ML20136C800
Text
.
REGION 11 ATLANTA, GEORGIA 1
l PLANT STATUS REPORT l
l ST. LUCIE .
Units 1 and 2
,/
i f
4 i
t i
1 l-
- February,1996- .
l t .
^ '
, 9703120188 970306 .
PDR FOIA BINDER 96-485 PDR ;;g , .
_' ~ - - - - - - - . .- - - - -
_J
1 l
I PLANT STATUS REPORT FOR ST. LUCIE l 1
TABLE OF CONTENTS PART 1 - FACILITY DESCRIPTION 1
1.1 FACILITY / LICENSEE....................................Page 2 ;
. 1.2 UTILITY SENIOR MANAGEMENT ...........................Page 2 i 1.3 NRC STAFF............................................Page 2 !
1.4 LICENSE INFORMATION..................................Page 3 1.5 PLANT CHARACTERISTICS................................Page 3 i
- 1.6 SIGNIFICANT DESIGN INFORMATION.......................Page 3 1.7 EMERGENCY RESPONSE FACILITIES / PREPAREDNESS...........Page.8 1.8 PRESENT OPERATIONAL STATUS (Past Six Months).........Page 9 1.9 OUTAGE SCHEDULE AND STATUS...........................Page 10 PART 2 - PLANT PERSPECTIVE ,
2.1 GENERAL PLANT PERSPECTIVE............................Page 11 2.2 SALP HISTORY (Past Two SALP Periods).................Page 11 2.3 " ELECTED 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 PART 5 - INSPECTION ACTIVITIES 5.1 OUTSTANDING ITEMS LIST
SUMMARY
.......................Page 18 l 5.2 MAJOR INSPECTIONS....................................Page 18 1
5.3 PLANNED TEAM INSPECTIONS.............................Page 18 l 5.4 INFREQUENT INSPECTION PROCEDURE STATUS................Page 18 5.5 SIMS STATUS (OPEN TMI ITEMS).........................Page 18 ATTACHMENTS
- 1. PERFORMANCE INDICATORS l
- 2. ALLEGATION STATUS -
- 3. NRR OPERATING REACTOR ASSESSMENT
, 4. ORGANIZATION CHARTS
- 5. POWER HISTORY CURVES ;
- 6. MASTER INSPECTION PLAN (NOT INCLUDED) l
- 7. SITE ACTIVITY SCHEDULE i
- 8. SITE INTEGRATION MATRIX
, 9. PERFORMANCE ANALYSIS GRAPH l 1
l l
l
1 l
2 i i
PART 1- FACILITY DESCRIPTIDN 1.1 FACILITY / LICENSEE FACILITY: St. Lucie Units 1 and 2 PLANT LOCATION: Hutchinson Island near Port St. Lucie, Florida LICENSEE: F1.orida Power and Light Co. (Corporate Office.in Juno Beach, Florida) 1.2 UTILITY SENIOR MANAGEMENT CORPORATE:
J. L. Broadhead (Jim), Chairman of the Board and CEO J. H. Goldberg (Jerry), President, Nuclear Division SITE:
W. H. Bohlke (Bill) - St.. Lucie Plant Interim Vice President C. L. Burton (Chris) - Services Manager L. W. Bladow (Wes) - Nuclear Assurance Manager R. E. Dawson (Bob) - Business Manager D. J. Denver (Dan) - Site Engineering Manager A. DeSoiza (Andy) - Human Resources Manager P. L. Fincher (Pat) - Training Manager' T. G. Kreinberg (Tom) - Nuclear Materials Management Superintendent J. Marchese (Joe) - Maintenance Manager C. A. Pell (Ash) - Outage Manager.
L. A. Rogers (Lee) - Systems and Component Engineering Manager J. Scarola (Jim) - Plant General Manager E. J. Weinkam.III (Ed) - Licensing Manager J. A. West (Jeff) - Operations Manager-1,3 NRC STAFF REGION II, Atlanta, GA:
S. D. Ebneter (Stew), Regional Administrator, (404) 331-5500 l L. A. Reyes (Luis), Deputy Regional Administrator (404) 331-5610 E. W. Merschoff (Ellis), Director DRP,'(404) 331-5623 K. D. Landis (Kerry), Branch Chief, (404) 331-5509 L. S. Mellen (Larry), Project Engineer, (404) 331-5561 E. Lea (Edwin), Project Engineer, (404) 331-3641 SITE: )
M. S. Miller (Mark), Senior Resident Inspector, (407) 464-7822 S. S. Sandin (Steve), Acting Resident Inspector, (407) 464-7822 9
]
I
3 NRR:
D. 8. Matthews, Director, Project Directorate.II-2, (301) 415-1490 J. A. Norris (Jan), Senior Project Manager, Project Directorate 11-2, (301) 504-1483 AE00:
S. Israel (Sandy), Reactor Operations Analysis 8 ranch, (301) 415-7573 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 Containment Type Freestanding Steel w/ Shield 8uilding Power Level 830 MWe (2700 MWt)
Architect / Engineer Ebasco NSSS Vendor Combusti'on 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 management 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.
span possible. Presently, a program is evbiving 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 I
i 4 .l 1
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. !
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. j Peactor Coolant Pressure Boundary
- On th'is 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 rafety injection (LPSI), and .
containment spray (CS) pumps' common containment sump suctions are l 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 normal complement of two automatic actuation isolati.on valves.
1.6.2 REACTOR SHUTDOWN Reactor Protection System l The reactor protection system provides protection for the reactor fuel and its cladding by providing. automatic reactor shutdowns i based on input.from reactor power, reactor coolant pressure, coolant temperature, coolant flow, steam generator pressure,-
containment pressure, turbine hydraulic fluid pressure, and, in
. Unit 2 only, Component Cooling Water. flow to reactor coolant pumps. The RPS is a redundant, four channel system that operates on a two-out-of-four logic.
ATWS Protection f.
I ATWS protection, outside the normal reactor protection system, is 1
- initiated via the ESF pressurizer pressure signal. It actuates by 1
, opening contactors in the output of the CEA MG sets, thereby interrupting control element assembly power at .its source. This I protection has been installed on both units per CE, the NSSS, recommendations.
R= ate Shutdown Facilities
, These facilities are' located in the switchgear rooms beneath each unit's control room.
~
1.6.3 CORE COOLING Feedwater System t
4 e
\
i
, 5 .
l The main feedwater. pumps are motor driven with each delivering 50 1 percent of the flow required for full power.
Turbine Byoass/Steas Dumo Capacity Each unit has five steam bypass valves, providing 45 percent of 4
- total capacity.
- Unit I has one atmospheric dump valve per train (two trains) and Unit 2 has two valves per train. Each unit-has the capability of dumping nine percent steam flow to the atmosphere.
Auxiliary Feedwater System i
There are two motor-driven pumps on each unit with 100 percent
, capacity per pump. There is one steam-driven pump on each unit 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 Feedwater Actuation System provided by the NSSS.
Emeraency Core Coolina System 4
In each unit, there are two HPSI pumps and two LPSI pumps with no unit-to-unit cross-connections. One pump of each type per unit will handle a postulated LOCA. The LPSI pumps also provide decay heat removal as required when the unit is shut down.
Decav 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 RCS (hot legs), passing the fluid through the shutdown cooling heat exchangers, and returning it to the RCS (cold legs). The heat removing medium is CCW - discussed in section 1.7.6 below. l Shutdown cooling flow path overpressure protection is provided by automatic isolation valves and various relief valves in'the l system.
1.6.4 CONTAINMENT !
Pressure Control / Heat Removal There are two containment spray pumps and four containment fan i coolers available per unit to suppress pressure spikes and cool l 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.
Hydrocen Control i
i I
)
1
6 LP ost-LOCA containment hydrogen control 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 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 apprnximately 10 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 (SBO) 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 Two trains of vital batteries per unit have been routinely tested i for four-hour DC load profiles. Recently,'following a cell 1 replacement, they have been tested for three-hour battery capacity instead. The battery capacity test is harsher than the load profile test and is. intended to more accurately reflect expected usage. There are four normal chargers per unit with swing chargers ~available for service. Non-safety batteries can be cross-connected to the safety-related, swing bus-if needed.
Instrumentation Power. ,
l Each unit has four inverters, two powered from each vital DC i
train, that provide four trains of instrumentation power. '
Station Blackout Resolution Status Unit 2 is a.four-hour "DC coping" plant per the original license ,
while Unit' l _is subject to the station blackout (SBO) rule of 10 i
CFR 50.63- requiring additional licensee action (unit-to-unft cross-connect of 4160V bus).
l
. l
)
. l 1
- j 4 . a 1
7' i i 1.6.6 SAFETY-RELATED COOLING WATER SYSTEMS i .
Intake Coolina Water (Service Water) i . Intake cooling water'(ICW) for each unit originates in the unit-common Intake Canal. The canal level varies with the tides since o it is filled by a level: difference between the' Atlantic Ocean and <
! the ICW pumps. One 16-foot and two 12-foot diameter. pipes pass under the beach to connect.the ocean and' canal. The intake pipe !
l ends in the Atlantic are covered by intake structures -(rebuilt in i 1991) intended to limit flow velocities, particularly' vertical F velocity, to reduce marine life entrapment. After use, ICW .
j returns to the ocean through the Discharge Canal and.under-beach l pipes. ;
Each unit has two trains of ICW plus a swing pump th'at can be ,
i aligned to either train electrically and physically. The licensee :
has converted the deep draft ICW' pumps from externally-(water) t lubricated to self-lubricated to increase reliability. The 100 i L percent (each) capacity pumps take suction from the intake canal l
- via a canal intake structure using traveling screen debris 1 protection. The intake canal structures adjacent to the ICW pump
. suctions are continuously injected with a hypochlorite solution to j reduce marine growth in the associated piping and heat exchangers. I The ICW pumps move water through two trains of heat exchangers ,
that cool component cooling water.(CCW) and two trains of heat
- exchangers'that cool main turbine cooling water. During a postulated accident, water flow isolates from the turbine cooling heat exchangers. The discharge from the heat exchangers returns via the discharge canal to the ocean.
, t
- Closed Coolina ' 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.
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 l fan coolers and the shutdown cooling (decay heat)' heat exchangers j (which also can operate as containment spray heat exchangers).
- Additionally, CCW cools a variety of bearings, seals, and oil t
coolers for the HPSI, LPSI, and CS pumps. A non-safety-relat.ed portion of the CCW system cools reactor coolant pump seals and the -
spent fuel pool. This section isolates upon engineered' safety features actuation. . .
l 1.6.7 SPENT FUEL STORAGE Wet storage capability' exists up to the year 2002-(Unit 2) and E
2007 (Unit 1). ,
) '
l r
8 l 1.6.8 INSTRUMENT AIR SYSTEM Instrument air compressors and driers on each unit provide all instrument air for Unit 2 and all but containment air for Unit 1.
Unit I has instrument air compressors inside containment.
1.6.9 STEAM GENERATORS Each unit has two large steam generators (SGs) rather than the
.three or four usually seen. The licensee has begun to focus on-a Unit 1 SG replacement in 1998. The SGs are under construction at the B&W Canada shops and a site organization is functioning.
1.7 EMERGENCY RESPONSE FACILITIES / PREPARE 0 NESS Emergency Operations Facility: 10 miles West of site, I-95/ Midway Rd., Exit Technical Support Center: Onsite, Adjacent to Unit 1 Control Room Operational Support Center: Onsite, 2nd floor of.
North Service Building The last annual emergency preparedness exercise was in February,1996.
This exercise was formally evaluated by the NRC.
- Since St. Lucie site has a high probability of hurricanes, communications facilities were improved following the Turkey Point experience with Hurricane Andrew in August, 1992. Improvements include
- ;
1 High Frequency Auto-link with other FPL sites and NRC.
Enhanced 900 MHZ System for site and mobile communications, with !
radio's also in the licensee's EOF and county emergency facility. l l
Cellular phones with hardened antennas. -
I Hardened Local Government Radio antenna ties.
. 1.8 PRESENT OPERATIONAL STATUS Availability Factors:
Unit 1 Unit 2 ,
1991 81.0 100.0~
l 1992 96.5 75.2 l 1993 74.0 71.8 1994 86.8 79.6 1995 (through 7/95) 93.9 98.3 Cumulative (through 7/95) 77.7 83.7 l
l 8
p s-. -,,1.s > a4 x ..n - , , ,n ...e., u~w.a+w-. ..uaa , , . .n .., w. an .u +- + - -u a se..
9 1.8.1 UNIT 1 OPERATING HISTORY (Past Twelve Months from 1/25/96)
Unit 1 operated continuously during the past 12 months with the following exceptions:
On February 21, 1995, the unit was removed from service for the replacement of pressurizer code safety valves which had been leaking by the seat since shortly after startup in November, 1994.
On March 4, 1995, the unit experienced a 14 minute loss of 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 denied the error; however, the licensee determined that he was responsible. He resigned from the company. The unit was returned to service on March 8, 1994.'
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 remained shut down for 73 days.
Problems encountered during the shutdown included a maintenance-induced RCP seal failure, discovery of two inoperable PORVs due to maintenance errors during refurbishment, a loss of inventory event while placing shutdown cooling in service due to lack of_ margin to relief valve lift setpoint and complicated by an excessive blowdown value, inadvertant spraydown of the. Unit I containment, catastrophic failure of the 18 EDG, and leaking pressurizure code safety valve flange leakage. The unit returned to power on
! October 12.
S On November 16, the unit was manually tripped when a feedwater
- regulating valve failed to the 50% position, resulting in low steam generator water level. The root cause of the failure was determined to be a faulty power supply. The power supply was i
replaced and the unit was returned to service on November 18.
'On January 22, 1996, operator error resulted in an excessive dilution event which resulted in reactor power accending to 100.2%. The operator in question apparently left the control room while dilution was in progress without informing other watchstanders of the evolution in progress. The operator was
- removed from licensed duties and the final disposition of the event is pending. -
l 1.8.2 UNIT 2 OPERATING HISTORY (Past Twelve Months from 1/25/96)
, Unit 2 operated continuously during the past 12 months with the-following exceptions:-
?
I
e 10 On' February 21, 1995, the unit tripped as a result of low' steam generator water level. The condition was the result of a
.feedwater regulating valve closure after. a steam generator water
' level control. level transmitter failed high.~ The transmitter.was
. replaced and the unit was returned to service on February 25, 1995.
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 /> to replace a main turbine DEH power supply.
On August 1, 1995, the unit was shutdown as a result of Hurricane :
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.
On October 9, the unit entered a refueling outage. The outage was complicated by the discovery of leaks in RCS flow transmitter taps at the loops, a reactor flange 0-ring leak, discovered'during l repressurization, and the failure of one stage of an RCP seal :
package. The unit returned to power on January 1., 1996. 1 The unit was manually tripped from approximately 35% power on j January 5 due to high generator hydrogen temperature. The root j cause of the event was improper operation of a turbine cooling water temperature control valve which supplied cooling water to j the hydrogen coolers. Post-trip review resulted in the discovery :
of clogged. steam generator water level transmitter sensing lines which resulted in artificially low levels being indicated when steam generators were isolated upon turbine trip. The lines were blown down and the unit was returned to service on January 7.
l '. 9 OUTAGE SCHEDULE AND STATUS.
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 '
safeguards test; steam generator tube inspection and plugging; steam :
generator sludge lancing; repair of refueling water storage tank; several instances of reduced inventory / mid-loop operations; replacement of ICW/CCW LOOP logic [HFA latching relays) with pull-to-lock switches; >
1 removal [ collection) of Rx vessel neutron flux dosimetry; modification of.EDG skids.to allow access underneath;finspection of ECCS sump area; i replacement of a main transformer; modification of containment spray ,
- NaOH addition piping; and mechanical, electrical, and I&C systems maintenance. The next Unit I refueling outage is scheduled for April
- 29, 1996.
Unit 2's last refueling outage began,on October 9,1995, and ended January 1, 1996. Major outage activities included: refueling; steam generator tube inspection and pluggin'; g low pressure turbine blade replacement;' emergency diesel generator inspection; ' replacement of three 6
, n ,,_
1 l
l 11 reactor coolant pump mechanical seals; and mechanical, electrical, and I&C systems maintenance. The next Unit 2 refueling outage is scheduled ,
for April 15,'1997. l P A R.T 2 - PLANT PERSPECTIVE 2.1 GENERAL PLANT PERSPECTIVE A SALP board meeting was conducted on January 18, 1996, covering the ' -
SALP period of January 2, 1994, through January 6, 1996. .The facility was rated category 1 in the areas of Plant Support and Engineering and 2
'in the areas of Operations and'Hainenance and Surveillance. The latter '
scores were a decline from-the previous SALP cycle, when the facility
. .was rated category 1 in all areas.
2.2 SALP HISTORY (Past 2 SALP Periods)
The last SALP period, SALP Cycle 11, ended on January 6, 1996. The current SALP period ends (tentatively) in June, 1997.
~
ASSMT. OPS RAD MNT/SURV EP SEC ENG/ TECH SAQV PERIOD 5/1/89 - 1 1 2 1 1 1 1 10/31/90 1
11/1/90 - 1 1 1 1 1 1 5/2/92 PLANT OPS MAINTENANCE ENGINEERING PLANT SUPPORT
'5/3/93 - 1 1 1 1 1/1/94 ,
l 1/2/94 - 2 2 1 1 1/6/96 2.3 SELECTED SALP AREA DISCUSSION l Since July 1995, there has been a series of events that led to questioning the plants overall performance. -These have included:
= A Unit I turbine trip due to procedural weakness, '
operator performance and supervisory oversight.
- The attempt to restage an RCP seal using inadequate and inappropriate procedural guidance. The evolution was compounded by failing to follow aspects of the guidence that did exist, which
. led to the failure of the second and third stage seals. !
1 O
r
1
,, l
- .t 12 1 c, . A main steam isolation. signal due to an operator failing to block
- . the MSIS signal during'a cooldown when an annunciator indicated ,
that the block was enabled. This failure occurred dispite the. ;
fact that that the operator's~ attention was directed to the j j
t annunciator.on at least two.different occassions..
Both pressurizer power operated relief valves being found inoperable due to incorrect assembly during a refueling outage. 'j The conditions had existed for approximately 10 months.
j I
b . .An-loss of.RCS inventory due to a shutdown cooling relief valve L
.which lifted and then failed to reseat due to incorrect setpoint .
c
- margins. (a generic problem involving several valves). The
- licensee had sufficient evidence that this generic condition
. existed, but had failed to act promptly to evaluate the
[j '
conditions.
- The spraydown of containment due'to an inadequate procedure and j operator error coupled with an existing operator-work-around. l j
These and several other recent. deficiencies involving weak procedures, a l- general lack of . procedural compliance' equipment failures, and personnel
, l
- errors clearly indicated that the plant's past high level of performance had declined. J l
l These and other problems led to several plant management changes, an j overall evaluation of the recent 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 comitted to use 7
the results of the independent assessment team to develop an action plan 4
for improvement.
Plant Operations Sumary of Previous Assessment i
The previous.SALP assessment concluded that Operations remained strong, that management actions were aggressive in dealing with i
identified weaknesses, and that attention to detail was a 4 continuing challenge for the licensee. ;
Sumary of the Most Recent SALP l
The board concluded that licensee performance had declined in the most rec'ent SALP period. .The board found that day-to-day F
activities were conducted with a degree of complacency. 4 Corrective actions, management involvement and comunication of .l expectations, attention.to detail, procedural adequacy and b adherence, and operator workarounds were similarly considered to be challenges to li,censee performance. l
'l 4
=. . . . . . .
i 13 ,
Maintenance / Surveillance Summary of Previous Assessment Maintenance was assessed as category 1 in the previous SALP.' 1 Assessments made early in the most recent cycle indicated that the performance leyel of maintenance activities had not abated.
Sunnary of the Most Recent SALP The board concluded that performance in this functional area had declined. Areas of concern included the existance of long-standing equipment problems and a sense that management expectations were either low or not adequately enforced. Of particular concern was the fact that equipment failure factored ,
into 6 unit trips during the SALP cycle. Additionally, worker i adherence to procedures, and the quality and adequacy of
. procedures was'found to be a challenge to performance.
Enaineerina. ,
Summary 5f Previous Assessment The previous assessments for this SALP' cycle concluded that engineering was generally strong. Good support of the plant was cited, as was the quality of engineering products, both to the site and in submittals to the NRC. .
~ Summary of the Most Recent SALP The board" concluded that Engineering continued to perform at a superior level. Continued support to the plant, as well as adequacy in safety and operational evaluations were identified. In addition, the licensee's activities at the engineering materials laboratory and in the developement of maintenance specifications were seen as strengths.
PART 3 SIGNIF.ICANT EVENTS
! '3.1 SIGNIFICANT EVENTS BRIEFINGS (Past 12 Months)'
I
. Unit 1: 95-08, 3/22/95, Failures of Rosemount Transmitters due to Gas Permention of Monel Diaphragms
> Unit 2:. None 3.2 ENFORCEMENT STATUS / HISTORY (Past 12 Months)
~
inoperable Unit 1 PORVs i
1-
q i
14
. Predecisional Enforcement Conference held, SL IV violation issued for failure to take prompt corrective action for issues relating to relief valve lift-and blowdown setpoint values which resulted' in a loss of Unit 1 RCS inventory'while on shutdown cooling.
,PART' 4 -
STAFFIN6 AND TRAINING 4.1 OPERATIONS STAFF - OVERALL.(9/95) ,
Average performance of the operations staff has been noted. Control room demeanor of personnel is above average. ;
Number of Shifts: (RCO, SRO) Five shift rotation, 8-hour '
. shifts; .(NPO, ANPO, SNPO) Five shift
< rotation, 8-hour shifts.
Number of SR0s:- 38. active /13 inactive / 51 total Numberlof R0s: 23 active /l inactive / 24 total .
Total Licensed Operators: 61 active /14 inactive / 75 total 4.2 WORK FORCE (2/96)
Plant personnel (including 787 disciplines below)
Breakdown by Ma.ior Oraanization' FPL Contractors Operations 128 0 Chemistry 20 0 Health Physics 73 0 Maintenance 311 60 Outage Management 21 0
. Nuclear Material, Management 36 0 Site Engineering 50 0 Juno Engineering Security 9 120 QA/QC 37 0
- Includes Reactor Engineers, System Engineers, and Test Engineers 4.3 OPERATOR OUALIFICATION/REOUALIFICATION PROGRAM (Past Two Years) 4.3.1 REQUALIFICATION PROGRAM Last Inspection - 9/26/94, Inspection Report 50-335,389/94-19 Next Inspection - 10/96~
.4.3.2 INITIAL EXAMS 4
1 9 t
15 Last Exams 10/17/94 - 2 R0 2 passed for 100%
9 SRO 9 passed for 100%
Next Exam 3/25/96 - 6 R0
- 4.4 PLANT SIMULATOR The simulator is on site and fully certified to meet ANSI /ANS 3.5, 1985.
4.5 INPO ACCREDITATION i
All training programs are. maintaining INPO accreditation. The site l- specific simulator has been used for training since 1988 and has been fully certified for approximately 5 years. NRC inspections in the form of operatcr examinations at the simulator have found no serious ,
problems.
PART 5 - INSPECTION ACTIYITIES 5.1 INSPECTION FOLLOWUP OPEN ITEMS
SUMMARY
(UNITS 1 AND 2 COMBINED)
(10/6/94)
Pre Division Change from Division _1li 19JUi Total last Report DRP 4 34 18
_QR!i IQ 4 _ 11 .
Total 14 37 51 Note: -Each item that applies to both units is counted as one item.
5.2 MAJOR INSPECTIONS IR-No. QAlg Iygg 89-02 1/89 RG-1.97 89-03 3/89 NDE i 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 92-14 7/92 Emergency Preparedness Program 92-17 7/92 EDSFI Followup 93-01 1/93 Check Valves 94-11 5/94 MOV Followup
. 95-05 6/95 Engineering
16 95-16 9/95 POR'V Special Inspection.
4 96-01 1/96 Dilution Event Spectial Inspection j
5.3 PLANNED TEAM INSPECTIONS None 5.4 INFREQUENT INSPECTION PROCEDURE STATUS No core inspection procedures are overdue at this time.
5.5 SIMS STATUS - OPEN TMI ITEMS l There are no open TPI items.
I 1
l l
l l
1
. l l
t 4
4
ST. LUCIE UNIT 1 - SALP CYCLE 11 1 2 3 4 5 6 7 8 9 m 100. = - - =- =
^ 80 --
aR oc w ,,
3 ~60 o
c I-Z 40 --
W
. O ac~
ua E 20 --
NO~E: 3ee atteclec age orennt comments
. s T T T T T T T T T T T T IO LO IO 10 IO 10 LO 10 LO 10 LO LO @ @
c) O) On C) 01 01 0) 01 01 0) 0) 0) On C) 0) 03 0) 03 0) 03 0) O) 01'03 03 03.
P N O T LO @ b @ O) O T- N r N M 4 to ~@ N @ 03 O v- N v- N v- v v- i v v-PERIOD OF OPERATION (MONTHLY)
,- JANUARY 2,1994 THROUGH JANUARY 6,1996 -
- - - _ - - - - - . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ ___ _ .._ _____ _ _ _ _ _ _ _ _ .__ . .. .J
. . _ . _ . - . . _ _ . _ . = . _ . _ _ _ - _ - . _ . . _ . _ . . _ _ . _ _ . ~ .. -.- m. ._. _ .m_ . .
i DESCRIPTION OF EVENTS - ST. LUCIE UNIT 1 i
- 1. On January 9, the unit was manually tripped in response to a loss of the.1B MFWP. I
- 2. The unit tripped from loss of load when'the generator excitor circuit breaker was i
. inadvertently opened locally on March 28, 1994.
- 3. . .On' June 6, 1994, the unit experienced a main generator lockout, followed by turbine and-reactor - trips, when a thunderstorm blew a section of . flashing - across two output
' terminals of main transformer 1A.
- 4. Power was reduced to 80% power on August 10, 1994, due to Digital Electro-Hydraulic System (DEH) leak. The unit was returned to full power on August 23, 1994..
- 5. The turbine was taken of line on August 28,.1994, to repair a leak in the DEH. Repairs were completed and the unit returned to power on the afternoon of August 28, 1994. The j unit was returned to full power on September 2, 1994. '
- 6. The unit' tripped as the. result of a lighting strike in the switchyard on October 26, 1994. Since the unit was scheduled to start a refueling outage on October 31, 1994, a i decision was made to start the refueling outage
- 7. On ' February 27, 1995, the unit was removed from service for the replacement of pressurizer code safety valves which had been leaking by the seat since shortly.after startup in November, 1994. The unit was returned to power on-March 8, 1995.
- 8. On July 8, 1995, the unit tripped during turbine valve surveillance testing. The unit -
was returned to power on July 12, 1995. I l
- 9. 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 remained shutdown until October 9, 1995. '
- 10. On November 17', 1995, the unit was manually tripped due-to low steam generator level when the feed regulating valve failed.to mid position.- ,
t
.-. - . .- - - . . - . . -- .~. - - . - _ _ _ _ . _ - - _ _ _ - _ - _ _ _ _ _ _ - _ _
ST. LUCIE UNIT 2 - SALP CYCLE 11
^
1 3 4 5 6 7
=
L 100' l
^
- 80 -"
cr u.1
. 3: 60 -
l O . .
n.
H Z 40 - 8" uJ 2 O o
. Er NOTE:~ See attached page fo r event comments uJ a 20 -
eeeeemmmmmmmmmmmmee O"""e"""""w"""""e""""e""""w"""""e".'"!""""""""'"""'""""""""""""""""""""'""""""""""""""""""""
e mammmmmmmmmmmmmmmmmmmmmmme v- a co e m m N m m T".oT" T" v- a e a co e m m N m mT""o1""e T a= e a PERIOD OF OPERATION (MONTHLY)
JAN'UARY 2,1994 THROUGH JANUARY 6,1996
DESCRIPTION OF EVENTS - ST LUCIE UNIT 2
- 1. -On February 27, 1994, the unit was coasting down to the cycle 8 refueling outage. The unit was taken off-line on February 14, 1994.
- 2. On April 23, 1994, the unit tripped from 30% power during RPS adjustment.
- 3. ' The unit 2 turbine was shutdown on July 9, 1994, and reactor power reduced to Mode 2 on July 10, 1994. On July 14, 1994, the unit was shutdown to repair a stuck closed trip circuit breaker. The unit was restarted and placed on line on July 15, 1994. +
- 4. On February 21, 1995, the unit tripped as a result of low steam generator water level.
The condition was the result of a feedwater regulating valve closure after a: steam generator water level control level transmitter failed high. The transmitter was
, replaced and the unit was returned to service on February 25, 1995.
- 5. On April 25, 1995, the main generator was taken of line to repair a faulty power supply in the DEH system.
- 6. On August 1, 1995, the unit was shutdown as a result of Hurricane Erin. It was restarted on August 4, 1995.
. 7. On' October 9, 1995, the unit was shut down for a scheduled refueling outage.
- 8. On January 1, 1996, the unit went critical. ,
- 9. . On January 5, 1996, a manual trip was initiated on high generator . hydrogen temperature.
Q 9
e O
__a__-----2.
4 BIOGRAPHICAL DATA NRC RE8f0ENT STAFF MARX 8. MILLER UANRC 8enior Residentinspector St.Lucie Nuclear Plant Date Asmgned: Assigned r.s Resident inspector SlS3 )
i Amaned SRIPosition IlO6 Previene NRC Employment '
-i Reacter Systems Engineer,NRHlDSSA 1993 l Headquartere Operetions Officer, AEOD 1991 1993 Resident inspector, Yankee Rows 1991 Reester Engineer, Region i 1990 1991 Previene Employment MmeiseisoiStote Univermtv !
Graduate ResearchfTeaching Assistent 19331990 .
~
Texas UtTitms Electnc pgmenche Peak Steam Electne Stotion
' System EngineerlRegulatory Compliance Engineer 1987 1988 Newoort News Shisbuddina and Dry Dock Co.
shift Test Engineer (S8G1 1983 1987
- Edsesties MenesineiStste Universty -
. MA Nucieer Engineenng,1990 MmeiseisoiState Universty MA Naciser Engineering,1983 ;
S
- t g
I' -: G -, ,
4 BIOGRAPHICAL DATA NRC RESIDENT STAFF i
STEPHEN S. SANDIN U.S.NRC Readent inspector .
St.Lucie Nuclear Plant Date Assigned: Retotionei Assignment January 18 thru July 31,1995 (Treining)
October 6,1995 thru April 6,1996 (Detail)
Previene NRC Employment Headquarters Operations Officer AEOD 87 96 Previene Employment 4-i Pearl Harbor Navel Shiaverd 82 87 1
" A8TElSTElACTEICTE IS314W, SSW & S6Gl 89 90 l t genwn & Root. South Texas Proinct 00 82 Engineer lill . Nuclear Analysis Group Biolonical Production 66 78 Fractionster, Fitration Specialist &
I Sterile Operations Supervisor l
Edecaties: l University of Califamis at Sants Barbars !
8.8. Nuclear Engineering,1980 f Venture Cologs A.A.,1975 1
8
+
9 9
e
4 . 41 a # u _ A b A .a ; - - .- a.a a.-.
k J
a6 1
s -
V e g =
=t - .
- j .
r S
l je
=
2 35 3-I "T" .
t
_. y 3 iv
}e'
,'l g-r g 8 38
- W :. 3 5 5 E .I 3~
-: Es ? 3.*Ee; su gg l 3 35 gg g _
.= se 1- 85 gg a- rg g .. m
=.-
g g [, -
au j g
=
8 s g, 1%
g
_ , _ g g 5. j e :I Y R . 83 )
s t e-v 4 1 i=
1W c=
- I5 h . $
Ed I
iI 3-
! Ih 1-t i ;
I e. -
I !s jeT re s
I -
la t
- I
_ iI ,
1,:
T s
. E 1:3 W 'a -
5 g
. l I
L___._.__._. i
l l
i E
i a !
Et at ! !E -~
w 1:
f
~
EE U 4
li 1
$ si - ,
! "a- 1 4 ' !
g l G i b
iL -
I l_ s
)
BE 8 '
Et $$ $5 .T1 O
G I!
- g. sg
!! !$ J-3 iE
' J F3 8. g !
' 1 i 3 @
d e i
~ f b.g E R .
j i
h ! Y
!s I.
ie 3 y
, "I gg -
a
~
si .
3 "s !E Ei -
In g! 1 5
z~
ag 5 I J
$ ! a, E
~
- .: ! "a i ? E= E ig 9 8 !! *i !
ag ! ! i: In p ja a.
!l 1 58 1
i af
- 3 3 l
s ls 'I
- v I jeI e
e ..
5 f g
f.
5 ! = I =
EE s
$5 l -@ lE Y lf 5 =
I' ? e- gi !! ! !! 'I i!
-- s!e
! E4 3[
wE -
I5 g Li.
II g
Ej we s- .
= n n .t- i i l 3 6
4
i
~ ST. LUCIE 1 SSF 10/23/94 LER# 33594006 50.728: 27940
! COWITION EXISTED IN ALL MODES UP TO 100% POWER SINCE 1978 1 PWR HIST:
GROUP : CONTAINMENT AND CONTAINMENT ISOLATION GROUP i SYSTEM REACTOR CONTAINMENT BUILDING j
i DESC A DESIGN ERROR COULD HAVE ALLOWED CROSS IN EXCESS OF DESIGN LIMITS.
l PWR NIST: POWER OPERAfl0NS AT 100%
SCRAM 10/26/94 LER8 33594007 50.72# 27956
- A REACTOR TRIP FOLLOWED A MAIN TUR8!NE TRIP. TNil QCCURRED WH) 4 1
DESC TRANSPORMER CAUSED A MAIN GENERATOR LOCKOUT. )
t PWR NISTs COLD SNUTDOWN SSA 11/22/94 LERs 33596009 50.728: 20060 ELECTRICAL LilmfP CSSIM DESC : BOTN EDOS STARTG ON Am SIAS. ONE EDG LOADED ITS SUS WNEN AN "'immat WITN ADDITIONAL LORDING FROM THE SIAS CAUSED TM SUS masarse TO OPEN.
Mst NIST: COLs SuuTDOWN SSA 11/22/96 LERe 33596009 50.72# 20060 DESC : AN SIAg nesan WNEN TWD OF FOR PRESSURIZER PRESSURE TRANSMITTERS DRIFTED NIM NyBROMM. THE CNAR$1NS MSPS WRE SECURED EKME TE LTOP SETPOINT WS REACMD.
PNR NISTs COLD SNUTDOW SS& 11/24/96 LERf 33596010 50.729: 20068 DESC : AN lumWERTENT SAPETT INJECTION ACTUAfl0W SleNAL CCEMBRED' DU ,
SAFEeUARDS CYSTEM TESTING WHEN A PRESSURIZER PRESSURE BISTA PROCEDURE.
PWR HIST: POWER OPERATIONS AT 1005 SSA 02/16/95 LERf 33595001 50.728: 28600 DESC WILE RESTORING A SAFETT SUS TO A NORMAL LINEUP FOLLOWING RELAY REPLACEMENT, THE S DEENERGIZED. THE EMERGENCY DIESEL STARTED AND LOADED ONTO THE SUS.
LERs 33595003 50.728: 29039 PWR HIST: POWER OPERAT10N'S AT 1001 i
SCRAM 07/08/95
- . DESC
- THE REACTOR TRIPPED ON MIGH PRESSURIZER PRESSURE WEN THE MAIN VALVES WENT CLOSED DURING TESTING. THIS EVENT WAS CAUSED SY AN OPERATOR, OMI i STEP.
I SSF 08/09/95 LEnf 33595005 50.728: 29175 PW NIST: CONDITION EXISTED IN ALL MODES UP TO 1001 POWER SIMM 1996 ,
I i GROUP .SAFETT AND RELIEF VALVES GROUP I SYSTEM : REACTOR COOLANT SYSTEM DESC THE POWER OPERATED RELIEF VALVES WERE FOUND INOPERASLE DURING TESTI i INSTALLED INCORRECTLY DURING THE 1994 REFUELING OUTAGE.
4 ifSF 08/10/95 LEnf 33595006 50.728:
. PWR MIST: EVENT OCCURRED IN COLD SNUTDOWN l OROUP : RESIDUAL MEAT REMOVAL SYSTEMS GAGJP SYSTEM : RESIDUAL NEAT REMOVAL SYSTEM DESC : SOTN TRAINS OF RESIDUAL NEAT REMOVAL WRE REWERED INOPERABLE AS A RESU RELIEF VALVE. THE ROOT CAUSE WAS INADEeUATE DESISM MARGIN BETWEEN THE
~l A S NORMAL SYSTEM OPERATING PRESSURE.
ST. LUCIE 2 LERf 38PP5002 50.7293 28416 Mst NIST: PO W R OPERATIONS AT 1001
' SCRAM 02/21/95 DESC : A REACTOR TRIP RESULTED FRtst A LOW STEAM GENERATOR LEVEL AFTER A STEAM FAILED HIGN, CAUSING THE FEED RERJLATING VALVE TO CLOSE.
l I
J t
R I
- 4 1
l I
- - _- . - - ..- - .=.
DRAFT /REllONAL REVIEW j Legend:
Shutdown < approx. 72 hrs ,i Startup i g {gj Refueling R Operation m 4
Industry Avg. Trend Shutdown mw Not Shown Using Op. Cycle 1555551
> Ops. ;
i i i i Ops. i i i i 1 J
a I I I ,; I g l l l 1 ,; I E ' 95-1' 3 E 931' 9 961' 963 951' 93 1 9 1' 94-3 Year- Quarter Year- Quarter Automatic Screme While Critical Safety System Actuations 4 4 3- -
3- .
R i I
2- 2-3
== = = 0 0 93-3 961' 963 951' 953 2 '
93-1' 93-3 941' 943 951' 953 ' 93 1' Year - Quarter Year - Quarter )
Signincant Ev'ents Safety System Failures 24 4 1.5 - 3-w u, 11.0- g 2-0.5 - 1- g g !
o.0 0 E M i 93-1' 93-3 94 1' B&3 951' 953 '
93-1' 93-3 9 4-15 943 951' l>53 Year - Quarter Year - Quarter Equipment Forced Outageal Forced Outage Rate (%) 8 1000 Commercial Crttical Hours 100 y 80 -
'E 60 - h Y
~
f0~
f lll'l l t 2 l' l
} 20 - , _e . hlll g ou oo 2o m oms m i m . .i.'
e 0 6
93 1' 934 941' 963 951' 953 w ' 93 93-3 961' 963 9515 953 Year- Quarter Year - Quarter Cause Codes -
- ^ b. Llc Oper c. Olher Per Radiation Exposure * =
200
- - e. w.
f ,
W e150- l
' s- s. ..
R E U -=R e
= = , e -
100- l
' l d. Maint e. Dese9n f. Misc f ,
$0 - Y" ,
l
- ~ " ""
o 4 ,L .J. O ,1 J.NA *- n- e.
4 93-1' 93 3 941' 94 3 951i 953 Year - Quarter n ,n N= ~ b=, -
e
- Site Avere9e Radioten Exposure . .
6
DRAFTIRE210NAL REVIEW ST. LUCIE 1 tesend: staac.i siss e.nce en ===
Medium EZ:lll21 Peer Group.Combuston Engineenng w/o CPC 924 to 95-3 Trends and Deviatons Deviations From Plant Peer Group Self-Trend Median Short Term Long Term Declined improved Worse Beter OPERATIONS (including startup)
Automatic Scrams Whhe Critical - 0
-0.56 Safety System Actuations - o go -
-0.36 Significant Events - 0 0 l Safety System Failures - 0 0.22 Cause Codes (All LERs)
- s. Aemmistreove centrea rrememe - ] 0.16 -
@ 0.45
- n. ucensed operow Errere - -1.50 -
] 0.22
- c. omer Personned Errere = l ) 0.64 -
-0.07 [
- d. Maintenance Prebiome - -0.37 E -
3 0.19
- e. Desierwceneiracoennneteneceneatncamen Precieme - ] 0.25 -
l0.30 t miseeneneous - 0 -
4.18 [
SHUTDOWN Safety System Actustions - 0.95 [hfhh M.67 Significant Events - 0 0
Safety System Failures - 0.22
-0.01 Cause Codes (All LERs)
- e. Ademieweeve coness Prememe - ]0.15 -
-0.06 [
- n. ucensed Operett Errors - 0 -
O
- c. omer Pereenne Errors - ] 0.13 -
0.16 [
~
- e. meineenance Prowsme - ]0.11 -
4.22 [
e.Desienc n r - obncenen Premame - ] 0.20 -
0
- f. Mioceneneous - 0 -
0 FORCED OUTAGES Forced Outage Rate * - 0.89
-0.10 Equipment Forced Outages / *
-2.45 hkffh~~ -0.82 1000 Commercial Critical Hours . -
Note: see TeWe 9 in Part N for me 1.0 -O'.5 0.0 0J5 1.0 1.0 0.5 0'0
. 03 1.0 speanceme fremse used en me cascesamene. Performance index Performance index
- Not Calculated for operet enal Cycle 4
DnArT/REDIONAL REVIEW Year - Calendar Quarter 9M Type rhase 92-4 93-2 93-3 93-4 94-1 94-2 94-3 94-4 95-1 95-2 95-3 rNIef$$1ng 8 h 8 8 k 8 8 h Startup 0 0 0 0 0 0 0 0 0 0 0 0' Nf!S$1ng 0 b 0 8 h 8 REIN $[n Non-Refu!1ing 0
0 8
0 8
0 0
0
!0 0 0
0 0
0 0
0 0
0 0
0 0
0
?:Inin$1= 8 8 8 8 8 8 8 8 8 8 8 8
8 8 8 8 8 8 8 8 8 8
.linYf=.u.
-Refo 0 0 0 0 0 0 0 0 8 0 8 0 3:!!ilh 8 8 l 8 8 8 8 8 8 l
BiHuun. i ! h ! ! ! ! ! l' 8! !
FCR (1) 0 0 0 6 O S 8 1 7 0 0 SS EF0/1000 ERS 0.00 0.00 0.00 0.00 0.00 0.45 0.47 0.00 0.00 0.00 0.00 10.24 CRJf. MRS 2200 2089 447 2114 2209 2062 2123 2208 1400 1941 2183 683
. RAD 7 37 182 5 6 75 11 6 160 22 6 NA CAUSE CODES:
^*""- "
miniatiu 8 8 8 8 h h 8 8 h 8 8 itinirn!1ing 8 8 8 8 8 8 8 8' 8 8 Non-Refu 0 0 0 0 0 0 0 .h 0 0 2
"" P"-
M!nialiu 8 8 8 h 8 8 8 8. 8 8 8 h 0 0 0 0 8 8 0 0 0 0 Re$NY$n!1ing Nond efu 0 0 0 0 0 0 0 0 0 0 0 0 NNRef$$1ng 8 h h 8 8 8 0 0 $ 0 8 8 O O 8 8 8 0 0 ReINY[n!ung Non-Aefu 0 0 0 0 0 0 0 0 0 0 0 1 NIek$$ing 0 b h h 0 h 0 8 0 8 loinYrn!1ing 8 8 8 8- 8 8 8 8 .8 Non-Refu 0 h h 0 0 0 0 0 0 0 8 2
""" i
- 5n1:$1= 8 8 8 8 8 8 8 8 8 8 8
. iinir Non-RefNiing
'a 0
8 0 h 8
0 8
0 8
0 8
0 8
0 h 8
0 8.
0 8
1 NfS$ing 0 8 h 8 8 8 RelNY[n!1ing 0 8 8 8 0 0 0 0 8 8 8 0 -
Non-Refu 0 0 0 0 0 0 0 0 0 0 0 0 rs.se rn.e. too st.rt End t.n.ca l
p:W$"!ninu.
In;Mi'"" 8[ndmn st! 5g ' 8'l;! 2ll 8: inia"hi}ll281nd!8l'g}j!! 3 n 8 8' di 1 2.1 N!atuun !Ena="nm :ini:" "Sg d9!8) 81['llj8t . g ke:fuelingf Inicu.utdown ' !! L8 Jt 2!i k0 b94 J 94 33
' tit N"!$efueling ini:"
. utdown it d 95' OD !"! !!-
8 NINk$ ling kkNdN 08/0 9h 09 /95 6 Trend Calculations Deviation Cateulations L l Hit:8llthfl 2;g
)f Ll/l$/94-09/30/9l g:;; in g ggg;;;;;j gggg.iggg;gg;gg g;gg;;jgng g,,02/2/94-09/30/93' 40 days g;g;;;;;;
270 days F 4
- 6 8 .
DRAFTfREGIONAL REVIEW Legend:
$""t"""<'"*"'",' 5'"'"' '
ST. LUCIE 2 Refueling R Operation m
" ^ "
92-4 to 95-3 Quarterly Date Not Shown Using Op. Cycle EEEEE
"' ~" ~ "' ~ ~ ~
l i i I I I l i l I I I I I g II I I I I n I l l I g -- ! i i i l I g __ l 1 i i l I i
93 1' 93 3 941' 94 3 951' 953 8 93-1' 93 3 941' 94 3 951' 95 3 Year - Quarter Year- Quarter Automatic Screms Whue Celtical Safety System Actuations 4 4 3- 3-g 2- < 2-1- J 9 1-
" 0 0 9'"3-1' 9M 94 3 951' 953 3
931' 9M 94 1' 94 3 951' 953 3 94-1i Year - Quarter - Year - Quarter Significant Events Salsty System Failures 24 4 1.5 - 3 .
W u-
$ 14 - gg 2-
, 0.5 - 1-Z 2 04 0 ,4,1, ,,,, ,,,,
, ,3,1; ,3,3 1, ,4,, , t, g$, , 93,1, ,M ,,,1, Year- Quarter Year - Quarter Equipment Forced Outageal
' Forced Outage Rate (%) 6 1000 CommercialCritical Hours i 100
~ ' "" '
2-6 l lI 2
20 . ig' f
I
- t e
j Il!g i
f,& g g
'5 51 J55 ctm ..L. '
e555_.L. oeu o w 0- 94 3 951' 953 g,
I 93 1' 9M 94 1' 94.3 95 1' 95 3
' 93 1' 93 3 941' w Year - Quarter Year - Quarter Cause Codes
- a. Admin b. Uc Oper c 09terPer Radiation Exposure * =
- 200 - '
g ,
] ,8-75 d. Maint e. Dessen f. lanc 50 - ~
$5I
. >: :- .. w. w.
0 I* A 8 Q "'b' A NA '-
93-1' 933 941' 94 3 951' 953
Year - Quarter e, . - . "" ""
t-
- See Average Redioson Exposure ,
9 9
DRAFT / REGIONAL REVIEW ST. LUCIE 2- Leeend: si e.ec i sion=== men Peer Group:Combuseon Engineenng w/o CPC Medium m Low i i 92 4 to 95-3 Trends and Deviabons ;
Deviations From ;
Plant Peer Group
. Self-Trend Median '
Short Term Long Term Decisned improved Worse Bemer OPERATIONS Automat;c Scrams While Critical - 0.54 0.18 Safety System Actuations - 0 o.go Significant Events - 0 o
Safety System Failures - 0 0.67 C: .
Cause Codes (All LERs)
- a. Aenewsweeve coness Promeme - ] 0.08
]0.15 I
, n. usenses o,erseer strero - 0 -
0.68 l
- s. omer Pereennes errors - 0, -
0.68 l
, e. - - Prowsme - T ~ 0.23 -
0.19 er ;- - -
a - Premone - 0 -
l0.30
- f. - -
0 -
1OAS
, SHUTDOWN Safety System Actuations - NA -
-0.15 l Significant Events - NA -
0 Safety System Failures - NA 1.34 l
Cause Codes (All LERs)
- e. 4emmmeneve cenew Premame - NA -
DFJ CA7
- e. ur.enne opuseer errors - NA -
4.30 l !
l
- e. omer Pweennes arrero - NA -
] o.00
- s. - _ _ Premame - NA -
]0.11
,,4 ,- p,enes== - NA -
0.26
- f. - - NA -
0 FORCED OUTAGES Forced Outage Rate * - o
- .-. o.49
- Equipment Forced Outages /
- 0 0.13
, 1000 Commercial Critical Hours -
swn: see fewe e m Part a for um 1.0 -0.5 0.0 0.5 1.0 . 1.0 -ols 0:0 o'5
. 1.o
- "*"***"**"****- Performance Index Performance index
+ mes coeweses er opweeenu cycm ,
- - . - . . - --- - - _~. . . - . . - - - - -
DRAFT /RESICNAL REVIEW ST. LUCIE-2 Year - Calendar Quarter t
~h h M 9,3-), 93-2 93-3 93-4 ' 94-1, 94-2 94-3 94-4 95-1 95-2 95-3 8 8 8 8 8 8 8 8 8 8 8 ptartup:!!!!"tio 0 0 0 0 0 0 k 0 0 0 0 0
- 8"
- 51'i : 11 8 8 8 8 8 8 8 8 8 8 itnft 8 l0 8 i 8 8 8 8
- 8. 8 8 an-RetS!1ing 0 $ 0 0 0 0 0 0 0 0 0 0 2 511) : 11 8 8 j 8 8 8 8 8 8 8 8 8 Bi!Inun. I 1 8 ! ii ! ! ! ! !
!tincti. l -j 8 8 8 8 Lins 8 8 8
0 l' l 8 0
8 0
8 0
FtR (I) 20 47 8 2 1 0 7 2 0 4- 0 4 IF0/1000 W 0.00 6.88 0.44 0.00 0.00 0.00 0.80 0.00 0.00 0.48- 0.00 0.47-CRIT. MS 1885- 281 2084 2204 2187 1954 18S8 2183 2208 208S 2188 2142 I
RAD 7 37 182 S 8 75 11 8 180 22 8 M CAUSE CODES:
ENfS$1ns 8 8 h ! 8 h 8 0 8 h 8
. itutt ling on-RetS! k 8
0 8-0 8
0 8
0 8
0 8
0 8
0 8
0 8
0 8
0 ..
8 0
" * - *- EA*intin. 8 8 8 % i 8 8 8 8 8 8 8 1
iluff on-RefS!1 ins 8
0 8
1 8
0 8
0 8
0 ,
8 0
8 0
8 0
8 0'
8 0
8 0
8 0
l pifine 8 i ! 8 8 8 3 8 8 8 8 8
,M e tf 8 8 8 8 8 8 8 8' 8 8 8 an-kef0!11ng 0 0 0 0 0' h" o 0 0 0 0 0 Maint, O 0 2 2 g g 0 i-rgtion. g g g g g 0 0 0 0 0 'O O 0 8 0 0 tartd"!u "A u ! i 8 8 8 ~& 8 8 8 8 8 8 ai -
- !tilatio I!.Mi!Inun.
n:!ei=ri.. -8 i-l 8
i 8
s i
8 8
8 8
i 8
8 8
8 I
8 8
i 8
8 i
8 8
i 8
8 8
i 8
ittnft 8 8 8 8 8 8 8 8 8 l0 8 Non-aelE!uns 0 0 0 0 0 0 0 0 0 0 0 0 .
n... m... ev.e s .,. in, too s.
2:!A'inu. R:!an" ifjijl!R81 !l kn!$ekSling - utdN db 9 ch i !3 h6 N!$skNiins . W[dNn . h j 93 9 p:Eni=u. n 8 n 8, 4
.m e q:::n"=n.u.8gh !;n 3 84..;n=rl :
N!!Isk$ lins !NS 0 N.0!/00/8h f6 frond Calgulation. Deviation calculations fl2 'Qu04,8!:8!,f'a,f'!
811811 18ag:!!il rIA "l'il,n 'i il1..
- 8!f'8f93ALf94-09,1'8!-$40.3:.!!"*1: 11 i s: eil 93-09108327813,: do. . !!"l1:
s l
y p , - - w -w e ,
1 BIOGRAPHICAL DATA NRC RESIDENT STAFF '
MARK S. MILLER .
'U.S.NRC Senior Resident inspector St.Lucie Nuclear Plant Date Assigned: Assigned as Resident inspector 9/93 Assumed SRIPosition 1l98 Prevleue NRC Employment:
Reactor Systems Engineer,NRRIDSSA 1993 Headquerters Operations Officer, AE00 1991 1993 Resident inspector, Yankee Rowe 1991 Reactor Engineer, Region i 1990-1991 i
Previeue Employment Mismsmooi Stote University Graduate ResearchlTeaching Assistsat 1988 1990 Texas Utilities Bectric ;
Comanche Peak Steam Electric Station System Engineer / Regulatory Compliance Engineer . 1987 1988 Newoort News Shiobuildina and Dry Dock Co.
Shift Test Engineer (S8Gl 1983 1987 Education: l Misassion State Universty M.S. Nuclear Engineering,1990 MissismooiStste Universty i
M.S. Nuclear Engineering,1983 0
4.
BIOGRAPHICAL DATA 4
NRC RESIDENT STAFF n
f STEPHEN S.SANDIN U.S.NRC Reaident inspector St.Lucie Nuclear Plant Date Assigned: Rotstional Assignment January 16 thru July 31,1995 (Training) ,
October 6,1995 thru April 6,1996 (Detail)
Previene NRC Employment Headquarter OperationsOfficer AE00 87 96 . ,
l Previous Employment Pearl Harbor Nevel Shieverd 82 87 ASTE/STE/ ACTE /CTE IS3/4W, S5W & S6Gl 89 90 .
3 Brown & Root. South Texas Proiect 80 82 I
EngineerIlli Nuclear Analysis Group ,
Eglonical Production 66 78 Fractionator, Filtration Specialist & j Sterile Operations Supervisor Edesation:
University of Califamis at Santa Barbara B.S. Nuclear Engineering,1980 Ventura Colone A.A.,1975 .
6 s
0 g
h w- - - -. - - - - . . . - - ,
m1. m - - --- 2 - a ~n E
?
- I ~
y :- .
3 :s2*
j 5
- ~
1 $
e a IeS 3*
- I *
. g i
a s,
-- ! E e .
E w
li "J
.$ .s 1 -
I
?
i L
f' -
r E
~
8 i
s 29 g
- E l: ! 13 ! " 2 a~
siw ma is we 1-
== 3$
n2
[5 3" r r .i-En- :9-
=.-
b s
!n j e s
5 a
s7 i 8 I {!
- a e
! ;y -
s ,$
g
- C .-
' d 3R a sg 3 y~
.t f
f I -
I a .
W N lg f 91 af --
es ge ; je8 i al 3 e .s
" k i
! s-1I 15i II ,
-! ,79 1 wI a - '
Si i- l!
A,.
Si-g f
E
- I M
T f?
Y E -S i W 3* i 8
J l 9
I s
B I
- - s~
-t g !!
ge v
gr g, . . .
ilg* jn
! ![.
I li a-
. e
,.. J
-' I E
ib -
gj e.!
E vs
's T -
_ v -- .3 0
e i!e. !! =g
!d i
lia-
.A 23 E- t 1 3 2 la i a
da Et e
R V
1 Eg in }=!
h 8 E
sg l
.E
'E g Ig ng 1 '
sa EE -
E"s 5 E' 1: $
af 3 :~
il 5 . ! !
- E 'aa
.: ! "a 9 E-gg 1 !!
eg ,! ! Je 5l
! g!s tw se g 58 g a
! ! 5 I a '
s E M
e i IW e i=
t .
$ f s g a n i
- I
- W 8- =
-e - G k e =
- k ! I !
r_
it
=!
en :s ,[e es
! } E l-eg 1
sg Si e- EE -
.. .! J l
3 l
O e a e
l l
Biographical Information 9 FPL William H. Bohlke Vice President, St. Lucie Plant Bill Bohlke is Plant Vice President of Florida Power & Light Company's St. Lucie Nuclear Power Plant. In this function, Mr. Bohlke reports to the Nuclear Division President and oversees the operation of the two nuclear units at the St. Lucie site located on Hutchinson Island, approximately 50 miles north of West Palm Beach.
Mr. Bohlke joined FPL in 1990 as Vice President of Nuclear Engineering and Lice-nsing.
He previously served as Vice President and Manager of Projects at Stone & Webster Engineering Corporation. A career nuclear professional, Mr. Bohlke performed in a variety of engineering and project management positions for Stone & Webster.
Mr. Bohlke is a graduate of the Massachusetts Institute of Technology and received a Master of Science degree in Nuclear Engineering from the Rensselaer Polytechnic institute.
He is a registered professional engineer in eleven states and a member of the American Nuclear Society.
' He is currently chairman of the NEl Appendix B Working Group and the industry Steam Generator Replacement Group. Heis a member of the NEl Nuclear Economics and Fuel Supply Advisory Committee, the NEl Executive Task Force on Regulatory Process and the INPO Analysis & Engineering industry Review Group. Mr. Bohlke serves as FPL's representative to
- the Advanced Reactor Corporation where he is vice chairman of the Utility Management Board.
S 2/96
l Biographical Information i
l O I: P L James Scarola -
Plant General Manager, St. Lucie Plant Jim Scarola is Plant General Manager of Florida Power & Light Company's St. Lucie ;
Nuclear Power Plant. In this function Mr. Scarola reports to the Site Vice Presicent. He is i responsible for Operations, Maintenance, and technical Support activities at the St. Lucie site located on Hutchinson Island.
Mr. Scarola began working for FPL in 1980. He has held a variety of positions of increasing authority, including l&C startup engineer, l&C maintenance engineer, assistant superintendent electrical maintenance, manager special projects, maintenance manager, manager equipment, support, and inspections, engineering project manager, and operations manager at St. Lucie.
Mr. Scarola holds 'a Bachelor of Science degree in Electrical Engineering from the University of Notre Dame and a Master of Business Administration degree
- from Florida institute of Technology. Mr. Scarola has completed the senior reactor operator certification training program at St. Lucie.
l l
1 1/96
Biographical Information
@ FPL Christopher L. Burton Gervices Manager, St. Lucie Plant ,
l
, Chris Burton is Services Manager of Florida Power & Light Company's St. Lucie Nuclear Power Plant. In this function, Mr. Burton reports to the Site Vice President. He is responsible i for Plant Facilities, Budget, Fire Protection, Emergency Planning, Training, Land Utilization, Security, and information Services at the St. Lucie site.
Mr. Burton began working for FPL in 1975. He has held a variety of positions of l increasing authority, including reactor operator, nuclear plant supervisor, assistant operations i supervisor, reliability maintenance s'upervisor, operations supervisor, operations manager, and I plant general manager. Mr. Burton has held reactor operator and senior reactor operator I' licenses at St. Lucie.
Mr. Burton is a graduate of State University of New York and holds a Bachelor of Science degree in Electronics Technology. Mr. Gurton also holds a Master of Business Admin.istration degree from Florida Institute of Technology.
He is a member of the American Nuclear Society (ANS) and the Professional Reactor Operator Society.
6 1/96 .
4 Biographical Information l
@ FPL C. Ashton Pell Outage Manager, St. Lucie Plant 4
Ash Pellis Outage Manager of Florida Power & Light Company's St. Lucie Nuclear Power Plant. In this function, Mr. Pell reports to the Site Vice President. He is responsible for the pianning and scheduling of St. Lucie Plant outages and for coordination of operations and maintenance activities on a daily basis.
Mr. Pell began working for FPL in 1975. He has held a variety of positions of increasing author,ity, including Reactor Engineer, Reactor Supervisor, Technical Staff Supervisor, Assistant to Senior Vice President-Nuclear, Director Nuclear Administrative Services, Plant Services Manager and Outage Manager. Mr. Pell completed certification as a senior reactor operator for both the St. Lucie and Turkey Point nuclear units.
, Mr. Peilis a graduate of the University of Central Florida and holds a Bachelor of Science degree in Physics.
He is a mernber of the Southeast section of the American Nuclear Society'(ANS).
t i 8 1/96 '
Biographical Information
@ f:PL Edward J. Weinkam 111-Licensing Manager, St. Lucie Plant 1 l
l Ed Weinkam is Licensing Manager of Florida Power & Light Company's St. Lucie Nuclear 1
Power Plant. In this function, Mr. Weinkam reports to the Site Vice President and is I responsible for coordination of the St. Lucie Plant regulatory interface among the NRC l Resident inspectors, NRC Region 11 Staff, and NRC Headquarters staff.
Mr. Weinkam began working for FPL in 1986. He has held a variety of positions of i increasing authority, including NRR licensing engineer and corporate licensing supervisor for I the St. Lucie Plant, licensing manager for the Turkey Point Plant. He has worked in the l nuclear industry since 1979 in various engineering, educational, and regulatory areas. He was l a U. S. Navy nuclear submarine officer, an engineering instructor at the University of l Maryland, and USNRC, NRR project manager. Mr. Weinkam completed certification as a senior reactor operator at the Turkey Point nuclear units.
Mr. Weinkam is a graduate of the University of Notre Dame and holds a' Bachelor of Science degree in Mechanical Engineering. He received a Master of Science in Mechanical
. Engineering from the University of Maryland in 1979.
i 1/96 6
Biographical Information j
- 1 I
O I: P L .
l 1
Robert E. Dawson Business Manager, St. Lucie Plant Bob Dawson is Busin~ess Manager of Florida Power & Light Company's S,t. Lucie Nuclear Power Plant. In this function, Bob Dawson reports to the Site Vice President and is responsible for the strategic plan, the plant operating plan, the corrective action program, and the in-house-event tracking and trend analysis programs at the St. Lucie Nuclear Plant.
Mr. Dawson began working for FPL in 1973. He has held a variety of positions of increasing authority, including reactor engineering department head at Turkey Point Plant, staff reactor support, mechanical startup group supervisor for St. Lucie Unit 2, core barrel repair project, electrical maintenance department head, plant maintenance manager, and plant licensing manager. Mr. Dawson has held an senior reactor operator license at St. Lucie.
Mr. Dawson is a graduate of the University of Virginia and holds a Bachelor of Science degree in Nuclear Engineering.
He is a member of the American Society of Mechanical Engineers (ASME) and the American Nuclear Society (ANS).
I 1/96
Biographical Information
@ FPL Thomas G. Kreinberg Superintendent, Nuclear Material Management, St. Lucie Plant -
Thomas Kreinberg is Superintendent of Nuclear Materials Management of Florida Power
& Light Company's St. Lucie Nuclear Power Plant.. In this function, Mr. Kreinberg reports to
. the Site Vice President and is responsible for Purchasing, Stores, and interface with Procurement Engineering at the St. Lucie Plant.
Mr. Kreinberg began working for FPL in 1980. He has held a variety of positions of
, increasing authority, including purchasing & . contract services, contracts administrator, ma. nager of contracts and manager materials management.
Mr. Kreinberg attended Syracuse University and holds a Bachelor of Arts degree in Russian and a Ba' c helors of Business Administration Economics from the University of Florida.
He is a member of Contract Management Owners Group (Nuclear Power Utilities).
e 1/96
Biographical Information 9 FPL Daniel J. Denver Site Engineering Manager, St. Lucie Plant Dan Denver is the Site Engineering Manager for Florida Power & Light Company's St.
Lucie Nuclear Power Plant. In this function, Mr. Denver reports to the Vice President - Nuclear Engineering and Licensing and is responsible for engineering services' including design .
packages, as-building, procurement engineering, fuel design, and outage NDE inspections for the two nuclear units at the St. Lucie site located on Hutchinson Island.
Dan joined Florida Power & Light Company in May,1993 as Director, Nuclear Technical Support in the Juno Beach offices. In this capacity, he was responsible for nuclear fuel supply, information services and the administrative staffs for Nuclear Engineering and Licensing. He has worked in the nucioar power industry since 1967 in various engineer.ing and technology development areas. He worked for a number of electric utilities including Public Service Electric & Gas, Yankee Atomic, and Houston Lighting and Power as well as.
Westinghouse Electric and a nuclear industry services company, El International.
Dan graduated from the University of. Notre Dame in 1966 with a Bachelor of Science degree .
in Mechanical Engineering and received a Master of Science in Nuclear Engineering from Massachusetts Institute of Technology in 1967.
In outside activities, Dan has served in local town government and on the boards of several amateur theater organizations and professional societies. He is a registered professional engineer in the Commonwealth of Virginia.
e
Biographical Information i
E
@ I: P L i
j L. Wesley Bladow i Site Quality Manager, St. Lucie Plant i
Wes Bladow is the Site Quality Manager of Florida Power & Lig'it Company's St. Lucie Nuclear Power Plant. In this function, Mr. Bladow reports to the Vice President Nuclear Assurance and is responsible for independently assessing the Quality Control and Quality Assurance Program implementation by the St. Lucie Nuclear Plant.
- Mr. Bladow began working for FPL in 1967 in the Distribution Engineering Department.
He has held a variety of positions of increasing authority, including quality assurance supervisor, quality assurance superintendent, and site quality manager at the Turkey Point Nuclear Plant and quality assurance manager of the St. Lucie Unit 1 steam generator replacement project, and manager of nuclear safety speak out.
Mr. Bladow is a graduate of Florida international University and holds a Bachelor of Science degree in Industrial Technology with a minor in industrial safety.
Mr. Bladow is a member of the American Nuclear Society.
1 4
J
+
4 e
1/96
Biographical Information O I: P L Andrew DeSoiza Human Resources Manager, St. Lucie Plant Andrew DeSoiza is Plant Human Resources Manager of Florida' Power & Light Company's St. Lucie Nuclear Power Plant. In this function, Mr. DeSoiza reports to the Nuclear Division Director of Human Resources, in this position Mr. DeSoiza is accountable for proper implementation of personnel policies and procedures at the St. Lucie Nuclear Plant.
Mr. DeSoiza began working for FPL in 1972. He has held a various positions, including payroll clerk and human resouree manager.
Mr. DeSoiza'is a graduate of Miami Dade Community College and holds an-Associates
. of Arts degree in Business.
4 a
\
1/96 .
Biographical lnformation
@ I:PL t
Jeffrey A. West i Operations Manager, St. Lucie Plant Jeff West is Operations Manager of Florida Power & Light Company's St. Lucie Nuclear Power Plant. In this function Mr. West reports to the Plant General Manager. He is responsible for the direction and coordination of the operational activities including health physics, radio-chemistry, reactor engineering, operations, and operations support & testing 1 at the St. Lucie Plant located on Hutchinson Island.
Mr. West began working for FPL in 1980. He has held a variety of positions of increasing i authority, including shift technical adviser, reactor control operator, nuclear watch engineer, i assistant nuclear plant supervisor, technical training supervisor, nuclear plant supervisor, I assistant operations supervisor, assistant superintendent - mechanical maintenance, operations supervisor, and services manager. Mr'. West has held a senior operator license at !
St. Lucie. Prior to his tenure at FPL,.he held the rank of Lt. Commander in the U. S. Navy Nuclear Submarine Service. Mr. West served from 1974 to 1979.
Mr. West is a graduate of the University of Tennessee and holds a Bachelor of Science degree in Electrical Engineering. Mr. West also holds a Master of Business Administration !
- degree from Florida institute of Technology. )
i l
I
~
1/96 j i
l
Biographical Information FPL 4
Joseph Marchese Jr.
Maintenance Manager, St. Lucie Plant Joe Marchese is Plant Maintenance Manager of Florida Power & Light Company's St. Lucie Nuclear Power Plant. In this function, Mr. Marchese reports to the Plant General Manager and is responsible for supervision and coordination of the maintenance activities including electrical, mechanical, instrumentation & control, records and planning at the St. Lucie Plant located on Hutchinson Island.
Mr. Marchese began working for FPL in 1984. He has held a variety of posidons of increasing authority, including lead construction electrical supervisor -Turkey P.oint Plant , lead constniction mechanical supervisor - Turkey Point Plant, site construction manager - Turkey Point Plant, and plant maintenance manager.' Prior to his tenure at FPL, Mr. Marchese had 12 years nuclear experience in i
various positions of increasing authority with Bechtel Power Corporation. including Milestone, Davis Besse, and St. Lucie Nuclear Plants construction and startup testing. Mr. Marchese completed the senior reactor operator certification training program at Turkey Point.
Mr. Marchese is a graduate of the University of Akron and holds a Bachelor of Science degree in Electrical Engineering. Mr. Marchese is a registered Professional Engineer in Florida and Virginia.
He is a member of the American Nuclear Society (ANS).
D b
1/96
Biographical Information I: P L Lee A. Rogers System & Component Engineering Manager, St. Lucie Plant P
Leo Rogers is System & Component Engineering Manager of Florida Power and Light Company's St. Lucie Nuclear Power Plant. In this function Mr. Rogers reports to the Plant General Manager, He is responsible for the direction and coordination of the technical support to Operations and Maintenance Departments and the coordination of issues, regulatory interaction and documents at the St. Lucie Plant loca'ted on Hutchinson Island. l Mr. Rogers began ~ working for FPL in 1980. He has held a variety of positions of !
increasing authority, including mechanical startup engineer, mechanical startup supervisor, shift technical advisor, project engineer, electrical maintenance department head, and l
instrument and control department head. Prior to his tenure at FPL, he was employed by l Carolina Power & Light Co. from 1977 to 1979. i i Mr. Rogers is a graduate of the University of Florida and holds a Bachelor of Science degree in Nuclear Engineering and a Master of Business Administration degree from Florida :
Institute of Technology. 1 He is a member of the American Nuclear Society (ANS).
I I
1/96 *