin0 reactor events, as wed as other operational

3) Scaffoki is not considered a temporary modificehon l

data such as special tests or construchon actMties. An event Jumpers and blocks which are instened and for which MRs identined from the screening process as a signincent event hate been submitted wGI be considered as temporary candidate is further evaluated to determine if any actual or modificahone unti final resolution of the MR and the jumper patentisi mreet to ms headh and eafety of the public was inwohod.

or block is removed or is permanently recorded on the Specific examples of the type of critorie are summertred as drewmps This indicator tracks temporary modincations for fonows:

SEP #62 and 71.

l

1) Degradation ofimportant safety equipment.

THERMAL PERFORMANCE I

l

2) Uneupscted plant response to a transient, The ratio of the design Dross heat rate (corrected) to the adjusted actual gross heet rate, expressed as a percentage j

3) Degradetion of fuel integrity, primary coolant pressure L

boundary,important===aew features; UNIT CAPABILITY FACTOR

4) Scram with complie= hart, The rabo of the available energy genershon over a given time 4

l period to the reference energy genershon (the energy that could

5) Unplanned reisese of radioactMty; be produced if the unit were operated conhnuously at fun power under reference ambient conditions) over the same time period,

6) Operation outside the timas of the Technical Specificehone, expressed as a percentage

7) Other.

UNIT CAPACITY FACTOR INPO signlRcent ennts reported in this indicator are EERs The not electrical energy generated (MWH) dMded by the (SignlAcant Event Reports) which inform uthilies of algnincent product of menimum dependeble cepecity (not MWe) times the i

l events and lessons teamed identined through the SEE-IN grosshours in the reportin0 povod, _ ^ f as a percent Not l

ecreenin0 process electrical energy generated is ll's groes electrical output of the

]

unM measured at the output terrninals of the turbine generator SPARE PARTS INVENTORY VALUE minus the normel station service code during the groes hours of the reportng period, expressed h megewett hours.

The domar value of the opere parts inve itory for FCS during the reportine portod.

i 80 i

b

?

PERFORMANCE INDICATOR DEFINITIONS UNPLANIED AUTOMATIC REACTOR SCRAMS PER 7,000 UNPLANNED SAFETY SYSTEM ACTIONS.(NRC

]

CRITICAL HOURS DEFINITION)

J i

TNs indicator is defined as the number of unplanned mulomatic The number of enfaty system adusuone ohich include (gh) the I,

screms (sender feelmogon system keic eduellone) that occur per High Pieneure Safety injadion System, the Law Pressure Safety 7,000 hours0 days <br />0 hours <br />0 weeks <br />0 months <br /> of craical operellort tr(scean System, the Safety Iniedian Tanks, and the Emergency Diesel Generators The NRC cieselfication of enfety system i

The value for this indlostor is mar m by mutiplying the total achaudons indudas actussions when major equipment is operated renbar of urplanned edemenc reactor screms h a specinc ume and when the logic eyelems for the etwve safety systems are period by 7,000 heure, then dMdnB that number by the total cheuenged d

l runber of hours ortloal in the same uma period. The indicator is further denned as fotows:

VIOLATION TREND

),

1) Unplanned means that the scram was not an anticipated part TNs hecolor is denned as Fort Calhoun Stanon CRed Vloimbons et a planned test.

and Nori-Caed Vloinhone trended over 12 months AddhonaNy, Caed vloisanne for me top quartin Region IV plant is trended over

2) Scram means the anomatic shutdown of the roedor by a 12 months (legging the Fort Calhoun Station trend by 2-3 rapid insergon of neestive reedMty (e p., by control rods, mordhs). R is the Fort Calhoun Station goal to be at or boiow the i

Squid hjedlon system, etc.) that is caused by actusuon of the cited vioishon trend for the top quartile Region IV piant.

l reactor protection syv em. The scram signal may have e

reeuned from escoeding a set paird or may have been VOLUME OF LOW-LEVEL SOUD parwTIVE WASTE spurtous J

This hdicator is defined as the volume of km-level sotd l

redoective weste actuaNy eNpped for burtal. TNs indicator aino

3) Adamdic means that the initial signal that caused actumbon shows the volume of low-level radioactive weste which is in of me seactor protection system logic was prov6ded from one temporary storage, the amount of radioacthe oE that has been

.i of the sensor's montorine plant parameters and condehone, shipped off-elle for proceseh0, and the volume of so8d dry l

remer than the manusi scram sweches or, monumi turbine trip redoeceve vests which has been eNpped offelle for processing i

avechas (or punt >bumons) provided in the main control room.

Low-levo mond radoective woole conents of dry nothe weste, oludges, reehs, and evaporator bottoms generated as a reeut of i

4) Cetucal Q Ans that during the steady-elete condition of the nudmar ptmer plant opershon and maintenance. Dry radioedhe reader prior to the scram, the effectNo rrdtantian (k,,)

weste hctsdes cortamineled rage, cimening materials, nanfia==ha=

wee essentimpy equal to one.

protodive dothing, plante containers, and any other material to be i

deposed of at a low-level redoective weste dispossJ elle, except UNPLANNED CAPABILITY LOSS FACTOR resin, aludge, or evaporator bottoms Low-level refers to ad radioactive weste that is not opent fuel or a by-product of opent The rumo of me unplanned energy losses durin0 a given period of fuel processing This indicator tracks radiological work i

tme, to me reference energy genershon (the energy that could be performance for SEP #54.

j pra,enn.,e if the unit were operated conhnuously at fuB power under reference ambierd condluons) over the sa'ne time period, j

exproceed as a percentage j

UNPLANNED SAFETY SYSTEM ACTUATIONS. (INPO DEFINITION)

This becakr is delhed as the sum of the following eefety system actumuune 4

1) The runber of unpienned Emergency Core Cochne System (ECCS) ectuscons that resut from reecNng an ECCS 3

1 octuation est point or from a spurious /lnadvertent ECCS eignet l

2) The number of unplanned errorgency AC power system actuations that reeut from a loss of power to e safeguards 4

bus. An urplanned eefety system actuohon occurs when en aduemon est point for a esteey system la reached or when a apurtous or hedhertent signal is generated (ECCS only), and l

maior equipment in the system is actussed Unplanned means met me system actuabon was not part of a planned test or ovskatiert The ECCS actuanons to be counted are actuations of the high pressure ingsction system, the low preneure injection system, or the esfety inpoeten tanks.

s 81 i

d -

l I

4 SAFETY ENHANCEMENT PROGRAM INDEX i

}

The purpose of the Safety Enhancement Program (SEP) Performance indicators index is to list l

performance indicators related to SEP ltems with parameters that can be trended.

l j

SEP Reference Numberis Enea e increase HPES and IR Accountability through use of Performance indicators Procedural Noncompliance incidents (Maintenance)....................................... 47 j

j Clean Controlled Area Contamina#ons11,000 DisintegrationsMinute Per Probe Ares............ 3

. PreventablePorsonnel Error t.ERs...................................................... 4 i

SEP Reference Number 24 t

Complete Staff Studies a

a j

Staf$ng I evel..............,........................................................ 40 i

j SEP Reference Numbers 25. 26. & 27

• Training Program for Managers and Supervisors implemented

)

• Evaluate and implement Station Standards for Safe Work Practice Requirements

=..itz:M Supervisory Enforcement of industrial Safety Standards r

)

Disabling injuryAliness Frequency Rate................................................... 2 3

SEP Reference Number 31

. Develop Outage and Maintenance Planning Manual and Conduct Project Management Training l

MWO Planning Status (Cycle 16 Refueling Outage)....................................... 64 Overall Project Status (Cycle 16 Refueling Outage)........................................ 65 Progress of Cycle 16 Outage Modification Planning....................................... 66 SEP Reference Number 33 l

. Develop On.4.ine Maintenance and Modification Schedule l

Percent of Completed Scheduled Maintenance Activities (All Maintenance Crafts)............... 46 l

SEP Reference Number 36

= Reduce Corrective Non. Outage Backlog i

Maintenance Workload Backlogs (Corrective Non-Outage).................................. 47 SEP Reference Numbers 41 & 44

. Develop and Implement a Preventive Maintenance Schedule

. Compliance With and Use of Procedures a

Rato of Preventive to Total Maintenance & Preventive Maintenance items Overdue.............. 44 j

Procedural Noncompliance incidents (Maintenance)....................................... 47 SEP Reference Number 46 i

= Design a Procedures Control and Administrative Program Document Review................................................................... 53 l

i i

i

SEP Reference Number 52 Eagg

. Establish Supervisory Accountability for Workers Radiological Practices Radiological Work Prac6ces Program................................................... 52 SEP Reference Number 54

. Complete implementation of Radiological Enhancement Program Colleceve Radiation Exposure.......................................................... 14 Volume of Low-Level Solid Radioactive Weste............................................ 35 Clean Controlled Area Disintegrations >1,000 CountsMinute Per Probe Area.................... 3 Contaminated Radiation Controlled Area............................................... 51 SEP Reference Number 56

= Revise Physical Security Training and Procedure Program Loggable/ Reportable incidents (Security)................................................ 54 SEP Reference Numbers 60 & 61 Improve Controls over surveillance Test Program Modify Computer Program to Correctly Schedule surveillance Tests Number of Mosed Surveillance Tests resulting in Licensee Event Reports

..................18 SEP Reference Number 62

. Establish interim System Engineers Temporary Modifications............................................................ 55 Engineering Assmtance Request (EAR) Breakdown........................................ 57 Engineering Change Notice Status

............................ 58 j

Engineering Change Notices Open................................................... Sg SEP Reference Number 68

. Assess Root Cause of Poor Operator Training and establish means to monitor Operator Training Ucense Operator Requalification Training.............................................. 61 License Candidate Exams......................................................... 61 SEP Reference NJmber 71 Improve Controls over Temporary Modifications 4

Temporary Modifications

.............................................................55 4

4 4

1 4

J 83 i

FORT CALHOUN STATION OPERATING CYCLES AND REFUELING OUTAGE DATES EVENT DATE RANGE PRODUCTION (MWH)

CUMULATIVE (MWH)

Cycle 1 09/26/73-02/08/75 3,299,639 3,299,639 1st Refueling 02/08/75 - 05/11/75 Cycle 2 05/11/75 - 10/01/76 3,853,322 7,152,961 2nd Refueling 10/01/76-12/13/76 Cycle 3 12/13/76 - 09/30/77 2,805,927 9,958,888 3rd Refueling 09/30/77-12/09/77 Cycle 4 12/09/77-10/13/78 3,026,832 12,985,720 4th Refueling 10/13/78-12/24/78 Cycle 5 12/24/78 - 01/18/80 3,882,734 16,868,454 Sth 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 -12/03/82 3,561,866 24,330,034' 7th Refueling 12/03/82 - 04/06/83 Cycle 8 04/06/83- 03/03/84 3,406,371 27,736,405 8th Refueling 03/03/84-07/12/84 Cycle 9 07/12/84 - 09/28/85 4,741,488 32,477,893 9th Refueling 09/28/85- 01/16/86 Cycle 10 01/16/86 - 03/07/87 4,356,753 36,834,646

)

10th Refueling 03/07/87 - 06/08/87 j

Cycle 11 06/08/87 - 09/27/88 4,936,859 41,771,505 j

11th Refueling 09/27/88- 01/31/89 f

l Cycle 12 01/31/89- 02/17/90 3,817,954 45,589,459 i

12th Refueling 02/17/90- 05/29/90 l

Cycle 13 05/29/90 - 02/01/92 5,451,069 51,040,528 13th Refueling 02/01/92 - 05/03/92 l

Cycle 14 05/03/92-09/25/93 4,981,485 56,022,013 l

l 14th Refueling 09/25/93 -11/26/93 Cycle 15 11/26/93- 02/20/95 5,043,887 61,065,900 15th Refueling 02/20/95- 04/14/95 Cycle 16 04/14/95 - 09/21/96 16th Refueling 09/21/96 - 11/02/96 (Planned Dates) i: ORT CALHOUN STATION CURRENT PRODUCTION AND OPERATIONS " RECORDS" First Sustained Reacton August 5,1973 (5 47 p.m )

First Electrierty Supplied to the System August 25,1973 Commercial Operston (180,000 KWH)

September 26,1973 Achieved Full Power (100%)

May 4,1974 Longest Run (477 Days)

June 8,1987-Sept. 27,1988 Highest Monthly Net Generston (364,468,800 KWH)

October 1987 Most Productve Fuel Cycle (5,451,069 MWH - Cycle 13)

May 29,1990-Feb.1,1992 Shortest Refuehng Outage (52 days)

Feb. 20,1995-April 14,1995 Highest Calendar Year Generaton (4,118,368.7 MWH) 1994 j

. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - -