ML20136C755

Plant Status Rept for St Lucie,Units 1 & 2

ML20136C755
Person / Time
Site:	Saint Lucie
Issue date:	09/30/1995
From:	NRC OFFICE OF INSPECTION & ENFORCEMENT (IE REGION II)
To:
Shared Package
ML17229A261	List: IR 05000335/1995015 IR 05000335/1996011 L-81-415, Informs That Staff Believes That NRC Interpretation of Term Directly Supervised Counterproductive ML17229A260 ML20136C421 ML20136C664 ML20136C714 ML20136C742 ML20136C755 ML20136C800 ML20136C820 ML20136C839 ML20136C941 ML20136D435 ML20136D456 ML20136D476 ML20136D508 ML20136D630 ML20136D855 ML20136D872 ML20136D892 ML20136D917 ML20136D944 ML20136D958 ML20136E025 ML20136E234 ML20136E255 ML20136E271 ML20136E283 ML20136E301 ML20136E307 ML20136E360 ML20136E364 ML20136E377 ML20136E387 ML20136E390 ML20136E396 ML20136E402 ML20136E448 ML20136E454 ML20136E464 ML20136E469 ML20136E484 ML20136E491 ML20136E539 ML20136E546 ML20136E564 ML20136E569 ML20136E579 ML20136E595 ... further results
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FOIA-96-485 NUDOCS 9703120176
Download: ML20136C755 (48)

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4 REGION 11 ATLANTA, GEORGIA

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PLANT STATUS REPORT ST. LUCIE 4

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SEPTEMBER,1995

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9703120176 970306 PDR FOIA BINDER 96-405 PDR

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PLANT STATUS REPORT FOR ST. LUCIE (9/95)

TABLE 0F CONTENTS PART 1 - FACILITY DESCRIPTION 1.1 FACILITY / LICENSEE....................................Page 2

1.2 UTILITY' SENIOR MANAGEMENT...........................Page 2

l.3 NRC STAFF............................................Page 2 1.4 LICENSE.INFORMATION..................................Page 3 1.5 PLANT CHARACTERISTICS................................ Page 3 1.6 SIGNIFICANT DESIGN INFORMATION.......................Page 3 i

'l.71 EMERGENCY RESPONSE FACILITIES / PREPAREDNESS...........Page 8-1 1.8 PRESENT OPERATIONAL STATUS (Past Six Months).........Page 9 1.9 - OUTAGE SCHEDULE AND STATUS...........................Page 10 PART 2 - PLANT PERSPECTIVE 4

2.1 GENERAL PLANT PERSPECTIVE............................Page 11 2.2 SALP' HISTORY (Past Two SALP Periods).................Page 11 2.3 SELECTED SALP AREA DISCUSSIONS

......................Page 11 PART 3 - SIGNIFICANT EVENTS 3.1 SIGNIFICANT EVENTS BRIEFINGS (Past 12 Months)........Page 16 3.2 ENFORCEMENT STATUS / HISTORY (Past 12 Months)..........Page 16 PART 4 - STAFFING AND TRAINING 4.1 OPERATIONS STAFF - 0VERALL...........................Page 16 4.2 WORK FORCE

..........................................Page 17 4.3 OPERATOR QUALIFICATION /REQUALIFICATION PROGRAM.......Page 17 4.4 PLANT SIMULAT0R......................................Page 17 4.5 INP0 ACCREDITATION...................................Page 17 1

PART 5 - INSPECTION ACTIVITIES 5.1 OUTSTANDING ITEMS LIST

SUMMARY

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5.2 MAJOR INSPECTIONS....................................Page 18 5.3 PLANNED TEAM INSPECTIONS.............................Page 18 5.4 INFREQUENT INSPECTION PROCEDURE STATUS...............Page 18 5.5 SIMS STATUS (OPEN TMI ITEMS).........................Page 18 l

ATTACHMENTS l.

PERFORMANCE INDICATORS 2.

ALLEGATION STATUS 3.

NRR-OPERATING REACTOR ASSESSMENT 4.

ORGANIZATION CHARTS 5.

POWER HISTORY CURVES.

6.

MASTER INSPECTION PLAN (NOT INCLUDED) 7.

SITE ACTIVITY SCHEDULE 8.

SITE INTEGRATION MATRIX 9.

PERFORMANCE ANALYSIS GRAPH Lr 1

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'FAC!!.ITY DESCRIPTION 1.1 FACILITY / LICENSEE I

FACILITY:

St. Lucie Units 1,and 2 PLANT LOCATION:

Hutchinson Island near Port St. Lucie, Florida LICENSEE:

Florida Power and Light Co. (Corporate Office in Juno Beach, Florida) 1.2 lJTILITY SENIOR MANAGEMENT CORPORATE:

J. L. Broadhead (Jim), Chairman of the Board and CEO J. H. Goldberg (Jerry), President, Nuclear Division SITE:

D. A. Sager (Dave) - St. Lucie Plant Vice President C. L. Burton (Chris) - Services Manager L. W. Bladow (Wes) - Nuclear Assurance Manager H. F. Buchanan (Hank) - Health Physics Supervisor R. L. Dawson (Bob) - Licensing Manager D. J. Denver (Dan) - Site Engineering Manager H. L. Fagley (Herman) - Construction Services Manager P. L. Fincher (Pat) - Training Manager R. J. Frechette (Bob) - Chemistry Supervisor P.

Fulford (Paul) - Operations and Testing Support Supervisor 4

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Marchese (Joe) - Maintenance Manager W. L. Parks (Bill) - Reactor Engineering Supervisor C. A. Pell (Ash) - Outage Manager L. A. Rogers (Lee) - Systems and Component Engineering Manager J.

Scarola (Jim) - Plant General Manager J. A. West (Jeff) - Operations Manager C.-H. Wood (Chuck) - Operations Supervisor i

1.3 NRC STAFF REGION II, Atlanta, GA:

S. D. Ebneter (Stew), Regional Administrator, (404) 331-5500 L. A. Reyes (Luis), Deputy Regional Administrator (404) 331-5610 g

B. A. Boger (Bruce), Acting Director DRP, (404) 331-5623 D. M. Verrelli (Dave), Branch Chief, (404) 331-5535 K. D. Landis (Kerry), Section Chief, (404) 331-5509 R. P. Schin (Bob), Project Engineer, (404) 331-5561 E. Lea (Edwin), Project Engineer, (404) 331-7096 SITE:

R. L. Prevatte (Dick), Senior Resident Inspector, (407) 464-7822 M. S. Miller (Mark), Resident inspector, (407) 464-7822 i

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NRR:

S. A. Varga (Steven), Director, Division of Reactor Projects-I/II, (301) 504-1403 J. A. Zwolinsky (John), Deputy Director, Division of Reactor Projects-l/II. (301) 504-1335 D. B. Matthews, Deputy Director, Project Directorate !!-2, (301) 415-1490 J. A. Norris (Jan), Senior Project Manager, Project

'l Directorate 11-2, (301) 504-1483 AE00:

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S. Israel (Sandy), Reactor Operations Analysis Branch,

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(301) 415-7573 j

1.4 LICENSE INFORMATION Unit 1 Unit 2 Docket Nos.

50-335 50-389 License Nos.

DPR-67 NPF-16 Construction Permit Nos.

CPPR-74 CPPR-144 Construction Permit Issued 7/1/70 5/2/77 Low Power License NA 4/83 Full Power License 3/1/76 6/10/83 Initial Criticality 4/22/76 6/2/83 1st Online 5/17/76 6/13/83 commercial Operation 12/21/76 8/8/83 1.5 PLANT CHARACTERISTICS Descriotion Units 1 and 2 Reactor -Type Combustion Engineering PWR, 2-loop i

Containment Type Freestanding Steel w/ Shield Building Power Level 830 MWe (2700 MWt)

I Architect / Engineer Ebasco NSSS Vendor Combustion Engineering Constructor Ebasco Turbine Supplier Westinghouse Condenser Cooling Method Once Through Condenser Cooling Water Seawater

1.6 SIGNIFICANT DESIGN INFORMATION 1.6~.1 REACTOR INTEGRITY Reactor Pressure Vessel (RPV)

With the present fuel type and mhnagement policy, Unit 1 is expected to reach a 40-year RPV life. On this unit, the fuel type and management policy have been modified to make that RPV life

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4 span possible. Presently, a program is evolving for RPV life.

extension beyond the projected 40 years, potentially to 60 years, via a flux reduction program. A flux reduction program has started with the addition of eight absorbers in core corner positions, performance of vessel fluence calculations, and determination of an optimum power profile for each core load.

Calculations using current methodology and uncertainty predict a -

significant RPV life extension, but not to 60 years.

Excore dostmetry installed for the current cycle [with planned removal in Octoberi 1994) will be used to reduce calculation uncertainty.

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Due to different design.and construction characteristics, Unit 2 RPV life expectancy exceeds 60 years.

Low leakage core designs are now used for economic reasons, however the low leakage designs provide even greater life expectancy..

Reactor Coolant Pressure Boundarv On this CE plant, ECCS-to-RCS injection points are isolated by at least two check valves and one closed MOV. High pressure safety injection (HPSI), low pressure safety. injection (LPSI), and containment spray (CS) pumps' common containment sump suctions are isolated from the containment sump by one closed MOV in conjunction with a closed seismic piping system.

The CS headers are isolated from containment by one closed MOV and a check valve in conjunction with a closed seismic piping system. CVCS has the j

s' normal complement of two automatic actuation isolation valves.

1.6.2 REACTOR SHUTDOWN Reactor Protection System The reactor protection system provides protection for the reactor fuel and its cladding by providing automatic roactor shutdowns (8

,i trip's) based on input from reactor power, reactor coolant pressure, coolant temperature, coolant flow, steam generator pressure, and containment pressure.

The RPS is a redundant four-3 channel system that operates on a two-out-of-four logic.

ATWS Protection

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ATWS protection, outside the normal reactor protection system, is initiated via the ESF pressurizer pressure signal.

It actuates by o,'ening contactors in the output of the CEA MG sets, thereby interrupting control element assembly power at its source.

This protection'has been installed on both units per CE, the NSSS, recommendations.

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Remote Shutdown Facilities These facilities are located in the switchgear rooms beneath each unit's control room.

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. 1.6.3 CORE COOLING Feedwater System a

The main feedwater pumps are motor driven with each delivering 50 3

' percent of the flow required for full power.

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Turbine Bvnass/ Steam Da=a Canacity i

Each unit has five steam bypass valves, providing 45 percent of j

total capacity.

4 i-Unit I has one atmospheric dump valve per train (two trains) and i1 Unit 2 has two valves per train. Each unit has the capability of j '1 dumping nine percent-steam flow to the atmosphere.

1 Auxiliary Feedwater System f

There are two motor-driven pumps on each unit with 100 percent

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capacity per pump. There.is one steam-driven pump on each~ unit i

with 200. percent capacity. Any of the three pumps can inject to either steam generator. Automatic initiation and faulted steam generator protection are provided by each unit's Auxiliary 3

'feedwater Actuation System provided by the NSSS.

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Fearaency Core Coolina System i- (

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In each unit,.there are two HPSI pumps and two LPSI pumps with no

" i-unit-to-unit cross-connections. One pump of each type per unit will handle a postulated LOCA. The LPSI pumps also provide decay L

heat removal as required when the unit is shut down.

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i Decay Heat Removal As indicated above, the LPSI pumps also provide decay heat removal as required when the unit is shut down by taking suction from the RCSi(hot legs), passing the fluid through the shutdown cooling

,I heat exchangers, and returning it to the RCS (cold legs). The heat removing medium is CCW - discussed in section l.7.6 below.

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Shutdown cooling flow path overpressure protection is provided by automatic isolation valves and various relief valves in the system.

1.6.4 CONTAINMENT Pressure Control / Heat Removal There_Are two containment spray pumps.and four containment fan coolers available per unit to suppress' pressure spikes and cool 4

the containment. One CS pump and two fan coolers will handle a postulated LOCA. There are no unit-to-unit cross-connections.

This engineered' safety feature is automatically started by ESFAS.

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Hydroaen Control Containment hydrogen control post-LOCA is accomplished on each unit by two trains of hydrogen recombiners located on the operating deck inside containment. By elevating, in a controlled manner, the temperature of containment atmosphere flowing through the recombiner, the recombiner units recombine hydrogen and oxygen to form water, thus preventing the buildup of hydrogen to potentially explosive levels.

1.6.5 ELECTRICAL POWER

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Offsite AC The station switchyard is connected to the transmission system by three independent 240 KV lines that share a right of way and interconnect with FPL's grid on the mainland approximately 10 4

miles West of the plant site. There are two independent offsite power feeds from the station switchyard to the emergency busses.

Onsite AC Onsite AC power is provided by four EDGs (two per unit).

EDGs are,

independent of other plant systems except vital DC power for control of starting. A Station Blackout (S80) cross connection is installed and tested. This cross-connection serves the emergency busses directly and reduces cross-connect time to less than 15 minutes.

DC Power 1

.Two trains of vital batteries per unit have been routinely tested for four-hour DC load profiles. Recently, due to cell replacement, they have been tested for three-hour battery capacity instead. The battery capacity test is harsher than the load profile test. There are four normal chargers per unit with swing chargers available for service. Non-safety batteries can be

j cross-connected'to the safety-related swing bus if needed.

Instrumentation Power Each unit has four inverters, two powered from each vital DC r

train, that provide four trains of instrumentation power.

Station Blackout Resolution-Status Unit 2 is a four-hour "0C coping" plant per the original license while Unit 1 is subject to the station blackout (580) rule.of 10 CFR 50763 requiring additional licensee action (unit-to-unit cross-connect of 4160V bus).

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1.6.6 SAFETY-RELATED COOLING WATER SYSTEMS

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Intake Coolina Water (Service Water) i Intake cooling water (ICW)'for each unit originates in a common canal called the Intake Canal. The canal level. varies with the tides since it is filled by a level difference between the l

Atlantic Ocean and the canal. One 16-foot and two 12-foot diameter pipes pass under the beach to connect the ocean and 1

canal. The intake pipe ends in the Atlantic ~are covered by intake structures (rebuilt in 1991) intended to limit flow velocities,-

particularly vertical velocity, to reduce marine life entrapment.

After use, ICW returns to the ocean through a Discharge Canal and under-beach pipes.

j Each unit has two trains of ICW plus a swing pump that can be aligned to either train electrically and physically. The licensee has converted the deep draft ICW pumps from externally (water).

lubricated to self-lubricated to increase reliability of the lubrication water source. The 100 percent (each) capacity pumps t

take suction from the intake canal via a canal intake structure using traveling screen debris protection. The intake canal structures adjacent to the ICW pump suctions are continuously injected with a hypochlorite solution to reduce marine growth in

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the associated piping and heat exchangers. Commencing 3/92, periodic injection of a clasicide at the intake structures, if primarily to control marine growth affecting the turbine condensers, has also somewhat reduced marine growth affecting the j,

ICW system, i4 The'ICW pumps move water through two trains of her.t exchangers that cool component cooling water (CCW) and two trains of heat

'exchangers that cool main turbine cooling water. During a-post.ulated accident, water. flow isolates from the turbine cooling

_ heat exchangers. The discharge from the heat exchangers returns via,the discharge canal to the ocean.

,l Increases in debris and silt in the' heat exchangers during 1993 indicated that the intake canal needed dredging.

As of September 1993, the utility was routinely cleaning main condenser waterboxes at reduced power and obtaining necessary dredging permits from the state and Corps of Engineers.

l The canal was dredged in December 1993 and January 1994 with immediate results.of reduced waterbox fouling.

Closed Coolino Water Systems Each unit has two trains of Component Cooling Water (CCW). The arrangement of two pumps and a swing pump mimics the ICW system.

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8 The swing pump can be aligned to either train. The 100 percent (each) capacity pumps drive water through the CCW/ICW heat exchangers and then on to the heat loads, mainly the containment fan coolers and the shutdown cooling (decay heat) heat.exchangers (which also can operate as containment spray heat exchangers).

Additionally, CCW cools a variety of bearings, seals, and oil coolers for the HPSI, LPSI, and CS pumps. A non-safety-related-portion of the CCW system cools reactor coolant pump seals and the spent fuel pool. This section isolates upon engineered safety features actuation.

1.6.7 SPENT FUEL STORAGE Wet storage capability exists up to the year 2002 (Unit 2) and 2007 (Unit 1).

i 1.6.8 INSTRUMENT AIR SYSTEM Instrument air compressors and driers, installed several years ago on each unit, provide all instrument air for Unit 2 and all but containment air for Unit 1.

These have increased instrument air reliability. Unit I also has instrument air compressors inside containment.

1.6.9 STEAM GENERATORS Each unit has two large steam generators (SGs) rather than the l

three or four usually seen. The licensee has begun to focus on a Unit 1 SG replacement in 1997. The SGs are under construction at the B&W Canada shops and a site organization is functioning.

a 1.7 EMERGENCY RESPONSE FACILITIES / PREPAREDNESS Emergency.0perations Facility:

10 miles West of site, I-95/ Midway Rd. Exit TechnicaT-Support Center:

Onsite, Adjacent to Unit 1 Control Room Operational Support Center:

Onsite, 2nd floor of North Service Building i

The last annual emergency preparedness exercise was in May, 1995. This exercise was.not formally evaluated by the NRC.

The next emergency preparedness exercise is scheduled for February, 1996, i

Since St. Lucie site has a high probability of hurricanes, "j

communications facilities were improved following the Turkey Point experience with Hurricane Andrew.in August, 1992.

Improvements include:

a High Frequency Auto-link with other FPL sites and NRC.

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Enhanced 900 MHZ System for site and mobile cor-mications, with idios also in the licensee's EOF and county emergency facility.

Cellular phones with hardened antennas.

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Hardened Local Government Radio antenna ties.

L8 PRESENT OPERATIONAL STATUS (9/19/95)

The unit was ' shutdown on August 1, 1995', as a result of Hurricane Erin.

A series of. problems including RCP seal' failure, both PORVs inoperable dea to incorrect assembly, SDC relief valve problems, associated poblems with several other relief valves, inadvertent spraydown'of the-containment, catastrophic failure of 18 emergency diesel. generator, and a leaking flange on a pressurizer safety valve have prevented the unit

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j from being restarted. With the unit down, a large number of operator-work-arounds and other plant deficiencies are pscheduled to be corrected. The next refueling outage is scheduled for April 4, 1996.

i Unit 2 was: shutdown on April 25, 1995, for approximately seven hours to replace a main turbine digital electro hydraulic power supply. The unit was down' powered for several days in June and July to clean condenser water boxes. The unit was shutdown on August 1, 1995, as a result of Hurricane' Erin. The unit was restarted on August'4, 1995.

Power was reduced from August li through 29 to clean condenser water boxes and repair various secondary plant deficiencies. The next refueling outage t-is scheduled for October.9, 1995.

.i Availability Factors:

Unit 1 Unit 2 F

1991 81.0 100.0 1992 96.5 75.2 1993 74.0 71.8 l

1994 86.8 79.6 1995 (through 7/95) 93.9 98.3 L

Cumulative (through 7/95) 77.7 83.7 t-

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1.8.1 UNIT 1 OPERATING HISTORY (Past Twelve Months from 8/1/94)

Unit 1 operated continuously during the past 12 months with the l1 following exceptions:

Lirit I reduced power and entered mode 2 on August 28, 1995, to repair a DEH leak. The. unit was returned to power approximately

,;l; 18 hours2.083333e-4 days <br />0.005 hours <br />2.97619e-5 weeks <br />6.849e-6 months <br /> later on the same date.

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On October 26, 1994, tne unit tripped from 100 percent-power due 1

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to a loss of electrical load. This was the result-of arc-over in:

1 a potential transformer in the switchyard due to salt buildup.

The licensee then entered a unit refueling outage, which had been

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scheduled to begin four days later. The unit' was returned to service on November 29, 1994.

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-On February 21, 1995, the unit was removed from service for the

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raphcoment of pressurizer code safety valves which had been leaking by the seat since shortly after startup in November, 1994.

The unit was returned to service on March 8, 1994.

On March 4, 1995, the unit experienced a 14 minute loss of' a

shutdown cooling.- The apparent root cause was operator error by a reactor operator placing one loop of SDC in. standby. The operator apparently closed the suction valve to the operating, vice standby, pump. The operator in question has denied the error.

.The licensee is considering disciplinary action and has relieved the operator of licensed activities.

1 On June 11, 1995, the unit was down powered to 40 percent to jumper out a cell on IB safety related battery.

On July 8, 1995, the unit tripped during turbine valve surveillance testing.

It returned to power on July 12, 1995.

On August 1, 1995, the unit was shutdown as a result of Hurricane Erin. Due to a series of equipment problems and personnel performance issues, the unit is presently shutdown.

'i 1.8.2 UNIT 2 OPERATING HISTORY (Past Twelve Months from 8/1/95) 4 I

Unit 2 operated continuously during the past 12 months with the following exceptions:

On February 21, 1995, the unit tripped as a result of low steam generator water level. The condition was the result of a 7

feedwater regulating valve closure after a steam generator water i

level control level transmitter failed high.

The transmitter was replaced and the unit was returned to service on February 25, 1995.

y On April 25, 1995, the unit was shutdown for approximately 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />

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to replace a main turbine DEH power supply.

On August 1, 1995, the unit was shutdown as a result of Hurricane 7*

Erin.

It was restarted on August 4, 1995, but operated at reduced power from August 17 through 29, 1995, to clean condenser water boxes and repair equipment problems.

i 1.9 OUTAGE SCHEDULE AND STATUS 4

Unit l's last refueling outage began on October 26, 1994, and ended on November 29, 1994.. Major activities included: refueling; reactor vessel nozzle and flange weld ISI inspection; installation of a permanent cavity seal ring; replacing reed switches for several CEAs; integrated 1

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s 11 safeguards test; steam generator tube inspection and plugging; steam generator sludge lancing; repair of refueling water storage tank; 4

several instances'of reduced inventory / mio ;oop operations; replacement of ICW/CCW LOOP logic [HFA latching relays) with pull-to-lock switches; removal (collection]'of Rx vessel neutron flux dosimetry; modification 4

of EDG skids to allow access underneath; inspection of ECCS sump area-4 replacement of a main transformer; modification of containment spray NaOH addition. piping; and mechanical, electrical, and IAC systems i

maintenance.

Unit 2's last refueling outage began on February 13, 1994, and ended 1

April 17, 1994.. Major outage activities included: refueling; steam generator tube inspection and plugging; low pressure turbine blade 4

i. l replacement; emergency diesel' generator inspection; replacement of two 1

reactor coolant pump mechanical seals; and mechanical, electrical, and I&C systems maintenance. The next Unit 2 refueling outage is scheduled for October, 1995.

PART-2

. PLANT PERSPECTIVE 2.1

' GENERAL PLANT PERSPECTIVE 4

A SALP presentation was conducted on February 17, 1994, covering the SALP period of May 3, 1992, through January 1, 1994. The facility was 4

i rated category 1 in all functional areas for the second consecutive SALP period.

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In June 1994 St Lucie was dropped from the NRC management list of good performers after experiencing five unit reactor trips in the first half

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of 1994.

j 2.2 SALP HISTORY (Past 2 SALP Periods)

The last--SALP period, SALP Cycle.10, ended on January 1, 1994. The j

current SALP period ends on July'1, 1995.

l ASSMT.

OPS RAD MNT/SURV EP SEC ENG/ TECH SAQV F

PERIOD

!l' 5/1/89 -

1 1

2 1

1 1

1 10/31/90 11/1/90 -

1 1

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1 1

1 5/2/92 PLANT OPS MAINTENANCE ENGINEERING PLANT SUPPORT 5/3/93 -

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2.3 SELECTED SALP AREA DISCUSSIONS (9/1/95)

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12 Since July 1995, there has been a series of events that led to questioning the plants overall performance. These have included: a Unit 1 turbine trip due.to procedural weakness, operator performance and

,a supervisory oversight; the attempt to restage an RCP seal using inadequate and inappropriate procedural guidance which led to the failure of the second and third stage seals, a main steam isolation signal due to inappropriate operator response, an inadvertent reactor q

protection system' actuation due to inattention to detail by an operator, j

both pressurizer relief valves being inoperable due to incorrect assembly during a refueling outage, an inoperable shutdown cooling 4

f relief valve due to incorrect setpoint margins (a generic problem involving several valves), the spray down of containment due to an 4

inadequate procedure and operator error coupled with an existing operator-work-around. These and several other recent deficiencies

j involving weak procedures, a general lack of procedural compliance, l[

equipment failures, and personnel errors clearly indicate that the plants past_high level of performance has declined.

Both units were shutdown on August 1, 1995, for Hurricane Erin. Unit 2 immediately restarted but Unit I remained shutdown. The above problems have led to several plant management' changes, an overall evaluation of the recent 4

-plant problems by a plant requested independent assessment team and a root cause evaluation by the NRC.

In a meeting with the NRC on August 29, 1995, the licensee committed to use the results of the independent assessment team to develop an action plan for improvement.

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'1 Plant Ooerations 2

1 Summary of Previous Assessment Within the current SALP cycle, previous assessments have noted a l-potential decline in Operations' performance.

Noted indicators included five reactor trips in the first six months of the cycle.

t No-rosmon root causes were. identified. Operator actions with regard to the noted trips were generally good. Two entries into f

reduced inventory operations during the Unit 2 outage were noted R

as excellent.

Procedural weaknesses which indicated'a lack of

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rigor in the review process were noted, as was_the fact that temporary changes to procedures were on the increase (indicating increasing' attention to procedural adequacy).

Management activities in response to the increase in operational events was determined to be strong, with an increase in overall focus directed at plant operations. The corrective action:

program was enhanced, consolidating several programs into one which involves daily management reviews of all documented conditions.

The previous _ assessments concluded that Operations remained strong in.the current period, that management actions were aggressive in dealing with identified weaknesses,' and that increased attention to procedural adequacy may be warranted.

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l 13 Last Six Months

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The previous six months has shown.an increase in personnel errors 1

involving,.the failure to follow procedures, inattention to ji detail, the failure to maintain awareness of equipment status, and l

weaknesses in logkeeping. Only one reactor trip, a turbine trip

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due to operator error, occurred during this time span. Operator 1

response to that event was excellent. Overall response to plant j

startups, shutdown, power maneuvers has been good.

Several findings indicated weaknesses in personnel performance, procedural

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adequacy, inattention to detail, weak logkeeping, equipment.

failures, poor communications, and living with operator-work-arounds. They include:-

4 Overpressurizing the main generator Not logging equipment out of service i

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Starting a LPSI pump with the suction valve closed

-Overfilling PWT' F

Spray down of Unit 1 Containment i

e Improper staging of RCP seal resulted in seal failure 1

Failure to block MSIS actuation i

Turbine trip due to operator error STAR /NCR not evaluating past operability i

Temporary modification not shown on CR drawing Loss of SDC, operator closed suction isolation valve Weak annunciator response on loss of SDC

!1 Operator failed to identify level out of sight on EDG i

cooling water tank i

Spent fuel pool housekeeping i

Failure of SGWL Rosemount transmitter (maintenance) 28 LPSI pump found airbound Failure to sample SIT within TS required time frame l.

following volume addition (second occurrence in 2 years) l; i

. Failure to identify and analyze hot leg flow stratification f

Str,engths

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Strengths have been identified in operator response to trips, transients, and power maneuvers. Post job or i-evaluation briefings have overall been timely and thorough J

with the exception of several recent events.

Weaknesses See paragraph'l above.

conclusion

' Operations performance has declined in the past six months.

Operators respond well to events but do notlalways have.a

. questioning attitude, appear to have lapses in procedural use.and compliance, and are not identifying and forcing

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p 14 plant support organizations to correct plant deficiencies.

Logkeeping and attention to detail have led to an increase in errors.

Maintenance /Surve111ance Summary of Previous Assessment Maintenance was assessed as category 1 in the previous SALP..

The previous assessments'made during the current SALP cycle

. indicated that the performance. level.of maintenance activities had not abated. Strong performance had been noted in the support of the Unit 2 outage, and housekeeping and plant preservation activities were' deemed good.

t Last Six Months 1

During the past six months, 24 maintenance activities were observed in varying levels of depth. One violation involving the installation of incorrect size motor overload heater was identified.. Three potential violations involving, inadequate surveillance, inadequate post maintenance tests, and two inoperable PORV are currently being evaluated. Two non-cited violations involving inadequate control on jumpers were identified. Workers were found to be well skilled and trained overall. Problems have s'

been noted in procedural adequacy and use.

Twenty-two surveillance activitie's were observed. Two non-cited violations involving the failure to perform surveillance within specified time limits were identified.

These were the result of a weak surveillance tracking system.

Strengths

~

q The licensee continues to use and improve'on their online maintenance procedure and implementation.

Overall maintenance activities performed under this program were well planned and executed.

The craft work force is motivated and overall skill level is high. The licensee has completed the development of their maintenance rule and it will be in place and 4

operating by the end of September. The predictive maintenance-crganization continues to provide early indication of pending failure and assists in root i

cause evaluation of equipment failures.

Weaknesses Weaknesses have been identified in the following V

areas:

' !n f

.9 15

~

Procedural adequacy Procedural complianse Installation of incorrect parts.-

Personnel errors in work performance Surveillance tracking system Equipment failures

=

Control of lifted leads / jumpers Communications

=

Conclusion Maintenance performance has declined.

Equipment failures have impacted plant operation. Craft personnel are not identifying and correcting procedural deficiencies and are using procedures as general guidance.

Individual and group performance is generally excellent for high visibility jobs, j

but attention to detail appears to lapse on routine work.

)

j Enaineerina i~

Summary of Previous Assessment The previous assessments for this SALP cycle concluded that engineering was generally strong. Good support of the Unit 2 outage was noted, as was good QA with respect to fuel fabrication and receipt inspection.

Last Six Months o

Engineering at St. Lucie remains strong. The trend in the i

1 number of issues over the past two quarters has gone down.

However, a number of issues in the area organizational / program communication have arisen. Recently.

there was an upward turn in the number of engineering issues l{-

' during the recent shut down. Those issues are being inspected.

In the aggregate, St. Lucie Engineering has provided valuable support to Operations and Maintenance

].

l; throughout the past year.

il~

Conclusion Engineering continues to perform well. No weaknesses have been identified in this functional area.

l:

I Plant Suocort

,1:

l I

Radioloaical Controls The' radiation protection' program continues to adequately maintain external and internal radiation exposures ALARA and within n__________

_ _ _ _ _ _ _ __ _ a

l 16 1

regulatory limits. The licensee adequately incorporated revisions to the radiation protection program for implementation of the new requirements of 10 CFR Part 20. The licensee continued efforts to reduce respirator usage while maintaining personnel exposures TEDE

.)

ALARA..The licensee. maintained adequate c_ontrol of radioactive material to include adequate radiological survey activities.

Fearaency Prenaredness The licensee continues to maintain an effective EP program.

Security Security upgrades made prior tu the last SALP were notable. The licensee continues to maintain a very effective security program.

e.

i Fire Protection The licensee continues to maintain an effective fire protection program.

4 Housekeepina Housekeeping has been generally very good.

y Nl SIGNIFICANT EVENTS P.A R T 3

l Q

3.1 SIGNIFICANT EVENTS BRIEFINGS (Past 12 Months)

JI Unit 1: None this period Unit 2:

Failure of a GE AK-25 Trip Circuit Breaker 1

3.2 ENFORCEM NT STATUS / HISTORY (Past 12 Months)

'j Currentlyi there is one escalated enforcement actions pending at St.

Lucie.

STAFFING AND TRAINING PART 4

l; 4.1 OPERATIONS STAFF - OVERALL (9/95)

Average performance of the operations staff has been noted. Control room demeanor of personnel is above average.

4

)

k Number of Shifts:

(RCO, SRO) Five' shift rotation, 8-hour

. shifts; (NPO, ANPO,-SNPO) Five shift 1[.

rotation, 8-hour shifts.

Number of SR0s:

38 active /13 inactive / 51 total Number of R0s:

23 active /1 inactive / 24 total f

y 17 Total Licensed Operators:

61 active /14 inaain/ 's total 4.2 WORK FORCE (8/94) ff.L Contractor Plant personnel-(excluding 699 122 i

disciplines below)

Training 64

.0 Quality Assurance /ISEG/ SPEAK 0VT 39 0

Materials M.nagement 47 0

j Security 11 122 Site Engineering 48 0

4.3 OPERATOR OUALIFICATION/REOUALIFICATION PROGRAM (Past Two Years) 4.3.1 REQUALIFICATION PROGRAM Last Inspection - 9/26/94, inspection Report 5",335,389/94-19

'Next Inspection - 10/96 4.3.2 INITIAL EXAMS Last Exams 10/17/94 -

2 R0 2 passed for 100%

9 SRM 9 passed for 100%

Next Exam 3/25/96 -

6 R0 4.3.3 GENERIC FUNDAMENTAL EXAM Next Exam 10/3/95 - 1 applicant 4.4 PLANT SIMULATOR

.The simulator is on site and fully certified to meet ANSI /ANS 3.5, 1985.

4.5 INPO ACCREDITATION All trainingJ rograms are maintaining INPO ' accreditation.

The site 4

specific simulator has been used for training since 1988 and has been fully certified for approximately 5 years. NRC inspections in the form of operator examinations,at the simulator have found no serious problems.

m.

18 INSPECTION ACTIVITIES PART 5

5.1 INSPECTION FOLLOWUP OPEN ITEMS

SUMMARY

(UNITS 1 AND 2 COMBINED)

(10/6/94)

Pre Change from Division J_

Total Last Report DRP O

18

-12 DRS 0

14 7

DRSS

_A

_1

-1 Totals 0

33

-6 i

Note:

Each item that applies to both units is counted as one item.

5.2 MAJOR INSPECTIQRS D31t lyR1 89-02 1/89 RG-1.97 89-03 3/89 NDE 1

89-07 3/89 EQ 89-09 3/89 Design Control 89-24 10/89 Maintenance Team Inspection 89-27 11/89 E0P Followup 90-09 4-5/90 OSTI 91-03 2-3/91 EDSFI 91-18 9/91 MOV (no negative findings)91-201 9-10/91 Service Water Inspection j

92-14 7/92 Emergency Preparedness Program

!j "

92-17 7/92 EDSFI Followup 93-01 1/93 Check Valves 94-11 5/94 MOV Followup j

95-05 6/95 Engineering 5.3 PLANNED TEAM INSPECTIONS None 5.4 INFRE0 VENT INSPECTION PROCEDURE STATUS No core modules are overdue at this time.

5.5 SIMS STATUS - OPEN TMI ITEMS _

There are no 6 pen TMI items.

2 J

J

s

' ~

• PRED3CISIONRL ST. LUCIE 1 PI ETENTS FOR 94-3 NONE PI ETENTS FOR 94-4 SSF 10/23/M LERs 335 Moo 6 50.72s: 27M 0 l

PW NIST: CluSITION EXISTB IN ALL INSES UP TO 1005 POWR $!NCE 1978.

j GROUP : CONTAIWENT Ass CONTAfleWIT ISOLAT10N GROUP j

SYSTEM REACTOR rlEulTAIIBENT SUILDING j

DFSC

A 9E81011 ERRER calls MVE ALLOWD CROBS TRAIN PRESSURIZATION OF All.!DLE CONTAllWIENT SPRAY Msep REmlLTIIIS IN A RELIEF WALW LIFTilIG AS CINITAlWENT SIAF IINEllTORT LOSS TO THE AUKILIARY Bh!LDINS IN EXCESS OF DESi m LIMITS.

t' SCRAM 10/26/M LERs 335%107 ' 50.728: 2795A PW HIST: POWER OPERATIONS AT 100x DESC A REACTS TRIP FOLLGm A 804IN TWBINE TRIP. TNIS OCCURRED WIEN A FAULTED SWITCM TARD POTENTIAL 3'

TRANSPtWER CAUES A IIAIN GEIIERATE LOCEIRJT.

SSA 11/22/M LERs 33596009 50.728: 20060 - PWR NIST: COLs SuuTDOWN 1

1!l DESC 00TN EDGS STARTS ON AN SIAS. ONE EDS LOADED ITS BUS WlEN AN ASNOWIAL ELECTRICAL LIIEUP COMINED

}{

WITN AeolTICIIAL Lote!NG FROM THE SIAS CAUSED THE sus assanst TO OPEN.

l SSA 11/22/M LERs 335M 009 50.72#2 20060 PWR MIST: COLD SNUTDOW DESC

AN SIAS OCCURRB taEN TW 0F FOLR PRESalRIZER PRESSURE TRANNIITTERS DRIFTED NIGli DUE TO ENTRAPPS i

NTDROCEN. THE C80ARGilIG MSFS WRE SECURED SEFORE TIIE LTOP SETPo!NT WAS REACNED.

4 SSA 11/24/M Leas 33596010 50.72s: 2a068 PWR NIST: COLD $NUTDOWN DESC Ale IllADVERTENT SAFETT !alJECTICII ACTUATION SIGIIAL OCCURRED DURING REACTOR PROTECTIVE AS ENGIIIEERED SAFEIRAARDS SYSTEN TESTilIG WNEN A PRESSURIZER PRESSURE IISTA8LE TRIPPED. TIIE CAUSE WAS A DEFICIENT j]

PROCED42E.

ll FI EVENTS FOR 95-1

)

4 i

SSh 02/16/95 LERs 33595001 50.72s: 2e400 PWR NIST: POWR OPERATIONS AT 100x j

DESC

WILE RESTORIIIG A SAFETT SUS TO A IIONIAL LINRP FOLLOWING RELAT REPLACBWIT, flIE BUS WAS DEEMERGIZED. THE EIIERGENCY DIESEL STARTED AS LO409 CNTO THE SUS.

^

FI EVENTS FOR 95-2 j

i mowE i

j i'

to

1 PREDECISIONAL Legeft:!:

g

((

{ j

$hutamen a coeros. 72 hrs. 4 Startte Refuenng R

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~

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Commercae Noirs forced Outcge Rate (s)

=

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'"S'''S'**"

Peer Crow: Correustion Er9neereng w/o CPC

)

92-3 to 95-2 frenos and Devetae Deviations From Plant Peer Group Self-Trend Median Short Term Long Term D'C'i"'d

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OPERATONS (including startw) l Automatic Scrome WNie Criticci.

or

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o

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'#REDECISIONAL l

ST. LUCIE 2

'r i'

-FI EVENTS FOR 94-3 mn i

PI EVENTS FOR 94-4

-?

NONE PI EVENTS FOR 95-1 SCRAN 02/21/95 LEts 38995002 50.728: 2E16 mat NisT: POW R OPERATIOut AT 100K DESC

A REACTOlt TRIP RESULTED FROM A LOW STEAM GENERATOR LEVEL AffER A STEAM GENERATOR LEVEL INSTRLSENT FAILED NIGN, CAU$!#G THE FEED RESULAfinG VALVE To CLost.

_PI EVENTS FOR 95-2 i

J A

I.

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PREDECISIONAL Legend:

~ '

ST. LUCE 2 aerwenng a

coerseen hastry Avg Trone 9mstooen M 92-3 to 95-2 Owtry Data g

g

~

l I I I

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rear - omrter voor - owrier Siyviksrit bents Safety System Fakes C

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4 wa-.

.>.y u-.

e-i es-.

m.i wa-.

m>.1 m>-.

w-r es-e m.m ouorter Year - Quarta voor Forced Odages/

Forced Odage Rate (s)

Commercus texts goc go

{ go,

C*'

I4'

$ m.

5 w

aa.

g

!2.

$ 20.

f a

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Year = ouarter Year - ourter 1,

MM ftedation Dpasste

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o. Uc Coer

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?REDECISIONAL l

M2 5'*5'-''

t usewn Peer Group: Corrcusten Engineenng w/o.CPC 92-3 to 95-2 Trenos ono Devetions Deviations From Plant Peer Group Self-Trend Medien Short Term Long Term Declined improved worse Better TN

~.

Automatic Scrams WNie CriticcW.

o

o. s Sofety System Actations -

o os:

Sigraficet Events -

o o

Sofety System Fcatures o

045 Couse Codes (E LERs)

I' i

g

.=.

w. -

.. w o.

q 3..

3.a

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1

=.

j i

SHUTDOWN

\\

l Sofety System Actuotions.

o

-022 Siipifecont Events a

o o

i ~

7.,

l Sofety System Fai4ures.

c 0.72 Cause Codes (E LERs)

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FORCED OUTAGES Forced Outoge Rote *.

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. ~,,a 4

PAGE' - 1 l

ST. LUCIE OPEN ALLEGATIONS AS OF 09/12/95 ALLEGATION: RII-94-A-0105 FACILITY:

ST LUCIE 1

~

DATE RCVD:

940520

SUBJECT:

WELDING SUPERVISOR RECEIVED NEGATIVE PERFORMANCE APPRAISAL A DUE DATE:

951030 ND WAS THEN WAS REMOVED FROM SUPERVISORY POSITION.

DAYS OPEN.

480 ACTION PNDG:

AP: DOL ACTION.

NO SAFETY ISSUES. 0! ACTION PNDG RSP DIV:

EICS LCA:

LCA: 06/09/95;LTR ACTION DUE DATE: DUE:

ALLEGATION: RII-94-A-0220 FACILITY:

ST LUCIE 1

.I DATE RCVD:

941215

SUBJECT:

FITNESS FOR DUTY CONCERN. AN INDIVIDUAL WHO HAS WORKED AT DUE DATE:

950828 NUCLEAR PLANTS FOR MORE THAN 20 YRS CONSUMES SIGNIFICANT DAYS OPEN:

271 ACTION PNDG:

AP: CLOSURE MEMO PROVIDED TO EICS ON 7/5/95. EICS AMDIN CLOS E

RSP DIV:

EICS LCA:

LCA: 05/13/95; LTR ACTION DUE DATE: DUE: 07/07/95 4

3 ALLEGATION: RII-95-A-0001 FACILITY:

ST LUCIE 1 DATE RCVD:

950103

SUBJECT:

ARMS ROOM 000R LEFT OPEN AND UNATTENDED i

DUE DATE:

950823 DAYS OPEN:

252 ACTION PNDG:

AP: EICS ADMIN CLOSE.

IR:

1 RSP DIV:

EICS

_.~

LCA:

LCA: ANONYMOUS ACTION DUE DATE: DUE: 08/30/95 I

ALLEGATION:

RII-95-A-0002 FACILITY:

ST LUC.IE 1 DATE RCVD:

941222

SUBJECT:

CI ALLEGES THAT WELD REPAIRS CONDUCTED, A COUPLE OF YEARS AG DUE DATE:

950822 0,

ON THE TURBINE COOLING WATER AND COMPONENT COOLING WATER DAYS OPEN:

264 ACTION PNDG:

AP: EICS PREPARING CLOSURE LETTER IR:

RSP DIV:

EICS LCA:

LCA: 08/11/95;LTR ACTION DUE DATE: DUE:

3 m

i i

PAGE-2 t

ST. LUCIE OPEN ALLEGATIONS AS OF 09/12/95 ALLEGATION: RII-95-A-0026-FACILITY:

ST LUCIE 1

~

DATE RCVD:

950227-SU8 JECT:-

016 REFERRRAL - ALLEGED DISCRIMINATION FOR REPORTING SAFETY DUE DATE:

951030 CONCERNS REGARDING SYSTEM CONFIGURATION, MAINTENANCE AND THE DAYS OPEN:

197 ACTION PNDG:

AP: P82 INSP COMPL. PROVIDE CLOSURE /IR TO EICS-BY RSP DIV:

DR9/PS2 LCA:

LCA: 03/02/95; LTR ACTION DOE DATE: DUE: 09/29/95

[

ALLEGATION: RII-95-A-0033 FACILITY:

ST. LUCIE & TURKEY POINT DATE RCVD:

950312

SUBJECT:

ANONYMOUS - THE CONTRACTOR WHO

. WON THE SECURITY AND FIRE

'DUE DATE:

950830 WATCH SERVICES IS NOT COMPETENT DUE TO QUESTIONABLE SECURITY DAYS OPEN:

184 ACTION PNDG:

AP: EICS ADMIN CLOSE IR: 95-08 i

RSP DIV:

EICS LCA:

LCA: ANONYMDUS ACTION DUE DATE: N REQUIRED.

I ALLEGATION: RII-95-A-0039 FACILITY:

NORTH ANNA, SUMER & PCI i

ENERGY SERVICES DATE RCVD:

950322

SUBJECT:

PCI IS LETTING MACHINISTS i

CROSS TRAINED AS WELDERS WELD ON C

,0 DUE DATE:

951022 CRITICAL WELDS, WHEN WELDERS QUESTIONED THIS PRACTICE THEY W DAYS OPEN:

174 ACTION PNDG:

AP: DRS/ENG PROVID CLOSURE MEMO TO EICS BY 9/1. DRSS/RPEP REVIEW DOSE ISSUE RSP DIV:

DRS/ENG DRSS/RPEP LCA:

LCA: ANONYMOUS ACTION DUE DATE: DUE: 09/15/95 5

ALLEGATION: RII-95-A-0065 FACILITY:

ST LUCIE 1 DATE RCVD:

950508

SUBJECT:

MULTIPLE CONCERNS INVOLVING

-PUBLIC NOT NOTIFIED OF EVENTS, DUE DATE:

950808 OUTDATED TECH MANUALS, VENDOR DRAWINGS NOT UP TO DATE, POOR DAYS OPEN:

127 ACTION PNDG:

AP: PB2 RVW ISS 1, 2, 3, 4, 8.

(EVENTS, MANUALS, VENDOR DRAW.

INGS, SPEAK 0VT) RPEP RVW RAD RELEASE, ENG RVW ISS 5, 6, 7-a RSP DIV:

DRP/PB2 DRSS/RPEP DRS/ENG l

i LCA:

LCA: ANONYMOUS ACTION DUE DATE: DUE:

4 f

PAGE 3

1 x

ST. LUCIE OPEN ALLEGATIONS AS OF 09/12/95 ALLEGATION: RII-95-A-0083 FACILITY:

TURKEY POINT &.ST LUCIE DATE RCVD:

950627

SUBJECT:

REGION I RECEIVED A COMENT FROM AN INDIVIDUAL THAT PEOPLE DUE DATE:

950930 IN RECE!PT INSPECTION DID NOT KNOW WHAT THEY WERE DOING.

DAYS OPEN:

77 ACTION PNDG:

AP: 8/10/95 LTR TO ALGR REQUESTING SPECIFICS FOR AN ARP MTG IR:

RSP DIV:

EICS LCA:

LCA: 8/10/95; ACK LETTER ACTION DUE DATE:

l 4

e f

I

[

i

~~,

1

)

i o

e S

4 d

3 2

?

?

ATTACHMENT 3

)

i NRR ASSESSMENT FOR ST. LUCIE i

September 1995 i

CURRENT ISSUES

-Seismic qualification of electrical and mechanical equipment (GL 87-02, USI A-46) issue on Unit 1 is still not resolved. The staff. issued a letter in early 1994 providing a general framework of criteria which would resolve this issue. FPL responded in May 1994 restating their previous position and stating that they j

believe that further NRC requests for work, evaluations, or plant changes would provide no additional safety benefit to their nuclear facilities. The staff is considering performing a backfit analysis to determine the possibility of ordering FPL to implement additional actions or accept the licensees position. A third alternative being evaluated is performance of a site inspection to determine if any safety-significant issues exist in the areas of disagreement.

-Unit I will be replacing steam generators in 1997.

The licensee is well into,

planning for the event.

-An alternative approach to the resolution of the Thermo-Lag issue was proposed by i

FPL, however, the staff did not pursue review of this performance based approach based on Commission direction of this issue. The licensee is scheduled to submit to the staff by.early November 1994 a schedule and method for resolution of the Thermo-Lag issue.

-The plant continues to perform well.

The latest SALP evaluation had ratings of I in all categories.

Contact:

Jan A. Norris 504-1483 me

4

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Operational Period August 1.

Tlirougli Sept eniber 12, 1995 1

2 3

4:

100 -

.I 80-1.

On October 26, 1994, the unit tripped from 100 percent power due to a loss of electrical load. This was the result of arc-over in a potential transformer in the switchyard due to salt buildup. The licensee then

'"*" "' *"S*

""'c" *** 6a 'ch'd"'*d **" '*""

C 60-

'"''d * "."he unit was returned to service on November 29.

days later T

A 2.

On february 21, 1995, the unit was removed free service for the b

replacement of pressurtzer code safety valves which had been leaking by

.the seat since shortly after startup in Noveeber, 1994. The unit was Z

returned to service on March 8.

N 10 -

C.>

On July a. 1995, the unit tripped during turbine valve surveillance 3.

testing. It returned to power on July 12.

N On August 1, 1995, the unit was shutdown as a result of Hurricane Erin.

4.

b Due to a series of equipment problems and personnel perfonnance issues, 90 -

the unit is presentir shutdown.

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A M

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PERIOD OF OPERATION Graph does not include power reductions for routine repaifs, wat erbox cle,aning, or required repairs.

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ST J('IE 2 Operational Period August 1,

Through Septeniber 12, 1995 1

2 100 1,3 80 -

ct:

W Si:

60-1.

On February 21. 1995, the unit tripped as a result of low steam p

generator water level. The condition was the result of a feedwater Z

. regulating valve closure af ter a steam generator water level control level transaltter failed high. The transaltter was replaced and the g

40-

-it was returned to service on rear ary 25.

O Ct; 2.

On August 1. 1995, the unit was shutdown as a result of Hurricane M

Erin. It was restarted on August 4. 1995 but.

20 -

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A S

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F M

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A S

i PERIOD OF ~0PERATION 1

Graph does not include power reductions for routine repairs, waterbox cleariing, or required repairs.

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4 a i ATTACBENT 7 j

MIPC0005 REDION 2 OuARTERLY ACTIVITT SCNEDULE 09/13/95 s0RTED IT FACILITY /ACTivlTY START DATE PAGE 23 FAC ACTIVITT RESP LEAD TM ACTIVITY 18 25 02 09 16 23 30 06 13 20 27 04 AseR -

10 NAME ORG EMP $2 TARGT Of SEP OCT NOV DEC TP3 R000 CUTAGE REFUELING 2000 KDL 0 09/04/95 ***** ***** **

REC INSPECTION 2411 C00 1 11/13/95 TP3... A601 5ElsMIC INSPECTION N000 TFJ 9 11/13/95 J

TP3... A011 4

TP3 A012 SEISMIC INSPECTION N000 TFJ.

9.12/04/95 TP3 A757 EP CORE INSPECT 10N 2412 KFB 1 12/18/95 TP3 A905 SFGDS INSP 2421 LKS 1 02/26/96 TP3 A111 REC INSPECTION 2411 CQR 1 04/01/%

TP3 A900 2515/127 ACCEst AUTN 2421 WJT 1 05/20/96 TP3 A903 SFGD5 INSP 2421 LKs 1 05/20/%

TP3 A401 INITIAL EXAM 2321 GON 4 06/17/96 TP3 U904 SFGD$ INSP 2421 WJT 1 06/24/%

TP3 A400 INITIAL PREP 232t 00N 4 06/24/96

)

. TP3 $000 END CTCLE 13 2200 0 08/17/96

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w MIPC0005 aEG10W 2 GUARTERLY ACTIVITr SCNE00LE 09/13/95 sonTED BY FACILiff/ACTIvlTY STAaf DATE PAM 24 FAC ACTIVITT RESP LEAD TM ACTIVITY 18 25 02 09 16 23 30 06 13 20 2T' 06 ASSR 10.

AWWE ORG EW SZ TARGT OT SEP OCT NOV DEC TP4 R000 cuTAGE REFUELING 2000 KDL 0 03/01/96 l

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SEPTE.

12, 1995

-.[

ST LUCIE a

i Site Intearation' Matrix 4':

L-

_K osecripeien ideptified D

D.t. '

Sai, R.f.

Cause F. A.

3 9/7/95_.

OPS }

IR 95-15 Personnel Errort Licensee Unit 2 Main Generator overpeessunted wide REing inoperable with H2. Onettention by operatore.

Equipment 9/2/95 OPS IR 95-15 Personnel Error NRC Weaknessee identified in logo relating to abnorrnal espaprnent condenone and out of service espapment notlogged 8131/95 MS IR 9515 Personnel Error Self Identifying Damaged cyimder and head on 18 EDG due to loose lash "

u..:

g 8t30/95 PS IR 9515 Management and NRC Centainment closure walkdowne by management OC weaknesses were inadequate end i; _ ' ' hoewdy on OC iswelvement to identify deficiencese 8/30/95 MS IR 95-15 Superwoory NRC Memtenance personnel not using procedures for oversight and wed in progrees.

+

worker attitude 8/29/95 OPS OR 95-15 Personnel Error Licensee Started 15 LPSI purre with suction valve cleoed.

.t 8123/95 MS IR 9535 Equipment self Identifying 2A HOP trip due to relay failure.

Failure /

Inadequate i

Corrective Action 8/22/95 PS IR 95-15 Personnel Error NRC QA failed to document a de6ceeney identified in en

[

audit.

8/19/95 OPS IR 9515 Operator Errorf Self Identif eng OverfiN of PWT.

Operator gl Workeround 8118195 MS IR 9515 Procedural NRC Precedural weakness involving supervisory oversight Weaknese and joumeyman qualifm.eteest.

8/17/95 OPS LER Ut 95 Procedurst Self Identifying Spreydown of Unit 1 -1 007 Weakneset Operator-Work-Around

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S/9/95 MS LER Ut 95-Maintenance /

Licensee perstde Unit 1 PORVs due to ensintenance 005' Testing errors error /teenne inadequacy t

s/6/95 ENG LER UI 95-~

Corrective Self identifying Uftme of Unit 1 SDC thermal relief due to precedural

• w 006-Action / Procedural reviesen from previous conective action.

Weakness 1

S/2/95 OPS-LER Ut 95-Procedural Licensee 1 A2 RCP seat festers due to *restegmg* et lugh 004 Weakness tersperature.

dt2!95 OPS LER U1 SE Operator Erroe Self identifying Operator famed to block MSas actueeon during 04 oseidown.

s:

7/29/95 MS IR 9514 Prodcodural Stif Identifying l&C pereennel ettempt to meet a lowel switch circuit -

Weakness widah eeuld not actuate given eyetern condisons.

7/29/95 OPS BR 9514 Operator Self Identifying Turbine / Reactor Trip due to teet error.

Error / Procedural Weakness 7/29/95 MS IR 94-14 Root Cause Self Identifying C_^

^_,0., fedure of Urdt 2 9 train CEDM coolms Pending fen.

7/3/95 PS IR 9514 Security Self Identifying Aistemolute passed through normsey closed security Weaknese gate to plant intake / discharge conste et beech.

3 Subsequent scendent reeutted in welecte lodged in discharge canal pipens-7/1/95 OPS IR 95-12 Week Log NRC Weaknesses identsfied in loge relaung to bettery Keeping jurspor installation and outef-oorweee equipment 7/1/95 MS IR 3512 Memtenance Self 4dentifying Corresson in treneformer fire protection deluge j;

system seeutto in muleple feihares.

m 7/1/95 PS BR 95-12 Personnel Error NRC Three pieces of S8dM found :..e-_._ rg tagged NCV 9512-y*

O2 7/1/95 PS tR 9512 Progr&m NRC Fire Ptotection prograrn weaknesses idenefied in Gre-Weaknessee Eghting techniques and roepirator 7

~^

program.

7/1/95 MS 1R 95-12 Personnel Error NRC M&TE fewnd instened acrose bettery ces without l

NCV 95 JAL outhenzenon.

l.

01

-l i

6/3/95 MS IR 9510 Procedural NRC Several esemples of week edherence to procedures.

Adequecy/

enetudsng step signoffe and ? '.._ i t worification, i

Adherence identlSed l

6/3/95 M5 IR 95-10 Poor Commurece-Licensee Peer n

_"eeenAmek of deteBed enstnsctionleads 4

tien to heproper IS EDG governer instesation.

6/3/95 MS tR 95-10 Poor NRC HVAC systems fee both unite poorly Maintenance / Proc enenntained/Opereeng procedures contained 33 edures a: deAcsoneses l-1 hh ',

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IR 9510 Poor Surveillance Licensee wessed several nuevespences'f7 deyt on EDG.

T.

NCV 95 Tracking System 01.

J 4/29/95 -

MS.

IR 95-09 Personnel Error Ucensee Failure to perform poeconnel air lock tesema on time.

NCV 95 01

+

4/28/95 OPS tR 95-05 Corrective Action NRC STAfUNCR program did not addrese evaluetmo poet Program eporebilsty Weakness Liddneee incere Instrumente et ICI Flenge 8 miewired - ICI 4/28/95 MS-IR 95 OS Maintenance Error oveput signefe dwected to wrong cornputer pointe.-

4/28/95 OPS IR 95-05 Weaknees in NRC Weakness in addressing how enedo would effect Temp Mod contrat room drowings.

Procedure 4/28/95 ENG IR 95 05 Failure to NRC Failure to document nonconformance regardmg IC8 NCV 95 Implement flange 8 con 6tione.

04 Corrective Action Progrem 4

4/28/95 MS BR 95 05 Desegn NRC Installeeon of wrong overtoed heater models an "

swine.g.w.

s VIO 95 05-Implementation 01 Discrepency 4/1/95 OPS IR 95-07 Apparent Licensee Uret 1 empenenced en approximate 14 eninute lose of NCV 95 Personnel Error shutdown coolmg while stofting from one shuulown 02 cocems loop to the other. The teet cause wee the

< dooms of the wrong SDC ouction % velve Ithe vilwe for the opereeing, wice isNo. purnp) en the part '

of the operator.

4 4/1/95 MS IR 95-07 Poor Adherence Licensee Jumper left installed in ECCS venellenen damper NCV 95 37-to J/LI. and after work complete.

02 Maintenance Procedures 4/119 5 OPS IR 95-07 Week NRC Week ennunciator response by ROs contributed to Annunciotor less of shutdown cootmg event.

Response

3/26/95 MS BR 94-09 Procedural NRC LPSI macherocal seal houems outer cap noemeteRed.

Weaknees 3/26/95 OPS IR 94-09 Operator NRC Operator feiture to recognate out-of-sight high Error /Proced-ures inecamen en EDG coeling weser tank. Femure of Weaknese pseesdure to inceude inoeswomeno en dreisdne tenk.

3N)4/95 ENG IR 9544 Design Ucensee SOC emotion remef wfwe mit due to weser hemmer.

3/04/95 OPS IR 96-04 House-NRC Leese plastic detwie found in Unit 2 fuel peel stee.,

keeping

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MS-IR 95-04 Egepment Fedure Self identifying

.s 1 wee shut down for the.

- :cf 3 i

p peescueiros code oefety valves.uThe valves were :

l-leelung by the oest.

,k 2121/95 '

OPS IR 95-04 Egepment Failure Self Identifying -

Unit 2 tsip due to faawe of a SGWL cenerallevel -

tronenwateri Trenenutter famed high, reauleng in j.

eleeure of the FRV and a sehengsent tsip enlow ggg pg i

+

2/20/95' OPS

'IR 95-04~

Egepment Self identifying -

25 LPSI pump fewul air-heesad seusing survesence' l

Anomaly tesesng. The licensee hoe theesized that the migree6en of air in the eyeese resumed in the '

',p condmen as a reeues of prowieue sesrveimance testing The pumpe are not e.Il-venslag.

2/17/95 MS OR 95-02 Physical NRC.

Numoreue eroes of u..

Idenseed in Unit 1/2 Co.dra e CCW areas.

t 2/17/95 PS IR 95-03 Personnel Error NRC in two sheerved esercises, Eco failed to notify etenes

i ITraining within 15 minutes.

Weakness '

+

2116/95 MS IR 95-04 Meineenance Self identifying Lead shed of the 1 A3 IE 4130 hus due to Errorf inedwortent lumper coneoct while rm a Procedural degraded voltage reley.

1 Weaknese 214/95 OPS tR 95-01 Operator Licensee Failure to sample SIT within TS romered eme frame VIO 95 Error /Com-fellowing volume addoelen. Second occweence in 2 01 veere.

214/95 OPS ~

IR 95-01 Poor NRC Failure to idonefy and analyze Unit 1 hot ;eg flow Communscetions ser*%

2/4/95 MS 1R 95-01 Personnel E rori Self idenntving inedessate independent h resulted in CVCS VIO 95 Program leadown control valve falling to roepend elue to i

02 Weaknese reversed leads. Resulted in a cessemon of letdown i

New.

t

. 7 12/31/94 ENG IR 94-25 Engmeenne Self Identsf ying inedegsees dowen control of NeOH cross-connecten I

NCV 94 Desson Erree between ECCS trains.

01 4

t 12/3/94 PS IR 94-24 Procedure Review Ucensee Feture to perform TS-respuued perieshe procedure

?

NCV 94 '-"^^^y reviews.

01 1

12/3/94 MS IR 94-24 Maintenance NRC W=a= process for ehenges te vender technseel l

VIO 94 ~4-Procestures noenuelo.

O2 Inedegsecy I

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g-11/25/9, MS IR 94-21 Program Licensee

., Econeee's OA orgerdaseien idonefied roameteue weakness weakn

e. in the 1

-_ eeien of the site o l

wekene program. As a reedt. the Maintenance if Manager placed e step work order en wohNng acadeles The stoppage leased om week.

.11/24/94 MS IR 94-24 Procedure Self-identifying Unit 1 B side SIAS actuation due to a bietetde t

weakness medde w9dch had not been '

,- withdrawn from the ESFAS cabinet during maintenance

['

11/23/94 MS IR 94-24 '

Equipment Feaure Seit identifying Unit 1 SIAS with uret in made S due to common mode feEure of Rosemount evenenesters used for

,g pressunser pressure channaio.

11/5/94, OPS IR 94 22 Operations.

Licensee Weste gas valosse on Sept. 10,1993, with '

NCV 94 Maintenance messorological L ;_..__ eut of service.

03 Errore 10/26/94 MS IR 94-22 Weather-Retened/

Self Identifying Unit 1

--?- tripped due to arc-over from a LER Memtenance potene6el trenoformer due to eset tuohfup on awitchyard insulators.

9/30/94 OPS IR 94-20 inconsistent NRC Looel valve poorten indicaters not enemaamed MS Espectatione eneurste. Precedures/treining prowided se operatore en wenfving valve poesmon found week.

9/30/94.

OPS IR 94 20 Operations.

NRC Plant personnet not tremed on IPE and not wenne it Maintenance

,for work plannmg and e-C * " e.

Deficiency 9/30/94 OPS IR 94-19 Operatione NRC Dudng secluel enem, a Econsed operator omhituted en Weekness apparent diseegard for EOPs.

9130/94 MS IR 94-20 Personnel Error Licensee Meineenance personnel begin to work the wrong RWT imeleolon wahre, threatening the operetsie6ty of both trains of ECCS.

9/30/94 Of8S -

IR S4-19 Operations Error Licensee Fatwo to notify the NRC of changes in otetus of MCV 94 Boonsed operators' rnedical cendloone 31 l

g/29/94 _

OPS OR 94-20 Operations Errore NRC Operecere pieced 1 A EDG in en electrical Enoup for l

VIO 94 whlott TS-resluired survetenee teste had not been I

01 perfesmed (with the esfotyrelated swing bus VeO 94 powered from it). Aloe, related centrol reem leg

,i O2 enedes appeared to be inecourese.

t f-8/28/94 -

OPS IR 94-20 Eslusprnent Foaure Licensee UeJt I wee taken off line tenede 2) to repair a DEH leek. The isedt wee retumed en une loser the some.

day.

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NRC_

. e beenees wee usdesens new fuel for Unit l 'wieli Momeonence a hoist grapple sties wee neossne tete setety leech.

Error and Lack oc steewe necesing pin. The seeeev_elsewe funemoned by.

Engmeenne facten eedy.

Deawinge/In-spection Cntana

7/14194 MS.

m 94 Eqimpment Licensee /NRC Dunne survedience test. TCS 5 famed to apen alue to.

5 LER U.2 94-Failure / Poor anschenical tunstmo micenseet. The licensee fateel se 06

!?. ;- -...nt secessere the cenemore se reguming a shutdown per -

Vt0 94 Decioson TS INRCI.

4 01 9

r m 9415 '

Egiepment Fedues Lic'ensee Unit 2 turtune wee shut down and seector power.

OPS.l 7/9/94 seduced to Mode 2 beesume tene 291 RCP lower es

~

levelish===i showed a leak. The inesasion wee later shown to be a;- -- -

7/s/94 OPSf a 9415 Operator Erros Licensee TS 3.01 entry due to pescing 2A1 LPSI pump and LER U2 94 28 charging puenp OOS et tine same esmo.

05' 6/2s/94-MS.

IR 94-14 Personnel Erroet Licene se Inoperande Urut 2 RAS woneitseien exhaust WRGM NCV 94 Procedural due to feiture to connect sample tusse.

01 Weasness LER U-2 94-

+

04 6/6/94 OPS tR 94-14 Weenhee Licensee Unit i teip froen 100% power during e severe thundersteern due to delwie hiewn acrose two main trenefoemer eueput terminale 5/2s/94 PS-IR 9413 -

Poos Corrective NRC Emergency supphoe in centeel reem less that stated DEV 9413 Action in FSAR.

l 01 I

5/6/94 -

ENG' m 94-11 Engineenne Erros NRC tr== data-se correceve action for MOVE wiuch staged '

VIO 94-11 spuring survemences.

01 4123/94' OPS E 94-12 Mfg. Error Self Idnetying Unit 2 auto reacter trip from 30% power eeused by LER U-2 94-HPS cabinet wising erver for trip bypees circuit, from i'

03 ensinalisnit constnsction.

(.{

Eqimprnent Faiture Seef-identifying -

F Jewing urut 2 anp. steem bypeos system opereced

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4/23/94 MS m 94-12 8

unesgnectedly and dropped RCS songs by seven l

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degrees F. preeeunter heatere numed off.

4/21/94-OPS.

m 94-12 Operates Licensee Unit 2 reacter power increases from 26 to 31% due ~

Insatenewonese to peeselve MTC.

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4/7/94 hts IR 9410 Memtenance NRC-teatractor personnel enade and contracter OC i

VIO 94 Error eseepted presouneer neerle weld prey that ed not 01 meet procedures regeremente for toewet one e.

s Licensee engineenng had seconned overly tight '

tolerances 4/3/94 OPS IR 9412 Operatione Sett identifying Uret 1 outo reactor trip due to unuouel electncel LER U194-Procedure Error bnoup lieochronous EDG parameled weth effeite -

04 (Lock of sufficient power through TCSel.

depth in tewiew1 4/3/94 ENG IR 9412 Surveillence Error Lic neee Licensee descovered that the 4100 V I AS Suel swing VIO 9412-bus consponente IC ICW Pump and C CCW Punpl i

01 would not stnp from the bue upon undervehage if the bus were shgned to the S bus due to e ressems wwe.

3/28314 MS IR 94 09 Personnel Error Sett identifyme Uret 1 oueo reactor trip. he foremen LER Ut 94-opened generator esciter breaker en wrong uret.

03 3/16/94 ENG iR 94 08 Engineering

$4RC W inepector had two Uret 2 SL4 wioletrone: il vio 9448-Corrective Action correcewe action for en 11/24/92 water hemmer 01 event woe done wethout documented instructions or VIO 94 08 procedures. resulting in operating unta 3/94 with fewe 02 enubbers on the SRV a.wi PORV teilpapee inoperstde.

21 Fedure to write e nonconformence report for e damaged pape support in March 1994 3/16/94 ENG IR 94-10 Equipment Failure Licensee A Uret 2 presemirer instrument notale that had been LER U 294-repened a year ego woe found Seeking while the unit 02 wee in Mode 5. The unit remamed shut down for

~ l repaire.

3/4/94 ENG IR 94 r)6 Engineenne Licensee inadequate design controle on Unit 2 esquencer NCV 94 Design Error charging pump loedmg block.

02 3/4/94 ENG IR 94-06 Engineenne Erros Licensee Fodure to report en EDG failure.

NCV 94 06-01 2/28/94 ENG IR 94-09 Refueling Licensee /NRC lesadequate grappime of a fuel essembly caused by NCV 9444-procedure &

error in Recommended Move List and operator error

j 01 operator error in fogowing procedure. OR 94-091 2117/94 OPS BR94C5 Operator Error Lmennee Pressustrer eux eprey isoletion velve had been NCV 9445-locked closed twice opent einee 3/27/s3.

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