ML20136D476
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REGION 11 ATLANTA, GEORGIA t
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PLANT STATUS REPORT t
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ST. LUCIE i
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i-OCTOBER,1994 h
l 9703120371 970306 M i PDR FOIA l
BINDER 96-485 PDR i
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Y PLANT STATUS REPORT FOR ST. LUCIE (10/94) i TA8LE OF CONTENTS PART 1 - FACILITY DESCRIPTION 1.1 FACILITY / LICENSEE....................................Page 2
1.2 UTILITY SENIOR MANAGEMENT
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1.3 NRC STAFF............................................Page 2
1.4 LICENSE INFORMATION..................................Page 3 1.5 PLANT CHARACTERISTICS................................Page 3 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 12 PART 2 - PLANT PERSPECTIVE 2.1 GENERAL PLANT PERSPECTIVE............................Page 13 2.2 SALP HISTORY (Past Two SALP Periods).................Page 13 4
2.3 SELECTED SALP AREA DISCUSSIONS......................Page 13 PART 3 - SIGNIFICANT EVENTS 3.1 SIGNIFICANT EVENTS BRIEFINGS (Past 12 Months)........Page 20 3.2 ENFORCEMENT STATUS / HISTORY (Past 12 Months)..........Page 20 i
PART 4 - STAFFING AND TRAINING 4.1 OPERATIONS STAFF - 0VERALL...........................Page 20 4.2 WORK FORCE
..........................................Page 20 4.3 OPERATOR QUALIFICATION /REQUALIFICATION PROGRAM.......Page 21 4.4 PLANT SIMULATOR......................................Page 21 4.5 INP0 ACCREDITATION...................................Page 21 PART 5 - INSPECTION ACTIVITIES 1
5.1 OUTSTANDING ITEMS LIST
SUMMARY
.......................Page 22 5.2 MAJOR INSPECTIONS....................................Page 22 5.3 PLANNED TEAM INSPECTIONS.............................Page 22 5.4 INFREQUENT INSPECTION PROCEDURE STATUS...............Page 22 5.5 SIMS STATUS (OPEN THI ITEMS).........................Page 22 ATTACHNENTS 1.
PERFORMANCE INDICATORS 2.
ALLEGATION STATUS 3.
NRR OPERATING REACTOR ASSESSMENT 4.
ORGANIZATION CHARTS 5.
POWER HISTORY CURVES 6.
MASTER INSPECTION PLAN
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2 PART 1-FACILITY DESCRIPTION 1.1 FACILITY / LICENSEE 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 UTILITY SENIOR MANAGEMENT CORPORATE:
J. L. Broadhead (Jim), Chairman of the Board and CEO 1
J. H. Goldberg (Jerry), President, Nuclear Division SITE:
D. A. Sager (Dave) - St. Lucie Plant Vice President i
C. L. Burton (Chris) - Plant General 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 j
P. L. Fincher (Pat) - Training Manager R. J. Frechette (Bob) - Chemistry Supervisor J.
Marchese (Joe) - Maintenance Mariayr W. L. Parks (Bill) - Reactor Engineering Supervisor C. A. Pell (Ash) - Outage Manager J.
Scarola (Jim) - Operations Manager J. A. West (Jeff) - Services Manager D. H. West (Dan) - Technical Manager i
C. H. Wood (Chuck) - Operations Supervisor 1.3 NRC STAFF l
REGION II, Atlanta, GA:
S. D. Ebneter (Stew), Regional Administrator, (404) 331-5500 L. A. Reyes (Luis), Deputy Regional Administrator (404) 331-5610 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 A. R. Long (Becky), Project Engineer, (404) 331-4664 SITE:
R. L. Prevatte (Dick), Senior Resident Inspector, (407) 464-7822 M. S. Miller (Mark), Resident Inspector, (407) 464-7822
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-NRR:
S. A. Varga (Steven), Director, Division of Reactor Projects-I/II, (301) 504-1403
.j J. A. Zwolinsky (John), Deputy Director, Division of Reactor Projects-l/II, (301) 504-1335 V. M. McCree (Victor), Acting Director, Project Directorate II-2, l
(301) 504-1485 [90 DAY DETAIL]
J. A. Norris (Jan), Senior Project Manager, Project l
Directorate II-2, (301) 504-1483 AE0D:
S. Israel (Sandy), Reactor Operations Analysis Branch, (301) 415-7573
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l.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 Description Units 1 and 2 Reactor Type Combustion Engineering PWR, 2-loop Containment Type Freestanding Steel w/ Shield Building Power Level 830 MWe (2700 MWt)
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 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
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 dosimetry installed for the current cycle (with planned removal in October,1994] will be used to reduce calculation uncertainty.
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 Boundary On this CE plant, ECCS-to-RCS injection points are isolated by at least two check valves and one closed M0V. 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 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 reactor shutdowns (8 trips) 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-channel system that operates on a two-out-of-four logic.
ATWS Prctection ATWS protection, outside the normal reactor protection system, is initiated via the ESF pressurizer pressure signal.
It actuates by 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.
Remote Shutdown Facilities These facilities are located in the switchgear rooms beneath each unit's control room.
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5 1.6.3 CORE COOLING Feedwater System The main feedwater pumps are motor. driven with each delivering 50 percent of the flow required for full power.
Turbine Bypass / Steam Dumo Capacity Each unit has five steam bypass valves, providing 45 percent of total capacity.
Unit I has one atmospheric dump valve per train (two trains) and Unit 2 has two valves per train. Each unit has tne capability of dumping nine percent steam flow to the atmosphere.
Auxiliary Feedwater System 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.
Emeroency Core Coolina System 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.
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 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.
Shutdown cooling flow path overpressure protection is provided by j
automatic isolation valves and various relief valves in the system.
l.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 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.
6 Hydrocen 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 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 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 i
minutes.
l DC Power 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 cross-connected to the safety-related swing bus if needed.
Instrumentation Power Each unit has four inverters, two powered from each vital DC 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 1 is subject to the station blackout (SBO) rule of 10 CFR 50.63 requiring additional licensee action (unit-to-unit cross-connect of 4160V bus).
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-1.6.6 SAFETY-RELATED COOLING WATER SYSTEMS 4
-Intake Cooline Water (Service Water) 8 Intake cooling water (ICW) for each unit originates in a consen-j canal called the Intake. Canal. The canal level varies with the tides since it is filled by.a level difference between the Atlantic Ocean and the canal. -One 16-foot and two 12-foot 1
diameter pipes pass under the beach'to connect the ocean and canal..The intake pipe ends in the Atlantic are covered by intake j
structures (rebuilt in 1991) intended to' limit flow velocities, 4
particularly vertical velocity, to reduce marine life entrapment.
After use, ICW returns to the ocean through'a Discharge Canal and i
under-beachipipes.
t Each unit has two trains of ICW plus a swing pump that can be aligned to either train electrically and physically. The licensee
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has converted the deep drtft ICW pumps from externally (water) lubricated to self-lubricated to increase reliability of the lubrication water source. The 100 percent (each) capacity pumps J
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
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injected with a hypochlorite solution to reduce marine growth in the associated piping and heat exchangers. Commencing 3/92, periodic injection'of a clasicide at the intake structures, primarily to control marine growth affecting the turbine condensers, has also somewhat reduced marine growth affecting the
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ICW system.
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 i
heat exchangers. The discharge from the heat exchangers returns
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via the discharge canal to the ocean.
i Increases in debris and silt in the heat exchangers during 1993 l
indicated that the intake canal needed dredging.
As of September 1993, the utility was routinely cleaning main condenser waterboxes at reduced power and obtaining F
necessary dredging permits from the state and Corps of Engineers.
The canal was dredged in December 1993 and January 1994 with immediate results of reduced waterbox fouling.
Closed Coolina Water Systems i.
The Each unit has two. trains of Component Cooling Water (CCW).
arrangement of two pumps and a swing pump mimics the ICW system.
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8 h e swing pump can be aligned to either train.
ihe 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 coolirg (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 g
i 2007 (Unit 1).
l.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 1 also 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 1997. The SGs are under construction at the B&W Canada shops and a site organization is functioning.
1.7 EMERGENCY RESPONSE FACILITIES / PREPAREDNESS 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 held February 9, 1994. Two followup items were idrntified; one involving the definition of containment failure and one involving the need to demonstrate a protected area evacuation. An evacuation drill on September 30, 1994, satisfactorily demonstrated the accountability program. The next emergency preparedness exercise is scheduled for May,1995.
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:
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High Frequency Auto-link with other FPL sites and hRC.
'I Enhanced 900 MHZ System for site and mobile connunications, with radios also in the licensee's EOF and county emergency facility.
Cellular phones with hardened antennas.
Hardened Local Government Radio antenna ties.
1.8 PRESENT OPERATIONAL SIAlts (10/5/94)
Unit 1 is operating at 100% power and has been operating since a reactor startup on June 8 following a reactor trip on June 7.
i Unit 2 is operating at 100 % power and has been operating since a reactor startup on July 15 following a July 14 shutdown to repair a j
stuck closed trip circuit breaker.
Availability Factors:
Unit 1 Unit 2 1991 81.0 100.0 1992 96.5 75.2 1993 74.0 71.8 1994 (through 8/94) 96.8 69.3
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Cumulative (through 8/94) 77.3 82.4 1
I 1.8.1 UNIT 1 OPERATING HISTORY (Past Twelve Months)
Unit 1 operated continuously during the past 12 months with the following exceptions:
On November 1, 1993, Unit 1 experienced a dropped rod event due, apparently, to a loose power supply card. The CEA was recovered without incident.
j On January 1, 1994, SALP period 10 ended.
On January 9,1994, the unit was manually tripped when the IB Main Feedwater Pump spuriously tripped.
Post trip response was normal
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and the unit was returned to power on January 10. On the first attempt at restart, the reactor failed to achieve criticality by the time an all-rods-out condition was reached. The root cause was the use of outdated core physics curves, which were updated.
The second attempt at startup was successful.
j On March 28, 1994, Unit 1 experienced an automatic reactor trip when a maintenance foreman opened the generator exciter breaker.
The worker had been issued a clearance on the Unit 2 exciter breaker and mistakenly entered the wrong unit's exciter control cubicle.
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0n April 2,1994,.the unit was returned to power; however, the -
unit automatically tripped on April 3 from 19% power while t
deenergizing a 4160 Volt non-vital bus to allow safe removal for maintenance of a failed'startup transformer output breaker. The planned electrical lineu'p placed the A emergency bus on its EDG, which was~ running at a different frequency from the grid. The paralleled CEA MG sets, now with different frequency drivers, t
4 developed circulating currents, resulting in several' tripped circuit breakers. A partial reactor trip tripped the turbine, which. tripped the reactor. Unit I returned to power on April 4,
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1994.
1 On June 6, 1994, Unit I tripped during a severe thunderstorm.
The main transformer locked out the generator, causing a reactor l
j' trip, due to a phase differential on main generator transformer-1A.
This occurred as a result of an approximately 8' length of flashing from an adjacent building which was blown across two phases of the 1A main transformer output. The licensee conducted inspections and tests of the 1A and IB main transformers and the main generator, and performed repairs to the 1A main transformer.
The reactor was taken critical on June 8; however, the licensee elected to remain off-line until repairs were completed to the 1A a
main transformer. Unit I was placed on line on June 11.
Unit 1 reduced power and entered mode 2 on August 28 to repair a DEH leak. The unit was returned to power approximately 18 hours2.083333e-4 days <br />0.005 hours <br />2.97619e-5 weeks <br />6.849e-6 months <br />
.q later on the same date.
L 1.8.2 UNIT 2 OPERATING HISTORY (Past Twelve Months)
Unit 2 operated continuously during the past 12 months with the
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following exceptions:
j On October 31, 1993, power was reduced to 45% to extend the fuel j
cycle to February 15, 1994.
The downpower lasted until mid j
j; December.
On November 2, 1993, Unit 2 was manually tripped when operators I-noted increasing generator hydrogen temperature. The cause for i
the noted condition was tied to a temperature control valve in the Turbine Cooling Water system which starved the generator hydrogen j
coolers of water. A contributor to this event was the operation of-the system.with only one pump while leaving both turbine lube I
oil coolers'in service. The procedure in place at the time of the l
event did not recognize the potential for starving the hydrogen i
coolers of TCW in such a lineup.
On November 3, 1993, Unit 2 was returned to power and operated at approximately 45% until December 13, when power was increased to.
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100%.
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On December 25,.1993,- power was reduced to 30% in response to a 3
' condenser tube leak. Repairs were effected the same day and the unit.was returned'to 100% power.1 On February 13,1994, Unit 2 was' shut down for the 1994 refueling i
outage.
The outage lasted 65 days.
i As a function of the outage, Unit 2 entered reduced inventory
' conditions twice. The first occurrence began February 19 and
- supported reactor disassembly, reactor coolant pump seal package i'
replacement, and the installation of steam generator nozzle dams.
The second occurrence commenced March 16 and supported reactor vessel reassembly, reactor coolant pump seal package replacement,--
and steam generator nozzle dam removal. Coolant inventory was
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controlled well during these evolutions.
l On March 16, 1994, the licensee identified boron' deposits
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indicative of leakage from one of four pressurizer steam space
' instrument nozzles. Licensee investigations identified unacceptable linear. indications in three of four nozzle pressure boundary welds. The steam space nozzles were constructed of Inconel 690 and were installed in 1993 as replacements for existing Inconel 600 nozzles, which had been found to be cracked.
The new nozzles were attached with Inconel 600-equivalent weld material, as 690-equivalent material was not approved for use at the time. The licensee determined that the indications were the result of Primary Water Stress Corrosion Cracking (PWSCC).
4 The licensee's corrective actions involved repairing all four i
nozzles by creating new pressure boundary welds at the exterior wall of the pressurizer. The new welds were of the Inconel 690-4 compatible material. During the repair efforts, region-based
'i inspectors found that the overall repair effort was well
. controlled and that performance was good; however, one violation was identified involving incorrect bevel angles on two weld preps.
1 On March 18, Unit 2 experienced a six minute cessation of shutdown cooling when a misanalyzed clearance (tagout) resulted in automatic valve realignments that secured flow to one of two operating shutdown cooling trains. A second shutdown cooling loop was in operation at the time; however, operators stopped the operating pump as a precaution against damage after the unexpected valve realignments. 0perators assessed the situation and restored shutdown cooling in six minutes.
Unit 2 completed the refueling outage and was returned to power on April.19, 1994.
On April 23, 1994, Unit 2 tripped due to a RPS cabinet manufacturer's wiring error which manifested itself during RPS troubleshooting. The wiring error existed since the original manufacture of the cabinet.
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following Unit 2 trip stabilization of April 23, 1994, the steam.
i bypass control. system operated unexpectedly, resulting in a rapid i
7 degree cooldown and a resultant severe RCS shrink (pressurizer j
heaters deenergized on low pressurizer level).
Prompt operator-action was taken to secure the cooldown. Unit 2 was returned to
. power on April 26, 1994, i
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On July 9,1994, Unit 2 turbine was shut down and reactor power reduced to Mode 2 because the 2B1 RCP lower oil level indication showed a leak. The sump was not leaking and anl unusual failure in the indication system was determined to be the reason for the g'
indication. The reactor was returned to mode l' and the turbine.
l started up on July 10, 1994, d.i On July 14, 1994, Unit 2 was shut down to allow repair of a stuck-I-
closed trip circuit breaker. Operators did not follow Unit 2 Tech Spec LC0 time requirements regarding shut down on July.14 to allow repair of a stuck-closed trip circuit breaker.
The unit was
. restarted and placed on line on July 15, 1994, and has operated I
continuously since that date.
l 1.9 OUTAGE SCHEDULE AND STATUS l
~ Unit l's last refueling outage began on March 29, 1993, and ended on May 28, 1993. Major outage activities included:
refueling; steam generator tube inspection and plugging; station blackout related electrical cross-tie testing; Containment pressure sensing lines labelling and capping; Containment integrity violation corrective action (penetrations identified, caps installed); safety-related breaker protective relays -
rewired for " green slime"; HFA latching relays verified operable; post-accident containment water level monitoring system - magnetic reed E
switch system installed; Mod to stop auxiliary building exhaust fan upon SI installed; radiation monitors replaced for liquid release to CCW and batch liquid release system; safety-related motor bearing alarm setpoints reduced per vendor request; EDG fan drive modification to 1r reduce vibration; and mechanical, electrical, and I&C systems i
maintenance.
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The next Unit 1 outage is scheduled to start October 30, 1994.
It is j
currently being planned for 38 days. Major activities include:
3 refueling; reactor vessel nozzle and flange weld ISI inspection; installation of a permanent cavity seal ring (at end of outage];
L replacing reed switches for several CEAs; integrated safeguards test; steam generator tube inspection and plugging; steam generator sludge l
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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; removal
-[ collection] of Rx vessel neutron flux dosimetry; modification of EDG
- skids. to allow access underneath; inspection' of ECCS sump area; and mechanical, electrical, and I&C systems maintenance.
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13 Unit 2's _last' refueling outage began on February 13, 1994, and ended; 2
April-17,-1904. Major outage activities-included:- refueling; steam
~ generator tube' inspection and plutging; low pressure turbine blading replacement; emergency diesel generator inspection; replacement of two j
reactor coolant pump mechanical seals; and mechanical, electrical, and.
i 18C systems maintenance. The next Unit 2 refueling outage is scheduled i
for October,1995.
PLANT-P E R S P E-C T I V E PART 2
2.1
' GENERAL PLANT PERSPECTIVE A.SALP presentation was conducted on February 15, 1994, covering the SALP period of May 3, 1992, through January 1, 1994. The facility was
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rated category 1 in all functional areas for the second consecutive SALP period.
In-June 1994, St Lucie was dropped from the NRC management list of good r
i performers after experiencing five' unit reactor trips in the first half of 1994, i
2.2 SALP HISTORY (Past 2 SALP Periods)
The last SALP period, SALP Cycle 10, ended on January 1, 1994. The r
current SALP period ends on July 1, 1995.
j ASSMT.
OPS RAD MNT/SURV EP SEC ENG/ TECH SAQV PERIOD 5/1/89 -
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2 1
1 1
1 10/31/90 11/1/90 -
1 1
1 1
1 1
1 5/2/92 r3-PLANT OPS MAINTENANCE ENGINEERING PLANT SUPPORT 5/3/93 -
1 1
1 1
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2.3 SELECTED SALP AREA DISCUSSIONS Since the assessment of the SALP period ending in January, 1994, there have been no events that should significantly change the overall assessment of this facility. A new corrective action program, the St.
Lucie Action Report Star System, was implemented in. July, 1994.
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program will be used to identify, review, analyze, resolve:, track, and close out all plant discrepant conditions.
It is. intended to previde l
increased emphasis in this area.
The program is currently being run in i
parallel-with: other' existing programs until it is debugged.
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implementation 'is planned by the end of 1904. To date, 215 items have been identified and 59 of these have been closed.
Plant Operations Operator performance has historically been excellent. Transients and off-normal situations have been handled well by the operators.
Increased Reactor Trips Operators h:ve responded well to 6 reactm trips since November, 1993.
The dates and root causes are as follows:
11/2/93 Unit 2 manual trip due to high generator cold gas temperature. Operation of TCW system with one pump and two TLO heat exchangers, erratic temperature
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control valve operation were root causes of condition.
.i 1/9/94 Unit I manual trip due to MFP trip. Cause of electrical malfunction leading to MFP could not be determined.
Instrumentation deemed most probable causes for the trip were replaced. Autopsy of equipment inconclusive.
3/28/94 Unit 1 automatic reactor trip when maintenance foreman mistakenly opened generator exciter breaker on wrong
,l unit. Human error.
4/1/94 Unit 1 automatic trip due to inadequate electrical lineup which led to circulating currents between CEA MGs, resulting in TCB trips.
Inadequate procedure review.
4/23/94 Unit 2 automatic trip caused by preexisting RPS cabinet wiring error.
Fabrication flaw dating from original manufacture.
6/6/94 Unit I automatic trip due to main generator lockout when severe thunderstorm blew debris across main transformer output. Weather-related, e
While the number of reactor trips is high, given the timeframe in which they occurred, only the 11/2/93 and 4/1/94 trips appear to be related in that both involved review of unusual operating lineups.
The human error-related trip of 3/28/94 did not involve operators.
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e Two trips were related to equipment deficiencies; however, one involved a preexisting condition and one involved a 4 -
spurious, non-repeatable, failure.
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The weather-related trip involved a piece of aluminum flashing, which was ripped from a building by high winds and blown across transformer terminals; it was not the result of a housekeeping problem, e
Operators performed well in responding to all trips, particularly the 4/23/94 trip, which was followed by a SBCS failure which resulted in an opening of 4 steam bypass control valves.
Prompt operator action secured the ensuing cooldown.
e The two procedure-related trips may be indicative of a general lack of rigor in procedure review. The general topic of proceoaral adequacy is discussed below.
In conclusion, the recent increase in the number of reactor trips does not appear to be indicative of an overall declining level of performance; however, additional attention to the adequacy of operations procedures may be indicated. Operator performance following the trips has been good, and, in two cases, operators properly inserted manual trips in response to plant conditions.
These actions indicated a good ability to quickly assess plant conditions and to take manual action prior to automatic action.
Other Operational Observations A mispositioned valve was discovered on February 17, 1994. With Unit 2 in Mode 5 beginning a refueling outage, the licensee discovered that the Unit 2 auxiliary spray would not work because manual auxiliary spray isolation valve V2483 was mispositioned to locked-closed and had been in the incorrect position for about 13 months. Operators had positioned and independer.tly verified the valve to be locked open in January, 1993. This was the first mispositioned valve since the June,1991 St.III for a mispositioned component cooling water valve. Management action in response to this event was swift and decisive. Disciplinary action was taken against the operators involved and management expectations with regard to independent verification was reiterated.
The inspectors have noted a positive effect of the management actions on the general conduct of operations.
During the 1994 Unit 2 refueling outage, the licensee entered reduced inventory conditions twice.
In both cases, preparations and operator performance was excellent.
On August 29, the resident inspector found that Unit I had the swing bus 1 AB aligned to DG 1A in order to permit work on expansion joints in the intake structure.
IR 94-12 had found that this alignment had not been tested to verify the load shedding and sequencing feature.
The licensee actions in the previous violation had focused ~on amending surveillance procedures to test these features during the next refueling outage and had not included measures to prevent placing the plant in this untested
j A
M 16' a
l' salignment. 'This' item.is unresolved awaiting the completion of
~
i #f -
outage testing to determine the safety. significance.
),
Management routinely makes conservative decisions regarding plant I
operations to the extent that they recognize the conservative path. An example was'the decision to repair the Unit 1: shutdown
[
cooling suction isolation valve body-to-bonnet leak even though.
J the leak rate was a fraction of that allowed by TS.. Another example was the decision to remain off-line while repairs were 7~
completed on the 1A main transformer. The slowness to shut down j
Unit 2 when TCBS failed to trip was a noted. exception from the i
' historical performance.
in
- d.
The program for conduct of infrequently performed tests or j
evolutions at St. Lucie Plant has dramatically improved the 4
T
' performance of these activities by requiring special planning and management involvement prior to the' test or evolution.
- t Procedural Adeauacy.
Recent inspections have noted a number of procedural deficiencies, requiring Temporary Changes (TCs) to be made before activities 3
could proceed. While the majority of the TCs involved ' items of i
marginal safety significance, in several of these procedures, the existence.of the deficiencies in question were clearly the result
,h of inadequate. review. One recent review error,. involving a
- l transpositional error of fuel assembly coordinates in the refueling' Recommended Move List, contributed to an attempt to
, 't grapple two fuel assemblies simultaneously. As stated above,
- )!
procedural inadequacy.has been a contributor in two~recent plant trips.
j It has been noted that operators have correctly obtained TCs as required, as opposed to attempting work-arounds. This may be due, in part, to recent management efforts to reinforce expectations for procedure compliance and independent verification.
- However, 1
the nature of the errors being identified suggests that attention i
j be paid to the licensee's procedure review process.
!I Manaaement Activities lj' Management has recently taken actions to refocus personnel
' j.
attention on day-to-day-activities. Trips to other sites by plant staff have been curtailed, as have visits by delegations from other organizations. All such activity is now subject to approval by.the site vice-president. Additionally, the morning meeting' format has been changed to include a more detailed discussion of plant operation and maintenance activities.
- g In response to recent concerns over the adequacy of the licensee's corrective action programs, site management has initiated a feasibil.ity study on the topic of consolidating corrective actions programs. The stated goal is to reduce the number of individual programs in deference to a limited number of comprehensive i
I 17 programs, thus reducing the probability of inadequately documenting or evaluating plant conditions.
The adequacy of corrective actions has been implicated in several recent issues, including:
The adequacy of surveillance testing of the units' swing ICW e
and CCW pumps, in light of previous NRC findings on the subject.
e Damage to Unit 2 PORV tailpipe supports incurred during a water hammer event in 1993.
The damage was identified by NRC during an inspection during the 1994 Unit 2 outage. The licensee's inspections following the original event failed to address these tailpipes.
i The licensee's approach to the issue appears to be sound and potentially far-reaching.
Conclusions Although an increased number of challenges to plant operation have occurred in the recent past, operator performance and the general conduct of operations has remained strong. Management has been aggressive in addressing identifiable problems and their actions appear to be effective.
Increased attention to the adequacy of normal operating and operational surveillance procedures appears to be warranted.
Maintenance General Maintenance / surveillance went from a SALP category 1 to a category 2 three SALP periods ago; this broad category had been brought down by some inattention to detail in the mechanical area.
This area then improved significantly and during the last two assessment periods was again rated SALP category 1.
Performance q
during this SALP period has not degraded.
Housekeeping is above average.
Implementation of a Plant Manager's List and a material condition group reporting to the plant general manager has been effective in maintaining general plant condition and appearance. A team inspects the plant each week and generates a corrective action list that is reviewed each week.
This program has resulted in significant rewards and has generally reversed degrading conditions.
Overall plant physical condition has been rated as good to excellent by several team inspections (e.g., HTI, OSTI, EDSFI, and Service Water), and recently by NRC managers. The housekeeping and geraral plant condition have been addressed with positive statements in recent SALP reports.
r i
g
{
I
- 18 1
Since the units are located adjacent to the Atlantic Ocean, in'a salt-laden atmosphere, the licensee has had to aggressively pursue exterior. equipment maintenance.
Painting and in.some cases metalizing of exterior equipment and of. equipment that.is exposed 1
to chlorides is a continuous aspect of the preventive maintenance scheme.
t Unit 2 Outaae Activities-1 Unit 2 outage activities ~were generally handled well. Maintenance activities were well-coordinated and were supported'by engineers i
working out of the maintenance shops. -Maintenance engineering l
involvement'was instrumental-in identifying and correcting a control wiring deficiency involving the Unit 2 swing ICW and CCW pumps which prohibited the pumps' from load shedding properly.
The y
problem had existed from unit construction.
q Maintenance activities surrounding the repair of pressurizer level instrument steam space nozzles were found to be well controlled and performed. However, the NRC found two instances in which weld l
preps, accepted by the vendor's QC inspectors, possessed bevel angles outside of the specified tolerances. Additional review-found.that the bevel angles were satisfactory for work but that plant engineering had specified an unnecessarily restrictive tolerance.
- Encineerina
^
Major. modifications have been few during the last several years.
These included the redesign and repair of the cooling water ocean intake structure, SB0 electrical wiring modifications, and changing ICW pump bearing water lubrication from external to self-i lubricating. Also, the four Unit 2 pressurizer steam space instrument nozzles were replaced with upgraded material (on 3/25/93). The licensee installed the redesigned Unit 1 EDG radiator fan drivers in Spring 1993. Unit I steam generator i
g replacement is being planned for 1997.
The last SALP-discussed plant modifications without design approval.
The licensee has taken positive measures to correct this practice.
i Engineering support to the plant has been good.
Staff engineers were available and on-site throughout the Unit 2 outage to support PC/M work and were integral to the resolution of pressurizer steam space-level: instrumentation nozzle weld cracks.
In fact, an engineer from site engineering was responsible for the t
identification of the boron deposits from the cracks.
Engineering support was also noted in'the leak repair of a Unit I shutdown cooling isolation valve body-to-bonnet leak. More recently, timely engineering support was noted in response to the weather-i related damage to the 1A main transformer.
n f
4.-
't e
m--
.,E,
~
n I'
19 a
Recent reviews of the licensee's control of fuel quality indicated that Juno Nuclear Fuels and site Reactor Engineering personnel were heavily involved in reviews of vendor performance.
Additionally, Reactor Engineering and Nuclear Fuels engineers have supported control room operators during plant startups and shutdowns.
Recent inspection.has indicated that potential problems exist in the area of vendor technical manual control. Additional inspection is planned in this area.
Plant Support Radiolooical Controls 1l The radiological control program continues to be effective with increased use of engineering controls and reduced respirator usage which were considered program strengths.
External and internal exposures were well controlled. Worker adherence to RWPs and radiological procedures was excellent.
The licensee continues to reduce the contaminated area, and personnel contamination events are consistently below goals. Audits were adequate; however, they tend to be compliance based. Management continued to support developmental training programs for health physics technicians.
The ALARA program was effective with several initiatives this period including use of robotics, new nozzle dams, and a reduction in microfiltration. The site HP organization maintains remotely controlled submersibles used both by St. Lucie and Turkey Point.
The licensee has recently placed an order for two robots to perform inspections inside the containment biological :hield at power.
Radiological controls for the Unit 2 outage were noteworthy. The licensee made extensive use of closed-circuit cameras to remotely provide HP coverage while maintaining dose rates ALARA. Good HP control of major evolutions, such as reactor vessel head lift, was also noted.
Emeroency Preparedness The licensee continues to maintain an effective EP program.
Security Security upgrades made prior to the last SALP were notable. The licensee continues to maint in a very effective security program.
Fire Protection The licensee continues to maintain an effective fire protection program.
I
i 20 Housekeepina-Housekeeping has been generally very good.
PART 3
SIGNIFICANT EVENTS
'3.1 SIGNIFICANT EVENTS BRIEFINGS (Past 12 Months)
Unit 1: None this period Unit 2:
Failure of a GE AK-25 Trip Circuit Breaker 3.2 ENFORCEMENT STATUS / HISTORY (Past 12 Months) j-Currently, there are no escalated enforcement actions pending at St.
Lucie.
The misalignment of bus LAB to DGIA which could render the DG inoperable and the incorrect CR log entries in this issue are currently unresolved, awaiting refueling outage testing to determine safety significance.
This item may be the subject of an enforcement conference.
STAFF 1NG AND T R.A I N I N G PART 4
j 4.1 OPERATIONS STAFF - GYERALL (8/94)
Above aversga performance of the operations staff has been noted.
Control room demeanor of personnel is above average.
Number of Shifts:
(RCO, SRO) Six shift rotation, 8-hour shifts; (NPO, ANPO, SNP0) Five shift rotation, 8-hour shifts.
Number of SR0s:
22 active /21 inactive' / 43 total Number of R0s:
30 active /2 inactive / 32 total i
Total Licensed Operators:
52 active /23 inactive / 75 total 3 SR0s perform only R0 duties and maintain SR0 licenses active only for R0 duties. This practice is being reviewed by RII operator licensing.
4.2 WORK FORCE (8/94)
EPL Contractor Plant personnel (excluding 713 122 disciplines below)
Training 63 0
i I
Quality Assurance /ISEG/ SPEAK 0VT 49 0
7.;
-..g
- q..
4 1
21 46-0
. Materials Management' Security =
11 122 Site Engineering 42 0
[
4.3 OPERATOR QUALIFICATION /REQUALIFICATION PROGRAM (Past Two Years) 4.3.1.REQUALIFICATION PROGRAM'
.F NRC-administered requalification exams were completed in October, i
1992. Results were good - 9 of 12 R0's passed and 12 of 12 SRO's passed. Three of the RO's failed the written exam and'one also failed the JPMs. The program was rated satisfactory.
j Requalification exams are currently in progress (10/94). To date, 1
20 of 24 SRO's.and 17 of'20 R0's have passed all portions of the ii exams.
Failures have included 5 written exams, 1 JPM, and 1
- j simulator failure.
4.3.2 INITIAL EXAMS Previous initial operator exams were conducted on April 29, 1991.
Six SRO upgrades were examined, and all six passed. Additional i
exams were completed October 25, 1991. Six operators, 2 SRO upgrades, and 1 instant SRO were examined. All passed. The last t1
.{
initial exam was given April 27 through May 1,1992, to 6 SRO A
upgrades and 2 R0s, and all passed. A hot license class of 15 persons was started in late February, 1992 (14 still in class).
The last initial exam was conducted in October 1993 - 10 of 10 l-prospective R0s. passed.
Initial exams are planned for October, l
1994, with 3 R0s and 7 SR0 Upgrades planned i
1-i 4.3.3 GENERIC FUNDAMENTAL EXAM On an NRC administered Generic Fundamental Exam on June 6, 1990, 6 ii of the,10 St. Lucie operators who took the exam passed. On February 6, 1991, 3 of 3 operators who took the exam passed. On June 6, 1991, one operator took the exam and passed. On February 10, 1993, all 12 operators who took the exam passed. One person took the exam on February 9, 1994, and passed. No further Generic Fundamental Exams have been taken.
4.4 PLANT SIMULATOR The simulator is on site and fully' certified to meet ANSI /ANS 3.5, 1985.
4 4.5 INPO ACCREDITATION i
All: training _ programs are maintaining INPO accreditation. The site specific: simulator has.been used for training since 1988 and has been fully certified for approximately 4 years.
Eight separate NRC 4
L
e-
's i
y 22 i-
-inspections in the form of operator examinations at the simulator have found no serious problems.
INSPEC' TION ACTIVITIES 3
. PART-5 5.1 INSPECTION FOLLOWUP OPEN ITEMS
SUMMARY
(UNITS 1 AND 2 COMBINED)
(10/6/94) 1 Pre Change from Division A
Total Last Report DRP 3
30 0
DRS 0
7
-3 1
DRSS 0
2
_0 Totals 3
39
-3 Note: Each item that applies to both units is counted as one item.
5,2 MAJOR INSPECTIONS IR-No.
Date J.y.ge 89-02 1/89 RG-1.97 i
89-03 3/89 NDE 89-07 3/89 EQ l
89-09 3/89 Design Control 89-24 10/89 Maintenance Team Inspection 89-27 11/89 E0P Followup i-i 90-09 4-5/90 OSTI 4
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 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 open TMI items.
1 1
k i
DRAFT / REGIONAL REVIEW
]
Leoeno ST. LUCIE 1
~
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DRAFT / REGIONAL REVIEW FIGURE 7.92b I
1 Legeno. Statisticci Signihecnce
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4
(*
DRAFT / REGIONAL REVIEW e
TABLE 8.92 ST. LUCIE 1 PI EVENTS FOR 93-2 i
SSF 06/09/93 LERs 33593006 50.72s PWR Mikla CON 0lfl0N EXISTED IN ALL MODES UP TO 100% POWER $!NCE AUGUST 1988.
GP W REACTOR TRIP INSTRtmENTATION SYSTEM PLANT PROTECTION SYSTEM DESC TNE RCS LOW FLOW REACTOR TRIP SETPOINT MAS SEEN APPROKIMATELY 3% NONCONSERVATIVE 51NCE AUGUST 1988.
THE CAUSE WAS A TYPOGRAPNICAL ERROR IN TNE REPORT USED TO DETERMINE THE SETPolNT.
PI EVENTS.FOR 93-3 NONE PI EVENTS FOR 93-4 NONE j
PI EVENTS FOR 94-1 SSA 01/13/94 Leas 33594002 50.72s: 26605 PWR Mist: POWER OPERATIONS AT 100%
DESC
- AN INADVERTENT UNDERVOLTAGE SIGNAL'INITI ATED AN EMRGf.NCY DIESEL GENERATOR START AND SUBSEQUENT LOADING OF ITS ASSOCIATED VITAL SUS WHILE PERFORMING TEsis Of fME UNDERVOLTAGE RELAY.
SCRAM 03/2s/94 LERs 50.72s: 27006 PWR Mist: POWER OPERATIONS AT 68%
DESC
- AN AUTOMATIC REACTOR TRIP OCCURRED, CAUSED BY AW lhADVERTENT OPENING OF THE CENERATOR EXClit2 FIELD BREAKER.
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DRAFT / REGIONAL REVIEW FIGURE 7,93o
' coenc:
~
ST. LUCIE 2
- w rv ag Trew
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4 DRAFT / REGIONAL REVIEW FIGURE 7.93b ST. LUCIE 2
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'O 59 6 4
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Safety System Fokses -
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- o
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Signifkont Events -
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1 4 ~
\\
j DRAFT /REGIONRL REVIEW TABLE 8.93 ST. LUCIE 2 i
PI EVENTS FOR 93-2 NOME PI EVENTS FOR 93-3 j
NONE j
PI EVENTS FOR 93-4 NONE PI EVENTS FOR 94-1 NONE 4
1 1
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i PAGE 1
i t
ST. LUCIE OPEN ALLEGATIONS AS OF 10/04/94 ALLEGATION: RII-93-A-0185 FACILITY:
ST LUCIE I DATE RCVD:
930927
SUBJECT:
QUESTIONABLE MAINT PRACTICES ASSOCIATED WITH VENDOR AND DUE DATE:
-941027 PLANT DRAWING CONTROL DAYS OPEN:
372 ACTION PNDG:
AP: DRP/PB2 CLOS PROV TO EICS 7/20. EICS ADMIN CLOSE IR:94-13 RSP DIV/LCA:
[EICS]
ACTION DUE DATE: DUE: 07/15/94 ALLEGATION: RII-94-A-0083 FACILITY:
ST LUCIE 1 DATE RCVD:
940331
SUBJECT:
DRAW 8 RIDGES BETWEEN THE SOUTH END OF HUTCHINSON ISLAND AND DUE DATE:
940830 MAINLAND WILL BE OUT OF SERVICE DURING '94 FOR UPGRADES AND DAYS OPEN:
187 ACTION PMDG:
AP: DRSS/RPEP CLOS MEMO PROV TO EICS ON 6/17. EICS ADMIN CLOS BY RSP DIV/LCA:
[EICS]
ACTION DUE DATE: DUE: 07/29/94 ALLEGATION: RII-94-A-0105 FACILITY:
ST LUCIE 1 DATE RCVDi 940520
SUBJECT:
WELDING SUPERV RCVD NEGATIVE PERFORMANCE APPRAISAL AND THEN DUE DATE:
941220 REMOVED FROM A SUPERVISORY POSITION DAYS OPEN:
137 ACTION PNDG:
AP:NO SAFETY ISSUE. EICS SEND LTR TO CI ADVISING OF DOL RIGHTS AND ASK FOR SAFETY CONCERNS RSP DIV/LCA:
[EICS]
ACTION DUE DATE: DUE:
ALLEGATION: RII-94-A-0119 FACILITY:
ST LUCIE 1 DATE RCVDi 940615
SUBJECT:
NOT ENOUGH GUARDS, LT HAS DRINGKING PROB, SECURITY OFFICER DUE DATE:
941015 SNELLS OF ALCOHOL, SEC GUARD STRUCK BY LIGHTNING, WEAPONS',
DAYS OPEN:
111 ACTION PNDG:
AP:DRSS/NMSS INSPECT BY IR:
"SP DIV/LCA:
DRSS/NMSS
.iTION DUE DATE: DUE: 09/02/94 i
g m,w
'h $A A.
.m
-S.h.-
%+F #'e J
--AsJsi
.w 4
%=#m,$
.au.
PAGE' 2
ST. LUCIE OPEN ALLEGATIONS AS OF 10/04/94 ALLEGATION: RII-94-A-0157 FACILITY:
ST LUCIE I DATE RCVD:
940831
SUBJECT:
CONCERN REGARDING LICENSED OPERATOR OVERTIME POLICY POTENTIA DUE DATE:
941131 LLY COMPRONISING SAFETY.DUE TO 16 HOUR DAYS WITH ONLY 8 HOUR
' DAYS OPEN:
34 ACTION PNDG:
AP: DRP/P82 (VERRELLI) & EICS PREP CLOSURE LTR TO ALGR EXPLA INING THAT HIS REQUEST WILL BE FORWRDED TO NRR AND CLOSE CAS RSP DIV/LCA:
DRP/PB2 ACTION DUE DATE: DUE:
m m
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ATTACHMENT 3 NRR OPERATING REACTOR ASSESSMENT NRR ASSESSMENT FOR ST. LUCIE
,1 October 1994 r
4 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 4
,I responded in May 1994 restating their previous position and stating that they 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 r
4
~ 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 FPL, however, the staff did not pursue review of this performance based approach i
{
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.
3
-The plant continues to perform well. The latest SALP evaluation had ratings of 1
?
in all categories.
)
Contact:
Jan A. Norris S04-1483 1
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On January 9, 1994, Unit 1 was manually tripped when the 15 P
Main Feedwater Pump opuriously tripped. Poet trip response was normal and the unit wee returned to power on January 10.
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2.
On March 28 1994 Unit 1 experienced an automatic reactor trip nE5 when a maintenance foreman opened the generator exciter breaker (on the wrong unit). The unit was restarted on April 2.
1.
On April 3,
1994, during unit restart, Unit 1 automatically E
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N powerea hr the = =oo - aich co e o ee eret rese=ar =rio breakers to qmn on overcurrent.
Unit 1 returned to power en f
April 4, 1994.
4.
On June 6, 1994, Unit I automatically tripped during a severe 40 -
thunderstorm as a result of aluminum flashing from an adjacent building being blown across two phases of the 1A main p
treneformer output. The reactor wee taken critical on June e and returned on line on June 11 after main transformer repairs O
were completed.
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"",I **"*the unit was returned to power later on the same date.
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Graph does not include power reductions j
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or required repairs.
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ST. LUCIE 2 Operational Period January 1,1994 through October 5,1994 1
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On February 13, 1994 Unit 2 wee ebut down for the 1994 R
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ne -tese lasted a dare and== -it wee restarted on April 15.
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On April 23, 1994, Unit 2 automatically tripged due to an RPS
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On July 9, 1994 Unit 2 wee taken off line neode 2) because the 281 RCP lower oil level indication failed, incorrectly showing g-a leak. The unit was returned on line on July 10, 1994.
4.
On July 14, 1994, Unit 2 was shut down to allow repair of a atuck-closed trip circuit breaker, h e unit was restarted and O
placed on line on July 15, 1994.
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MIPC0007 LONG RANGE INSPECTION PLAN
^
PAGE 2
50RIED ST IPE/SALP AREA /PROCEDimelffARGET DATE REGION: 2 REGUESTED DOCKET: 050-00335 REQUESTED DATE: 01/02/1994 REQUESTED ORG: ALL REQUESTED EMP: ALL~
UNIT NAME: ST LUCIE 1 DOCKET NUMBER: 050-00335 SALP SEGIN DATE: 01/02/1994 SALP END DATE: 07/C8/1995
- PROCEDURE PROCEDURE IPE SALP INS RESP LEAD 94 95 LAST NUMBER TITLE CDE AREA FRG ORG STAFF JFMAMJJAS0NDJFMAMJJASOND IkS RPT
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-20* MONTNLY RESIDENT -
2232 SBE M
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+01* RECORDS AND REPORTS AF PLTSUP 2421 WJT C
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-01* ACCESS CONTROL - PEOPLE AF PLTSdP 2421 WJT M
i 94021 37550 02* ENGINEERING AF ENG C
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-01 SAFETY ASSESSMENT CO OPS C
2232 58E M M M
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-01.Ltc OPERATOR REQUAL PRGRM CD OPS C
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-19 MONTHLY RESIDENT RI OPS M
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_'10/06/94 SORTED ST IPE/SALP AREA /PROCEDURETTARGET DATE PAGE 3
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REGION: 2
' REQUESTED DOCKET: 050-00335 REQUESTED DATE: 01/02/1994 REQUESTED ORG: ALL-REQUES.ED EMP: ALL UNIT NAME: ST LUCIE 1 DOCKET NUMBER: 050-00335 SALP DEGIN DATE: 01/02/1994 SALP END DATE: 07/08/1995 PROCEDURE
' PROCEDURE IPE SALP INS, RESP LEAD.
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-01* FOLLOWUP - ENGINEERING RI ENG 2232 ANI MM T
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-01* FOLLOWUP - MAINTENANCE.
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-01* MANAGEMENT MEETINGS Rt OTHER 2232 ANI
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94012 2515/118 01 SERVICE WATER STS OP PRGM St OPS 2323 TDP T
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94011 2500/020 01 ATWS - 10CFR50.62 St MAINT 2200 SBE T
. 2515/110-01 PRHNdCE OF S/R CV
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2500/028 01 EMPLOTEE CONCERNS PROGRAM $1 OTHER 2200 SBE I
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. LONG RANGE INSPECTION PLAN
.10/06/94-SORTED BY IPE/SALP AREA /PROCEDUREfTARGET DATE PAGE 2
REGION: 2
- REQUESTED DOCKET: 050-00389 REQUEST;D DATE: 01/02/1994 REQUESTED ORG: ALL' REQUESTED EMP: ALL
' UNIT NAME: ST LUCIE 2 DOCKET NUMBER: 050-00389 SALP BEGIN DATE: 01/02/1994 SALP END DATE: 07/08/1995 PROCEDURE PROCEDURE IPE SALP 1NS RESP' LEAD 94 95 LAST.
- NUMBER TITLE CDE AREA FRG ORG STAFF JFMANJJASONDJFMAMJJASOND INS RPT 71707
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-01' FIRE PROTECTION CO PLTSUP O 2232 SBE T
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-01 PLANT SUPPORT ACTF#ITIES CO PLTSUP Y 2232 ANI MMC T
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-01 PNYSICAL SECURITT PROGRAM CO PLTSUP C 2421 DNM
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-01 EP ENERCISE.
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-02* EP ENERCISE CO PLTSUP Y 2412 GWS
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-01 EP SCENARIO CO PLTSUP Y
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-01 EFFLUENTS, WATER CNEME Of CO PLISUP C 2411 CQR P
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2232 SSE T T T T T T T
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-01 SURVEILLANCE OBSERVATION CO MAINT B
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-01 ISI. OsSERVATIONS CD MatNT C
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-01* CORCTVE ACTNS VIOL & DEV OA SAQV-0 R
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-01* REFUELING ACTIVITIES RI OPS 2232 TFJ
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-19 MONTNLY RESIDENT RI OPS M
2232 SBE MMMMM M M
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-01* OPEN ITEM FOLLOWUP Rt OPS 2232 SSE MM M i
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-01* FOLLOWUP - PLANT OPERATIO El CPS 2232 58E M M T
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-02 PROMPT ONSITE REPNSE EVNT RI OPS M
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-02* PLANT SUPPORT ACTIVITIES RI PLISUP V 2232 STR M
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-01 OCPTML EMP CTRL EXT GUTGS RI PLTSUP 2413 T
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CIPC0007 LONG RANGE INSPECitak PLAN 10/06/94 SORTED BY IPE/SALP AREA /PROCEDUReiff ARGET DATE
.PAGE 3
REG 10N:.2 REQUESTED DOCKET: 050-00389 REQUESTED DATE: 01/02/1994 REQUESTED ORG: ALL REQUESTED EFF: ALL UNIT NAME: ST LUCIE 2 DOCKET NUMBER: 050-00389 SALP BEGIN DATE: 01/02/1994 SALP END DATE: 07/08/1995 PROCEDURE PROCEDURE IFE SALP INS RESP LEAD 94 95 LAST NUMBER TITLE CDE AREA FRC ORG STAFF JFMAMJJASONDJFMAMJJASOND INS RPI 90712
-01* IN-OFFICE LER REVIEW RI SAQV-O R
2232 58E
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94005 92700
-01* ONstTE LER REVIEW RI SAQV-O R
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-08 ONSITE ENGINEERING RI ENG 8
2232 SBE M
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-02* DESIGN CNANEES & MODS-RI ENG C
2232 SIR M
i 94013 37701
-01* MODS NEEDING NRC APPROVAL. RI ENG 2312 JVL M
T 94008 37828
-01* INSTAL & TEST MODS RI ENG C
2232 SBE MM i
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-01* EROSION / CORROSION PRGMS RI MAINT 2312 BRC C
T 94008 61726
-10 SURVEILLANCE OBSERVATION El MAINT e
2232 SBE M
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-01* MAINTENANCE PRACTICES El MAINT 2312 JVL M
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-19 MAINTENANCE ceSERVATION RI MAINT M
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-01* INSTRUMENT MAINTENANCE RI MAINT 2232 AMI
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-01* ELECTRICAL MAINTENANCE RI MAINT 2311 JRN M
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-04 ISI - OsSERVATIONS RI MAINT C
2312 JVL
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-01* ISI - DATA REVIEW RI MAINT 2312 JVt
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-01* FOLLOWUP - MAINTENANCE RI MAINT 2232 AMI R
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-Ot* NANAGEMENT MEETINGS RI OTHER 2232 ANI
- C T
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-02* MANAGEIENT MEETINGS RI OTHER 2232 AMI
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-03* PROMPT ONSITE REPNSE EVNT RR OPS M
2232 SBE M
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-01* NUCLEAR WELDING RR MAINT 2312 BRC C
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-01* ISI - PROGRAM RR MAINT 2312 HJC P
T 94010 73052
-Ol* ISI - PROCEDURES RR MAINT 2312 NJC
- P T
94010 T3753
-03* ISI - DeSERVATIONS RR MAINT C
2312 NJC PM i
94010 2515/118-01 SERVICE WATER SYS OP PRGM St OPS 2323 TDP T
2515/120 STATION BLACKOUT SI OPS 2311 MYS M
94006 2515/123-01 IMPLMNT REVISED 10 CFR PA SI PLTSUP 2413 T
2515/109-01 Mov TESTING - GL 89-10 St ENG 2313 C2C M
94011 2500/020 01 ATWS - 10CFR50.62 St MAINT 2200 SSE T
2515/110-01 PRFMNCE OF S/R CV St MAINT 2313 CZC T
2500/028-01 EMPLOTEE CONCERNS PROGRAM SI OTHER 2200 SBE T
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i October 19, 1994 ST LUCE Recent Sianificant Events / Findinas Date Cause Identified Event / Finding 4
SALP period 11 began 1/2/94 1/9/94 Equipment Licensee Manual. reactor trip - feed pump control failure circuit failure (IR 94-01, LER U1 94-01) 1/13/94 Surveill.
Licensee Inadequate load shed of the IA3 4160 procedure volt bus resulted in a lA EDG auto start error
- caused by procedure error in testing UV relays.
(LER U1 94-02) i 2/11/94 Security Licensee Failure to provide required compensatory 2
error measures in response to a security computer system failure.
(NCV 94-02-01) 2/17/94 Operator Licensee Mispositioned valve discovered. Aux.
i error pressurizer spray isolation valve had been locked closed (vice open) since 3/27/93.
(NCV 94-09-01, LER U2 94-01) 2/28/94 Refueling Licensee Inadequate grappling of a fuel assembly procedure &
/ NRC caused by~ error in Recommended Move List operator and operator error in following error procedure. Two related TS interpretation questions: Adequacy of a single operator on refueling bridge during core alterations; and required level of review and approval of Recommended Move List.
(IR 94-09) 3/4/94 Engineering Licensee Failure to report an EDG failure. (NCV error 94-06-01) 3/4/94 Engineering Licensee Inadequate design controls on Unit 2 error sequencer charging pump loading block.
(NCV'94-06-02) 3/7/94 Management NRC Nonconservative licensee entry into a TS decision LC0 action statement for lA EDG fuel oil tank level. (IR 94-09) 3/16/94 Equipment Licensee A Unit 2 pressurizer instrument nozzle failure that had been repaired a year ago was found leaking while the unit was in Mode 5.
The unit remained shut down for repairs.
(IR 94-10, LER U2 94-02)
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f*
e 2
3/16/94 Engineering NRC Regional inspector had two Unit 2 SL4 errors violations:
- 1) corrective action for an 11/24/92 water hammer event was done without accumented instructions or procedures, resulting in operating until 3/94 with five snubbers on the SRV and PORV tailpipes inoperable.
- 2) Failure to write a nonconformance report for a damaged pipe support in March 1994.
(IR 94-08) 3/28/94 Maintenance Licensee Unit 1 auto reactor trip. Maintenance error foreman opened generator exciter breaker
- on wrong unit. Operators had clearance on Unit 2.
(IR 94-12, LER U1 94-03) 3/29/94 Equipment Licensee Body-to-bonnet leak on Unit 1 non-failure isolable ten-inch shutdown cooling isolation valve.
Leak rate about two drops /second (TS-allowable).
Licensee installed exterior clamp and leak repair compound on valve.
(IR 94-12) 4/2/94 Equipment Licensee Unit I startup transformer output i,
failure breaker mechanically failed to open.
Bkr returned to mfgr for analysis.
(IR 94-12) 4/3/94 Operations Licensee Unit 1 auto reactor trip from 19% power procedure while deenergizing the 4160 Volt non-error (Lack vital bus for SU Tx output breaker of maintenance. With the A emergency bus sufficient on the EDG, which was running at a depth in different frequency from the grid, the review of paralleled CEA MG sets developed procedure circulating currents and tripped several change) reactor trip circuit breakers.
A partial reactor trip tripped the turbine, which tripped the reactor.
(IR 94-12, LER VI 94-04)
. f' 4
3 4/3/94 Surveill.
Licensee During testing for Unit 2 modifications error the licensee discovered that the 4160 V (AB Bus] swing bus components [C ICW Pump and C CCW Pump) would not strip from the bus upon undervoltage if the bus were aligned to the B bus.
A-missing jumper wire in the switchgear (from initial construction) was the proximate cause.
(SL4, Inadequate Corrective Action for 1992 NRC VIO for inadequate surveillance test - IR 94-12) 4/7/94 Maintenance NRC Contractor personnel made and contractor i
error QC accepted pressurizer nozzle weld prep
- i that did not meet procedural requirements for bevel angle.
Licensee engineering had specified overly tight tolerances.
(SL4 94-10-01) 4/16/94 Equipment Licensee Cracked weld in RCS pressure boundary -
failure 3/4 inch instrument line attached to 281 12-inch safety injection header.
Licensee accomplished weld repair using SI-to-loop check valve for isolation.
(IR 94-12) 4/21/94 Operator Licensee Unit 2 reactor power increased from 26 inattentive to 31% due to positive MTC and operator ness inattentiveness.
(IR 94-12) 4/23/94 Miv. error Licensee Unit 2 auto reactor trip from 30% power caused by RPS cabinet wiring error for trip bypass circuit, from original unit construction.
(IR 94-12, LER U2 94-03) 4/23/94 Equipment Licensee Following unit 2 trip, steam bypass failure system operated unexpectedly and dropped RCS temp by seven degrees F, pressurizer heaters turned off.
Prompt operator action was taken.
Extensive mechanical repairs were required. Unit 2 was returned to power on April 26, 1994.
(IR 94-12) 4 5/6/94 Engineering NRC Inadequate corrective action for MOVs error which stalled during surveillances.
(SL4 94-11-01) 5/28/94 EP Licensee Emergency supplies in control room less procedure that stated in FSAR.
(DEV 94-13-02) error 4
T i
I 4
6/6/94 Equipment Licensee Unit I trip from 100% power during a failure -
severe thunderstorm when the main due to transformer locked out the generator, storm causing a reactor trip. The lockout occurred due to a phase differential on main generator transformer lA. This l
occurred as a result of an approximately j
8' length of flashing, from an adjacent building, which was blown across two phases of the 1A main transformer output. The reactor was taken critical l
on June 8; however, the licensee elected to remain off-line until repairs were 1
completed to the 1A main transformer.
i Unit I was placed on line on June 11.
(IR 94-14, LER 94-05) 6/28/94 Maintenance Licensee Inoperable Unit 2 RAB ventilation error exhaust WRGM.
(NCV 94-14-02, LER U2 94-04) 7/8/94 Operator Licensee TS 3.0.3 entry due to placing 2Al LPSI error pump and 2B charging pump 00S at the same time.
(IR 94-15, LER U2 94-05) 7/9/94 Equipment Licensee Unit 2 turbine was shut down and reactor failure power reduced to Mode 2 because the 2B1 RCP lower oil level indication showed a leak. The sump was not leaking and an unusual failure in the indication system was determined to be the reason for the indication. After repair, the reactor was returned to Mode 1 and the turbine started up on July 10, 1994. (IR 94-15) 7/14/94 Equipment Licensee During surveillance test, TCB 5 failed failure to open. It had stuck shut. A broken piece of bakelite had fallen into the trip mechanism. The unit was restarted and placed on line on July 15, 1994. (IR 94-15, LER U2 94-06) 7/14/94 Operations NRC Operators did not follow Unit 2 Tech error Spec LC0 time requirements regarding shut down on July 14 to allow repair of a stuck-closed trip circuit breaker.
(SL4 94-15-01) 8/12/94 Operations /
NRC The licensee was unloading new fuel for Maintenance Unit I with a hoist grapple that was error missing the safety latch sleeve locating pin.
The safety sleeve functioned by friction only.
(IR 94-18) i
a c'
CI15 5
8/28/94 Equipment Licensee Unit I was taken off line (Mode 2) to
~
failure repair a DEH leak. The unit was.
returned on line later the same day.
(IR 94-20) 8/29/94 Operations NRC Operators placed 1A EDG in an electrical errors lineup for which TS-required surveillance tests had not been performed (with the safety-related swing bus powered from it). Also, related control room log entries appeared to be inaccurate.
(URI 94-20-01) 9/30/94 Operations, NRC Plant personnel not trained on IPE and maintenance not using it for work planning and a
deficiency scheduling.
(IR 94-20)
NRC CONCLUSION: The mispositioned valve and water _ hammer occurred.over a year ago. None of the'above personnel errors are similar. These events and findings mayJbe precursors to declining performance.
Further very close inspection and assessment is required.
s
January 5, 1995 ST LUCIE Pecent Sianificant Events / Findinas Date Cause fdentified Event / Finding I1/2/94 SALP period 11 began 1/9/94 Equipment Licensee Manual reactor trip - feed pump control failure circuit failure.
(IR 94-01, LER VI 94-01) 1/13/94 Surveill.
Licensee UV relay test resulted in load shed of procedure the IA3 4160 volt bus and a lA EDG auto i]
weakness start - caused by procedure weakness combined with relay anomaly.
(LER U1 94-02) 2/11/94 Security Licensee Failure to provide required compensatory error measures in response to a security computer system failure.
(NCV 94-02-01) 2/17/94 Operator Licensee Mispositioned valve discovered. Aux.
error pressurizer spray isolation valve had been locked closed (vice open) since 3/27/93.
(NCV 94-09-01, LER U2 94-01) 2/28/94 Refueling Licensee Inadequate grappling of a fuel assembly 1
procedure &
/ NRC caused by error in Recommended Move List operator and operator error in following i
error procedure.
(IR 94-09) 3/4/94 Engineering Licensee Failure to report an EDG failure. (NCV error 94-06-01) 3/4/94 Engineering Licensee inadequate design controls on Unit 2 j
error sequencer charging pump loading block.
(NCV 94-06-02) 3/16/94 Equipment Licensee A Unit 2 pressurizer instrument nozzle failure that had been repaired a year ago was found leaking while the unit was in Mode 5.
The unit remained shut down for repairs.
(IR 94-10, LER U2 94-02) i 0
\\
1 I
1p
- g -
a 2
3/16/94 Engin' eering -
NRC Regional inspector had two Unit'2 SL4 corrective violations:
- 1) corrective action for action an 11/24/92 water hammer event was done without documented instructions or procedures, resulting in operating until 3/94 with five snubbers on-the SRV and.
PORV tailpipes inoperable. 2) Failure to write a. nonconformance report for a damaged pipe support in March 1994.
(IR:
94-08) i.
3/28/94 Maintenance Licensee Unit-1 auto reactor trip. Maintenance error:
foreman opened generator exciter breaker-
- on wrong unit. -Operators had clearance on Unit 2.
(IR 94-12, LER U1 94-03) i 4/3/94 Operations Licensee Unit I auto reactor trip from 19% power J-procedure while deenergizing.the 4160 Volt non-error (Lack vital bus for SU Tx output breaker of maintenance. With the A emergency bus sufficient on the EDG, which was running at a depth in different frequency from the grid, the review of paralleled CEA MG sets developed procedure circulating currents and tripped several change) reactor trip circuit breakers. A partial reactor trip tripped the turbine, which tripped the reactor.
(IR 94-12, LER VI 94-04) 4/3/94 Surveill.
Licensee During testing for Unit 2 modifications error the licensee discovered that the 4160 V (AB Bus] swing bus components [C ICW Pump and C CCW Pump] would not strip from the bus upon undervoltage if the bus were aligned to the B bus. A missing wire in the switchgear (from initial construction) was the cause.
(SL4, Inadequate Corrective Action for 1992 NRC VIO for inadequate surveillance test - IR 94-12) 4/7/94 Maintenance NRC Contractor personnel made and contractor error QC accepted-pressurizer nozzle weld prep that did not meet procedural requirements for_ bevel angle.
Licensee engineering had specified overly tight j.
tolerances.
(SL4 94-10-01) 4/21/94 Operator Licensee Unit 2 reactor power increased frota 26 1
inattentive to 31% due to positive MTC and operator ness inattentiveness.
(IR 94-12) i L'.
~
9-L 3
4/23/94 Mfg. error Licensee Unit 2 auto reactor trip from 30% power 4
caused by RPS cabinet wiring error for trip bypass circuit, from original unit 1
construction.
(IR 94-12, LER U2 94-03) 4/23/94 Equipment Licensee Following unit 2 trip, steam bypass failure system operated unexpectedly and dropped RCS temp by seven degrees F, pressurizer heaters turned off.
Prompt operator action was taken. Extensive mechanical repairs were required.
Unit 2 was returned to power on April 26, 1994.
(IR 94-12) 5/6/94 Engineering NRC Inadequate corrective action for MOVs l
error which stalled during surveillances.
j (SL4 94-l?-01) 5/28/94 EP Licensee Emergency supplies in control room less corrective that stated in FSAR.
(DEV 94-13-02) 1 action 6/6/94 Storm Licensee Unit I trip from 100% power during a.
damage severe thunderstorm when the main j
transformer locked out the generator, causing a reactor trip. The lockout occurred due to a phase differential on main generator transformer IA. This occurred as a result of an approximately 8' length of flashing, from an adjacent building, which was blown across two phases of the 1A main transformer output. The reactor was taken critical on June 8; however, the licensee elected y
to remain off-line until repairs were completed to the 1A main transformer.
t Unit I was placed on line on June 11.
(IR 94-14, LER 94-05) 6/28/94 Maintenance Licensee Inoperable Unit 2 RAB ventilation error exhaust WRGM due to failure to connect sample lines.
(NCV 94-14-02, LER U2 94-04) 7/8/94 Operator Licensee TS 3.0.3 entry due to placing 2A1 LPSI error pump and 28 charging pump 005 at the same time.
(IR 94-15, LER U2 94-05)
g 4
l 7/9/94 Equipn.ent Licensee Unit 2 turbine was shut down and reactor failure power reduced to Mode 2 because the 281 RCP lower oil level indication showed a leak. The sump was not leaking and an unusual failure in the indication system was determined to be the reason for the indication. After repair, the reactor was returned to Mode 1 and the turbine started up on July 10, 1994. (IR 94-15) 7/14/94 Equipment Licensee During surveillance test, TCB 5 failed failure to open. It had stuck shut. A broken piece of bakelite had fallen into the trip mechanism.
The unit was restarted i
and placed on line on July 15, 1994. (IR 94-15, LER U2 94-06) 7/14/94 Operations NRC Operators did not follow Unit 2 Tech error Spec LCO time requirements regarding shut down on July 14 to allow repair of i
a stuck-closed trip circuit breaker.
(SL4 94-15-01) 8/12/94 Operations /
NRC The licensee was unloading new fuel for Maintenance Unit I with a hoist grapple that was error missing the safety latch sleeve locating pin.
The safety sleeve functioned by friction only.
(IR 94-18) 8/28/94 Equipment Licensee Unit I was taken off line (Mode 2) to failure repair a DEH leak.
The unit was returned on line later the same day.
(IR 94-20) 8/29/94 Operations NRC Operators placed 1A EDG in an electrical errors lineup for which TS-required j
surveillance tests had not been j,
performed (with the safety-related swing bus powered from it).
Also, related control room log entries appeared to be inaccurate.
Inadequate corrective action to NRC violation regarding EDG operability.
(SL4 94-22-01)
Improper modification of control room logs.
(SL4 94-22-02) 9/30/94 Operations, NRC Plant personnel not trained on IPE and maintenance not using it for work planning and deficiency scheduling.
(IR 94-20) 9/30/94 Operations NRC During requal exam, a licensed operator weakness exhibited an apparent disregard for E0Ps.
(IR 94-19)
)
i 5
1 i
9/30/94 Operations Licensee Failure to notify the NRC of changes in error status of licensed operators' medical conditions.
(NCV 94-19-01) 10/26/
Storm Licensee Unit 1 automatically tripped due to a 94 arc-over of a potential transformer due to salt buildup on switchyard insulators.
(IR 94-22) 11/5/94 Operations, Licensee Waste gas release on Sept. 10, 1993, Maintenance with meteorological instruments out of errors service.
(NCV 94-22-03) 12/3/94 Procedure Licensee Failure to perform TS-required periodic review procedure reviews.
(NCV 94-24-01) inadequacy 12/3/94 Maintenance NRC Inadequate process for changes to vendor procedures technical manuals.
(SL4 94-24-02) inadequacy 12/31/
Engineering Licensee Inadequate design control of Na0H cross-94 design connection between ECCS trains.
(NCV error 94-25-01)
NRC CONCLUSION: The mispositioned valve and water hammer occurred over a year ago.
Personnel errors generally reflect inattention to detail. While events in the last year indicated declining performance, the number of events has decreased in the last quarter. While it is too early to conclude that the decline has abated, recent management actions appear to be having positive affects on corrective actions, maintenance, and operations.
Further very close inspection and assessment is required.
)
l
-~
ST. LUCIE 1-Operational Period April 5,1994 through January 5,1995 1
2 3
100
=
P
~
1.
On June 6 1994, Unit 1 automatically tripped during a severe R
ta=4 r===
r==2 = ar 2 -'-- r2 aiae== = as e==
building being blown acrces two phases of the 1A m in
{
transformer output. The reactor was talten critical on June 8 and returned on line on June 11 after main transformer repairs
{
were completed.
T 2.
't I went off line (Mode 21 on August 28 to repair a DIDI 1.d. D e unit was returned to pouer later on the same date.
3.
On October 26, 1994 Unit 1 automatically tripped due to arc-over of a switchyard potential transformer due to salt buildup on insulators. ne unit then remained shut down for a refueling outage. Unit i vas restarted on atovember 29 and P
placed on line on December 1.
O W
20 -
E R
0 amunmunmununn i unmmunnmunnmmmun nunnumnunmuni:munmmui numunnmn A
M J
J A
S O
N D
J PERIOD OF OPERATION Graph does not include power reductions for routine repairs, waterbox cleaning, or required repairs.
_ ~.
ST. LUCIE 2 Operational Period April 5,1994 through January 5,1995 1
2 34 l& ~
v
<n\\
P 1.
On February 13, 1994, Unit 2 was shut down for the 1994 refueling outage. The outage lasted 65 days and the unit was
(
g_
restarted on Apr21 13.
R 2.
On April 23, 1994, Utait 2 automatically tripped due to an RPS cabinet manufacturer's wiring error which manifested itself C
during RPS troubleshooting. The wiring error had existed since the original manufacture of the cabinet.
Unit 2 was returned E
60 -
to po-er on aerit 25
>>>4.
3.
On July 9, 1994 Unit 2 was taken off line uude 23 because the 2B1 RCP lower oil level indication failed, incorrectly showing T
a leak. The unit was returned on line on July 10, 1994, 4.
On July 14, 1994, Unit 2 was shut down to allow repair of a stuck-closed trip circuit breaker. The unit was restarted anus P
placed on line on aeir 1s. 1994.
OW 20 -
E-R 0
nnco innmunnnnuninunnmm connunnmonunnonunnumnnnunmmunnmumununnuun A
M J
J A
S O
N D
J PERIOD OF OPERATION Graph does not include power reductions for routine repairs, waterbox cleaning, or required repairs.
l l
1 I N S P ECTION P LAN er.r
.. %,.r.
o w. e r.,
3 Inspection of:
N bu nt6 b9 N
on i
8 re n u toneen Type of Inspection:
Speci
~ii U'hannounced/Back Shif Submitted by:
Accompanyino Personnel: 6Maddr NC[/N 7KrehM i
Outstanding Items Reviewed and the Following Selected for Inspection /<. C./p r f 8 7 j
W<I D el e c : cnt matters. Oll No.
s C. kl,1Ier-Wefr%
rem Q ) M vious epmi items. OIL No.
//ob
( M lid. ins ur "otices. OIL No.
MMir rou u ni: ilcensee reports. OIL No.
j Date Submitted to Section Chief:
///C/98
~
Oate Projects Informed:
/ / /6/ 9 (v
/
Date Provided to Proj3 cts:
Current %
Carwege (Octmeel inspection Area or Module inspector Carvnente or Corwete Steve toptem)
S230f-Gvnf. & now.Mc % Dum iP w In-s
^
/
r i_ ~
$fLl5
?Y
/A2 Y
b Module H_r1 Current Planned Hrs Complete 8234/
O 8 2 3C 2-I ?_
L Instructions by Branch Chief:
Review TPPR Meeting Minutes Acoroved by:
1
/ // 7(
(Branch Cheef) beto In charge of Exit Interview: (!). E <t br-g location Durina inspection Hotel or Motel: //nl[dau Iut dekobd\\
(SON 225-3nno Telephone:
licensee
Contact:
R W tdM le c,-
T Telephone: Tven i Y 0 5 S e 4 7 s
Distribution:
Report Nos.-
IO ~ 3 3 N Od -o 2-Approving Branch Chief: c TseuY
.5D - 36 9 / 96 -C 2-
\\
Inspectors Me# gre{ h, C/ae6, S</m
~'
s i\\
Project Branch Chief: K, M fs
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Project Engineer: 6. L act Original to Branch File:
S:\\DRS\\lNSPLAN.SHO - 10/20/95
INSPECTION PLAN 4
INSPECTION OF:
St. Lucie INSPECTION DATES:
October 7-18,1996 REPORT NUMBER:
50-335, 389/96-17 (Resident inspector Integrated Report)
(Oct.13-Nov. 9,1996) i TYPE OF INSPECTION: Engineering (Core lupection) Module 37550 PLANNED INSPECTION HOURS: Approximately 140 hours0.00162 days <br />0.0389 hours <br />2.314815e-4 weeks <br />5.327e-5 months <br /> j
INSPECTORS:
J. York, C. Rapp, M. Miller (SRI)
INSPECTION OBJECTIVES: (Inspection Procedures used as Guidance. Provide brief wnte-up on objective of inspection) l The inspectors will concentrate on the Linear Range Nuclear Instrurr;entation being out of service due to miswiring. Other NI modifications were made during tae outage but this inspection will concentrate only on the miswirino of the linear Nis. Three areas will be inspected: Engineering's role, maintenance's role, and the safety signWeance of the event.
1)
ENGINEERING l
-Review the event with the licensee (LER 50-335,90-010)
-Review TS
-Review FSAR Sections
-Review Vendor Manuals
-Review Root Cause
-Review Modification Package
-Review Engineenng Procedures Used for Modifications
-Review Similar Incident at Calvert Cliffs (Contact RI) 2)
MAINTENANCE
-Review Work Orders
-Review Any QC Documentation
-Review Post Maintenance
-Review Vendor Manuals For Detectors (ref. CE Detector installed on the B channel) 3)
CORE PHYSICS /NI EFFECT-SAFETY SIGNIFICANCE
-Review design input documentation on Beacon system
-Review licensee analysis
-Review CPC function and inputs
-Review completed thermal margin surveillance This is a suggested out:ine for planning purposes by the inspectors and will be changed if inspection results warrant.
By following the items in the outline we should be able to achieve the following:
- 1) Determine the root cause, contributors to the production of an inadequate design modification package. ( U SE t-ICEASFE-OfS/ gov A@ CESS R.0W cg)d}y
- 2) Perform a barrier analysis of the failure.
- 3) Assess adequacy of licensee's root cause evaluation.
- 4) Assess adequacy of licensee's completed and planned corrective actions.
- 5) Determine the safety impact of 3 inoperable Ni channels during startup and power operation.
- 6) Were there any QA assessments of the barriers which failed? If a condition existed was it generic?
REQUIREMENTS INSPECTING AGAINST:
Observations will be compared for compliance with applicable licensee procedures, Technical Specifications, and the Updated FSAR.
SITE INTEGRATION MATRIX REVIEW: (Provide a brief discussion of the major adverse trends noted in the area of inspectiort for the last year of matrix data)
Have discussed this with SRI and will have further discussions when arnve at the site
)
1 PPR
SUMMARY
REVIEW: (Review the last PPR summary or SALP and note any trends or recommendations)
St. Lucie-Salp 1. The licensee has declined in performance during this PPR period due to problems with configuration management and a failure to identify an USO.
IPE IMPORTANT SYSTEMS:
TBD PROJECTS BRANCH CHIEF / SENIOR RESIDENT PERSPECTIVE: (Include any request for inspections / review of certain issues)
Inspector discussed with SRI and this was also discussed at the PPR meeting on Wednesday October 2,1996.
OUTSTANDING ITEMS TO BE REVIEWED:
Prior to beginning this inspection, review status of DRS open items and add any to this inspection as needed.
None will concentrate on the Linear Nis.
LODGING DURING INSPECTION: Motel: Holiday Inn-Jensen Beach (407) 225-3000
l Licensee
Contact:
Chris Wasik IN CHARGE OF EXIT INTERVIEW: J. York BRANCH CHIEF'S INSTRUCTIONS:
f APPROVING BRANCH CHIEF:
Date:
Date Subrnitted to Branch Chief:
Date Projects informed:
Date PIen Provided to Projects:
Distribution (After Branch Chief approval):
Approving Branch Chiefs: C. Casto, P. Fredrickson, K. Landis j
Inspectors: J. York, C. Rapp Project Branch Chief: K. Landis Project Engineer: E. Lea j
Senior Resident inspector M. Miller 4
Original To Branch / Division Files: Division of Reactor Safety 1
J
INSPECTION PLAN me.
...acu,touo;enst -, wor,,nse on, Inspection of: St. Lucie on 10/21 - 10/25/96 f 4Cllity of Licen5ee Dates
.Tvae of Insoection:
Ro6 tine / Announced /Norinal Shift Submitted by:
L. Stratton Accomoanvina Personnel: N/A Outstandina Items Reviewed and the Followino Selected for Insoection
( X ) Previous enforcement matters. OIL No.96-016. Failure to Reoort Event to NRC
( X ) Previous open items.
OIL No.
IFI 96-010. FFD Reoraanization and Corrective Action
(
) Bulletins or Noti-es.
OIL No.
( X ) Nonroutine licensee reports. OIL No.
LER 96-276. Tamoerina with Key Switches Date Submitted to Section Chief-10/17/96 Date Prolects Informed:
10/17/96 Date Provided to Pro 1ects:
10/17/96 EIEUI '
m,.n m.a,.... c, %,e,.s.,,,, ee, ~.,,,, e
.s s, -1, miet,- smes.
-m 81502 Fitness for Duty to close Alleaation RIl-96-A-0191 and IFT 96-010 81700 Physical Security Proaram for Power Reactors Trainino and Qualification Protected and Vital Area Access Controls (LER 96-276)
Corrective Actions / Audits l
Instructions by Section Chief:
/)
n
/0/n/9 6 Approved by:
5ection Ch ef bate I ocation Durino Insoection Hotel or Motel: Holiday Inn (10/21) Marriott Courtyard Telephone: 407/229-1000.225-3000 Licensee
Contact:
Bill White Telephone: 407/468-4176 Distribution:
Report Nos.
96-19 Inspector's Branch Chief:
P. Fredrickson Project Section Chief:
K. Landis Project Engineer:
S. Ninh Original to Branch File
INSPECTION PLAN m:0c A cm m mucers r.o was er mPcCnour
. Inspection of: Turkey Point on January 13-17. 1996 Facility or Licensee (Detas)
Tvoe of Insoection:
Special/Rdst{riii/Arinosn5Ed/L'nannounced/Back Shift!6 Submitted By: G. Hopper Accomoanvina Personnel:
P. Steiner Outstanding Items Reviewed and the Following Selected for Inspection (DELETE AND INITIAL THOSE NOT APPLICA8L1)
(
) Previous enforcaent matters. OIL No.
(
-) Previous open items.
OIL No.
1
(
) Bulletins or Notices; OIL No.
(L
) Non routine licensee reports. -OIL No.
Oate Submitted to Branch Chief:
12/18/96 Date Pro 1ects Informed:
10/1/96 Date Provided to Prolects:
12/19/96 Che (Optionau inspection Area or Module insper*or Coments or Cacletion Status (cotional) 71001 Licensed 00erator Reaualification Proaram Evaluation i
I i
i instructions by Branch Chief-s
.Acoroved By:
/ #/f 0 dreIENChieO
'Date 4
In charge of. Exit Interview:
G. Hopper 4
Location Durina Insoection Hotel or Motel:
hs' uproA/ wu Telephone: 305-p y7 PP33 Licensee
Contact:
Glen B'linde Telephone: 305-246-6976 D11Lribution:
Reoort Nos -
50-250/97-01
-Approving OLHPB Chief:
T. A. Peebles 50-251/97-01
~1nspector(s):
P. Steiner Project Branch Chief:
C. Julian i
Project Engineer:
S. Ninh B. Michael. DRS (2 cy)-
Branch' Secretary-(orig)
G:\\0LFORMs\\lNsPPLAN.FRM - 9/13/96
I li l
H:
PUW1' SUPPORT BRANCH INSPECTION PLAN Inspection of: E ~ fJlC 8-Inspection Dates: 16-7-Moto IO -(M(o M!A Report Neber: 9
--((
End Date of Integrated Report:
- E Feeder Report Due Date MIA I
Type of Inspection: Plant S ort (Health PhysicsgErgency Preparoonend i
ounce Unannounced)(Core /Regionai imuativeQptc181)
IP'i or TI f:
f2~)C[
P1anned Inspection Hours:
IRO Hours Completed to Date.
g Percent Compi After Insp:
,bb Accompanying: D,d'I. N M Inspector (s): Lead:
l w
s Inspection Objectives:
(Inspection Procedures used as Guidance.
Provide i
brief write-up on objectives of inspection.
Consider including reliability of l
rad monitors, spare parts availability, laid-up rad waste systems, humidistat j
. testing, and other recent plant issues.)
. i Dth 11" h pr9rth Wi$
dYldeMIP M as w h UeM /[ ca I id I
a u
/
- Reminder - Obtain Performance Indicator Data ********
Outstanding Items To Be Reviewed:
k l
Outstanding items NOT Being Reviewed:
,9 Allegations To Be reviewed: (lise es only) d "N -A - O/f0 d'
j i Projects Branch Chief / Senior Resident Perspective:
(Identify any request for inspections / review of certain issues)
A//A-I' Requirements To Inspect Against:
(i.e., TS, FSAR, 10 CFR procedure: source of information - project engineers have TS, FSARs are in room 3126B, and the Examiners library has most' licensee administrative procedures,)
TG PSh2_
L 0 CDR Pd50.
Fu,an u v Pi n i
i J
j rev. 5/96
V f eeM.%o A
y Au T
INSPECTION PLAN INSPECTION Or.
ST Lucie 1 & 2 INSPECTION DATES:
August 19-23, 1996 REPORT NUNBERS:
50-335,389/96-14 TYPE OF INSPECTION: Maintenance Implementation (62700)
INSPECTOR:
Jim Coley INSPECTION OBJECTIVES:
To perform aD in-depth review of licensee i
maintenance activities INSPECTION REQUIRENENTS:
Preplaning review of maintenance documents, TS, FSARs, PPR, SALP Reports, and Plant Status Report for this inspection will be performed week of August 12-16, 1996.
ANALYSIS OF SITE NATRIX:
Matrix will be reviewed b'efore inspection is performed as part of the preplaning review detailed above.
'IPE INPORTANT SYSTENS:
High Pressure Safety Injection, Emergency Power Systems, and Component Cooling Water Senior Resident Perspective: The SRI wants me to look at the process the licensee uses to determine post maintenance testing requirements on components.
Outstanding Items:
None, However, I will followup on the licensee process for determining the effectiveness of one,ided reactor vessel examinations performed during last outage and based on EPRI's non-representative PDI qualification mockup effort.
In Charge of Exit Interview: Senior Resident Inspector (End of Nonth) Briefing with management at end of this inspection - Jim Coley Motel: Holiday Inn Jensen Beach Fl. Phone No. 407-225-3000 Branch Chief's Instructions: None to da f;<
&A i
Approving tranch Chief: P. Fredrickson v
m.__
Date Submitted to Branch Chief: 8-6-96 Date Projects Informed: 8-6-96 Date Plan Provided to Projects: 8-6-96
[
]
copies Provided:
Maintenance Branch Chief:. David Verrelli, 8-6-96 Project Branch Chief: M 8-6-96
.4 i
Project Engineer: E. Lea, 8-6-96 Copy to: Maintenance Branch File, 8-6-96 Original to : Special Inspection Branch
'f.
i a
4 h
a i
^
4 a
f
-.s
,e
- h. M I
IN S PECTIO N PLAN g,....
...,.i..,u. -. m.,. i,...n%
Inspection of:
St. Lucie on 06/05 - 08/tB198 Facility.r Licensee Date.
ln5osction Tvoe:
spect.1/nout i n./Announe.d/unann.unceo/s.ex shi f t/ Normal Shi f t
' Submitted by: Curt Rapp Accompanyina Personnel: None Outstanding Items Reviewed and the Following Selected for Inspection ios..eno m in.na m ew.
(-
) Previous enforcement matters. OIL No.
(
-) Previous open items. OIL No.
(
) Bulletins or Notices. OIL No.
(
) Non routine licensee reports. OIL No.
Date Submitted to Section Chief:
08/1/96 Date Projects Informed:
8/1/96 Date Provided to Projects:
8/1/96 Current %
Campiete IOpteonell inspection Area or Module inspector Commente or Completion Statue iopuonen IP 61702 Core Power Distribution Limits IP 61705 Calibration of NIs (includes incore-excore x-calibration)
IP 61710 Control Rod Worth Measurements instructions by Branch Chief:
l 2/3 L Approved by:
h ihrench Chief)
Date In charge of Exit Interview: Kerry Landis Location Durina Inspection i
Hotel or Motel: -Holiday Inn Oceanside Telephone:
407-225-3000 Licensee
Contact:
Telephone:
Distribution:
Report Nos.-
i Approving Branch Chief: P. E. Fredrickson Inspectors: Curt Rapp Project Section Chief:
K. Landis j
Project Engineer:
E. Lea
)
Others:
H.A. Turner (TSS) l Original to Branch File:
r-.
% btiN f en b'Oh3[,
R^.
K. bud;.s abu Kc Q g h [e 1
4 Mw INSPECTION PLAN g m u] W O
E ',,
INSPECTION OF:
ST Lucie 1 & 2 INSPECTION DATES:
August 19-23, 1996 f
REPORT NUN 8ERS:
50-335,389/96-14 TYPE OF INSPECTION: Maintenance Implementation (62700)
INSPECTOR:
Jim Coley INSPECTION OBJECTIVES:
To perform ap in-depth review of licensee maintenance ~ activities INSPECTION REQUIREMENTS:
Preplaning review of maintenance documents, TS, FSARs, PPR, SALP Reports, and Plant Status Report for this inspection will be performed week of August 12-16, 1996.
ANALYSIS OF SITE NATRIX:
Matrix will be reviewed before inspection is performed as part of the preplaning review detailed above.
IPE IMPORTANT SYSTEhS:
High Pressure Safety Injection, Emergency Power Systems, and Component Cooling Water Senior Resident Perspective: The SRI wants me to look at the process the licensee uses to determine post maintenance testing requirements on components.
Outstanding Items:
flone, However, I will followup on the licensee process for determining the effectiveness of one-sided reactor vessel examinations performed i
during last outage and based en EPRI's non-representative PDI qualification mockup effort.
In Charge of Exit Interview; Senior Resident Inspector (End of Month) Briefing with management at end of this inspection - Jim Coley Motel: Holiday Inn Jensen Beach Fl. Phone No. 407-225-3000 Branch Chief's Instructions: None to da i
Approving Branch Chief: P. Fredrickson C
+
Date Submitted to Branch Chief: 8-6-96 Date Projects Informed: 8-6-96
~~
~
~'
Date Plan Provided to Projects: 8-6-96
i l
Li ii L
Copies Provided:
Maintenance Branch Chief: David Verrelli, 8-6-96 Project Branch Chief: K. Landis, 8-6-96 4
Project Engineer: E. Lea, 8-6-96 Copy to: Maintenance Branch File, 8-6-96 i
Original to : Special Inspection Branch i
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1 (Frerado e copy to Frejeste two weeks basere '
)
4 Inspection of:. ST. L-4==
on 9/p-13/96 re.aty or u eas maes>
- Type Inspection: Special Routine Asmasunced Unannounced Back Shift NorumalBildt o* es
. swr >
Submitted by: G.Ilonner Acu=anaavine Personnel:
Outstanding Items Reviewed and the Following Selected for Inspection menu e.d wde nes.
e,,6.aw,
( ) Previous enforcement matters. OIL No.
( ) Previous open items. OIL No.
( ) Bulletins or Notices. OIL No.
( ) Non routine licensee reports. OIL No.
Date Submitted to Section Chief; 8/29/%
JJate Projects Informed:
8/29/%
Date Provided to Projects; 8/29/96 Current %
l c.a m
\\
(OrdemaD lesperden Ares er Modulo lasporter Ardvity Name/ Comments or Ceampiades Status 92700 Onsite Followuo of Events 71715 Control Room Plant Observation Insitudi9as by Section Chief:
i Approved by:
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In charge of Exit Interview: G. Ilopper Location Durine Inspection Licensee Contact / Jeff Spodick Ilotel: Jamily residence Telephone: M7-468-4265 -
Distribution:
E_eport Nos.: 56-335/ % 15 Approving Branch Chief: T. Peebles 3-389/%15 Project Section Chief:K. Landis j
Project Engineer:F. LEA Others:
Original to Branch File:
The following information will be entered into MIPS by Admin staff (Shaded area is for Admin use only):
A Plant Mity Type Tarse Duration tmd Team AmMrr t.%
/
Date Employee Sise ID M
/
1 CURRENT CHANGE TO:
W TIE: "CF %NG ; TU:" information should be completed for any changes in inspectapa/ examination pinas. T.,._; provide copy to admin staff for update.
e 1
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i Inspection Plan INSPECTION Of: St. Lucie INSPECTION DATES: November 27-30 and December 1,1995 TYPE OF INSPECTION: Routine Announced Normal Shift SU8NITTED BY: William P. Kleinsorge l
OUTSTANDING ITEMS TO BE REVIEWED:
URI 94-08-03:
Quality Level of PORV and SRV Piping VIO 94-10-01 Failure To Meet Weld Prep Dimensional Tolerances on INSPECTION: Core maintenance and surveillance modules (61726 and 62703).
MC 61726: To ascertain, by direct observation of licensee activi-ties, whether surveillance of safety significant systems and components are being conducted in accordance with technical specifications (TS) and other requirements.To ascertain, by direct observation of licensee activities, whether surveillance of safety significant systems and components are being conducted in accordance with technical specifications (TS) and other require-ments.
MC 62703: To verify that maintenance activities for safety-significant structures, systems, and components (SSCs) are being conducted in a manner which results in reliable safe operation of the plant and plant equipment.
The senior resident inspector (R. Prevatte) requested that areas to examine should include:
review of the results of the last i
Steam Generator (S/G) eddy current examinations; Installation of S/G hot leg flow nozzles; and repairs to the pressurizer.
LODGING DURING INSPECTION: Holiday Inn Jenson Beach FL (407) 225-3000 SITE CONTACT:
Resident Inspector (407) 464-7822 IN CHARGE OF EXIT INTERVIEW: William P. Kleinsorge REPORT NUMBERS: Resident Inspector Report BRANCH CHIEF'S INSTRUCTIONS g4 Q&%
2
. O. Christensen Approving Branch Chief Date Submitted to Section Chief: November 7, 1995 Date Projects Infoimed: November 7, 1995 Date Plan Provided To Projects:
November 7, 1995 Approving Branch Chief:
H.0. Christensen Projects Branch Chief: K. Landis Project Engineer:
Inspectors:
W. P. Kleinsorge Original To Branch Files: Maintenance Branch
i i
}NSPECTIONPl.AN Previos nooroveo copy to Projects one ween cefore
.nsoection:
~~';oect un ni:
__h.
( tr c. t {
in ld ' 20 Oc7 5 Datap.-
x
- Fac1 ity or
- -*=<a
'De of. 'nsnection:
icecia ouncegUnannounceg/BicKShif oM iubmittaa by:
- 4idaccompanying Personnel i
Outstandina Ita=* Reviewee and the followina Selected for insnection 1 Delete and initial those not appitcaele) j Previous enforcement : natters. OIL No.
(
) Previous open items. OIL No.
t
) Bulletins or Notices. OIL No.
i
) Nonroutine licensee reports. OIL No.
. TMI items.
Jate sunmittaa to section Chief:
/ o - / * - P s' Date 0* elects Informen:
/c
<=-Fe Date elan ecovicea o Gro1ect:::
/o - r e - '/ >"
i Current Comments or Comolete (Optional)
- nspection Area or Module
- nspector Completion Status (Optional)
Ce tf ja > /nn sa ne mi e & ac i e n Wt wrs e un.,w ssasssao.c.(14) rot I
ffv>>
I,+, b LA> wes tv-e
- Module Hrs-Current ai Q
Pl anneo Mrs comoiete j
fY)P 20 fO j
14 p t" 2.o
/0 I
i
- nstructions by Section Chief:
Review TPPR Meeting Minutes
+
g[/v!fs In Charge of b#4J 2 eroveo by:s t'
L-0 (Sect 1on Chief)
(Date)
Exit interview:
.ocation Ourino !nsoection Hotei/ Motal: Sne Wnw
- leonone:
e
.icensee
Contact:
ft. <$ri u oz Telennone:
/ Y o ) ) - V e Y - ) # 4 2-31stribution:
After sect 1on Chief Aoproval) lecort Numoers:
aooroving Section Chief 7 4 DM**f.
f, - 3 s i t' f f " /' f
- nsoectors
/C >" c sw i '
~o-%ff; 9319 s
Project Section Chief NOTE:
Jse cacK of form X L #" d' 5 if nore : pace neeoed Dreject Engineer s', c of 3riginal to Branen File t
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INSPECTION PLAN INSPECTION OF St. Lucie INSPECTION DATES: January 29 - February 2, 1996 REPORT NUMBERS:
50-335,389/96-01 TYPE OF INSPECTION: Core:
Surveillance / Maintenance (61726/62703)
INSPECTOR (S) : B. R. Crowley INSPECTION OBJECTIVES:
61726:
To ascertain, by direct observation of licensee activities, whether surveillance of safety significant systems and components are being conducted in accordance with technical specifications (TS) and other requirements.
62703:
To verify that maintenance activities for safety-significant structures, systems, and components (SSCs) are being conducted in a manner which results in reliable safe operation of the plant and plant equipment.
REQUIREMENTS INSPECTING AGAINST:
Observations will be compared with the applicable licensee procedures, Technical Specifications and the Safety Analysis Report.
Technical Specification 4.0 covers surveillance requirements.
Section 6.8 covers procedures and programs, including requirements for maintenance and surveillance procedures.
Plant Administrative procedure 2-0010125, Revision 50, covers control of work, including Maintenance.
ANALYSIS OF SITE INTEGRATED MATRIX:
Review of St. Lucie Site Issues Matrix for the last year (1995) revealed the following adverse trends related to maintenance: (1) 9 cases of equipment failure - 3 of the 9 for EDG equipment, (2) 7 cases of personnel error, and (3) 12 cases of failure to follow procedures, inadequate procedures, or weak procedures.
The EDG problems may indicate a weakness in EDG Maintenance.
The number of problems related to personnel errors and procedure problems Page 1
-dQ,"
O indicate weaknesses, possibly attitude'. problems, in the Maintenance Program.--
IPE IMPORTANT SYSTEMS:-
High Pressure Safety Injection Emergency Power System Component Cooling Water OUTSTAB ING ITEMS T0 BE REVIEWED:
VIO 94-10-10, Failure to Meet Weld Prep Dimensional Tolerances DRP BRANCH CHIEF / SENIOR RESIDENT PERSPECTIVE:0UTSTANDING ITEMS TO REVIEWED:
The Resident Inspector indicated that the following should be evaluated during inspection of maintenance or surveillance activities:
Procedure adherence and adequacy - there have been problems with general procedure compliance and signoffs of steps as they are completed.
Problems with inattention to details PMT - need to verify that PMT is adequate for any maintenance activities
-observed.
Need followup on welding program - previous stop-work order - rod storage and welder qualification.
L00GING DURING INSPECTION: Holiday Inn Express, Fort Pierce, FL - 407-464-5000 (Confirmation # 60877487)
IN CHARGE OF EXIT INTERVIEW: Cro. ley BRANCH CHIEF'S INSTRUCTIONS: f,jk p t
l sz,: u F W h + Q 9 r y 'p4 % &<
h APPROVING BRANCH CHIEF:
O I
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Date Submitted to Branch Chief: January 22, 1995 Date Projects Informed: January, 1995 Date Plan Provide to Projects: January 22, 1995 i
Copies Provided:
Maintenance Branch Chief:
H. O. Christensen Project Branch Chief:
K. Landis Project Engineer:
E. Lea Original To Branch Files: Maintenance Branch Page 2
I j
J NS P ECTION PLAN m. de e ed e.t,y to e,,.e,e f.e.yo,e -
Inspection of: St. Lucie on 4/29 - 5/3/96 Foodsty or ucerwee Dates Routjns/ Announced / Normal;Shjft Tvoe of Inspection':
Submitted by:
L. Stratton Accomoanyino Personnel: N/A Outstandina items Reviewed and the Followina Selected for Inspection
(
) Previous enforcement matters. OIL No.
(
) Previous open items. OIL No.
(
) Bulletins or Notices.
OIL No.
(
-) Nonroutine licensee reports. OIL No.
Date Submitted to Section Chief:
4/16/96 Date Projects informed:
4/16/96 Date Provided to Projects:
4/16/96 Current %
CorrwAete lootinnea leecection Area or Module (se nooropriate. include inspector sessanments. completion status. end'or commente) 2515/127 Access Authorization (one day at FP&L Corporate Office) to closed RIl-96-A-0037.
81700 Physical Security Proaram for Power Reactors to close out LERS 95-S01 and 95-S02
-Testina. Maintenance. Compensatory Measures
-Trainina and Qualifications Records and Reports l
l Instructions by Section Chief:
4 4// ~7/$$
Approved by:
~
Date Section CNet In charge of Exit Interview: L. Stratton Location Durina inspection j
Hotel or Motel: Holiday Inn Telephone: 407-225-3000 j
Licensee
Contact:
Bill White Telephone: 407-468-4176 Distribution:
Report Nos.: 96 08 1
Inspector's Branch Chief:
P. Fredrickson Project Section Chief:
K. Landis Project Engineer:
E. Lea Original to Branch File j
INSPECTION PLAN %.,,..,,.,
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m.
2 /26 - S// /%
Inspection of:
ST -LuctE on F dry or Lac.re.e
/
- 10. [
Type of Inspection:
Special,osjjii/,gid/ Unannounced /Back Shift /
J Submitted by:
Accompanvino Personnel:
Outstanding items Reviewed and the following Selected for Inspection cou. e a.i nw
('
) Previous' enforcement matters. OIL No.
/ IM d!w)
(
) Previous open items. OIL No.
NA 4 /2
(
) Bulletins or Notices. OIL No.
A/4
-#'A D
(
). Non routine licensee reports. OIL No.
N/r M/ ',
Date Submitted to Section Chief:
1/3!#6 Date Pro.iects informed:
2 W / '
Date Provided to Proiects:
I N'* '-
curr.ni s cone.i.
i tooi nmi in
=..n Ar... Mou. w comen.nu cw n simu. a n.nni sue
>~.u,.,n w.,,,,,,.=/,:,
Module
!its,
[urrent Planned Hrs Comolete instructions by Branch Chief: bO t% --1 rk M Z e 9i-/P3r'7 W/8 b 7
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'/
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/ eview TPPR Meeting Minutes Acoroved by:
b (Br.nch Chi.fi D.t.
In charge of Exit Interview:
e We r e, nr location Durino inspection Hotel or Motel:
3e Telephone:
dff/
22f - 3700 Licensee
Contact:
Jn w
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Telephone:
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Distribution:
Pecort Nos.-
~~' - EI/ '
Approving Branch Chief: ( 2pR
. n. 3 M / -
Inspectors: F. W RtG - r
/
Project Branch Chief: x. WW Project Engineer:
E.
EA Original to Branch File:
S:\\DRS\\lNSPLAN.SHD - 10/20/95
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'orevida a brief star===nr of the safetv 21eerive of this inanactient 1
i
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Deviatinne.
Unresolved Ita==.
TFT'8-strenerha & Womenmeman. ochment a r2 i
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_ns' ecterdsnBranch: Chief Station:. Chief: Date p
nspecr=rf.anDisr:tzion-Direeter Prcjecc:Section: Chief /fptm.s.
. Repen 1 **'+=trator
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N INSPECTION PLAN INSPECTION OF:
ST Lucie 1 & 2 INSPECTION DATES:
May 6-9 St. Lucie, May loth EPRI and May 13-17, 1996 REPORT NUMBERS:
50-335, 96-06 For inspection performed on May 6-9 50-335, 96-To Be Announced May 13-17, 1996 TYPE OF INSPECTION: Core (Maintenance and Surveillance) May 6-9, 1996 May 10, 1996 EPRI Review of Southwest Research Institute Qualification Data for St Lucie Reactor Vessel Inspection May 13-17, 1996 Core (Inservice Inspection of Reactor vessel.
INSPECTOR:
J. L. Coley IMSPECTION OBJECTIVES:
To evaluate the effectiveness of the licensee's maintenance and surveillance activities and to examine Automated Ultrasonic Examination of Reactor Vessel plus other ISI activities.
INSPECTION REQUIREMENTS:
Preplaning review of maintenance documents, TS, FSARs, PPR, SALP Reports, and Plant Status Report for this inspection will be performed May 2-3, 1996.
ANALYSIS OF SITE MATRIX:
Matrix will be reviewed before inspection is performed as part of the preplaning review detailed above.
IPE IMPORTANT SYSTEMS:
High Pressure Safety Injection, Emergency Power Systems, and Component Cooling Water Senior Resident Perspective: The senior resident inspector stated that he would like me to focus on the visual Re&ctor Vessel internals examination, Steam Generator eddy current examinations, and the Reactor Vessel 10-Year automated ultrasonic examinations Outstanding Items:
Unresolved Item No. 335/94-008-03, Quality Level of PORV and SRV Discharge Piping Lodging During Inspection: Holiday Inn 9 Jensen Beach 407-225-3000 Lodging At EPRI : Hampton Inn, Charlotte (Unversity Place) 704-548-0905 In Charge of Exit Interview: Senior Resident Inspector (End of Month) Briefing with management at end of this inspection - J. L. Coley Branch Chief's Instructions: None to dat Approving Branch Chief: D. Verrelli Nld
o-
- p,
1 2
Date Submitted to Branch Chief: 4-17-96 Date Projects Informed: 4-17-96 3
r Date Plan Provided to Projects: 4-17-96 Copies Provided:
~4 Maintenance Branch Chief: Chris Christensen, 4-17-96 Project Branch Chief: K. Landis, 4-17-96 Project Engineer: E. Lea, 4-17-96 1
Original to Branch Files: Special Inspection Branch l
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~
[' PEANT SUPP0KFBRANCH INSPECTION PUWi~ (P' age 2)'
- 7 Plant Issuesal$st
- Noview:
(Consult the. Assigned Inspector, trie PIL, and- '_Er provide a br;.f discussion of the major adverse trends noted in the area.or inspection for tha last year of data)
CvsMu.- e "* r emer/c f,W PLM rouan MALBA.$ ~ mhDEDM*CY 0 h nudf 2 hWUX]
fPA SeGM.s F na t3 kWE-N'T/BJ
- T5 MMArw -
PPR Stamary reviews (Consult the Assigned Inspector, review the last PPR summary or SALP and note any trends or recoassendations.
Identify where these-are f tore {Me into your inspection.) GIL bcLGAnM5 AL Ssoumh
-3 IPE Important Systems:
(List the top three or four systems; if licensee is working on any of these systems while you are on-site and high radiation or high contamination levels exist for the work, you may want to inspect this activity.)O - S. -J %<i+ A A-efu, m Lodging During Inspection: _ iud /M R/vE4 Phone No. 4D7 77(-89d9 Address wgassw Ersca Site
Contact:
- pt L e M o+A)
Phone No. 401 4/8-4/f/
In Charge of Exit Interview:
F Ll a c s -r Branch Chief's Instructions:
Oh m/e_-- 1 4 a/*
V Approval:
M Date:
PS WanWChief Date Submitted to PS Branch Chief:
4 Date Projects Informed:
Date Plan Provided to Projects:
)
i Copies Provided To:
Projects Branch Chief K, L A NDIS Projects Engineer E, Lc4 Plant Support Branch Chief t BA M.
Original: To Plant Support Branch Files rev. 5/96
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{fE Inspection.ofk dW4E
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Report f. dk
'..'.t o u ntEhd,Dhte of, Integrated: Report:
So 35 jg g +...._...
c.,.',,
Jiheder Report Due: Dhte:
,Fim,/ M" g
- - - -,,. _. n...
e Type of InspEddf1dth, "** 1"a% Health ~ PNyshrgency Preparedness, r
~~'"
nounc narinounceant. ore / Regional Initiative /
e' a c
- vtawr IP'h on TL f:
93kD r
Planned Inspection Hours:
Hours Completed.to Date:
-e-Percent Compi After Insp:
+
- Q A t L Q k 537Tb at t PW y, Inspector (s): Lead:
4 I J R l lr H 1' Accompanying:
A)h M 1
I Inspection Objectives:
(Inspection Procedures used as Guidance.
Provide brief write-up on objectives of inspection. Consider including reliability of rad monitors, spare parts availability, laid-up rad waste systems, humidistat testing, and other recent plant issues.)
OuaPH/wAL RAo iA -r/or> L'pMans frLLEM170/)
P Ft/1 filc-.
- Reminder - Obtain Performance Indicator Data ********
Outstanding Items To Be Reviewed:
hp Outstanding Items NOT Being Reviewed:
A> A Allegations To Be reviewed: (Use #s only) Tf- / T3
% - D 60 / %- o T4 i
!4 i
l Projects Branch Chief / Senior Resident Perspective:
(Identify any request for inspections / review of certain issues) i rome oMuynom o r
%R 4 Con %m r e h)Tt-C s l
Requirements To Inspect Against:
(i.e., TS, FSAR, 10 CFR procedure; source of information - project engineers have TS, FSARs are in room 3126B, and the Examiners library has most licensee administrative procedures)
' 7'S.
k.A UA)rr s 7Aff n u Av cu rio/>s tM1 / AAK -L \\ -l * ?Y % l> Y srfrL*M A ?s"
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e 20.flof ALAAA o D R PA KT c~.
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INSPECTION PLAN Inspection oft
- 9. Lu I e_e m av i3 -I'7.I M d Inspection Dates:
Ro 7!'4 R 794 / o rn o9 Report Numbers:
Type of Inspections Ewm,L,a rbb$rwiAAn /A< Fo.G9)
G
(\\
/
/
4 l k-c d P1anned Inspection Hours:
s M.YoYb inspector (s):
e vs ever h o u g [,'Ytf g
y bjectives:
Inspebcion w C m un R Al% & dcq nwkWhv. h adL
(<'omw A'seunf orts ~ h n AT+bk L6J -s newt./-/,cd / noe / 6 bn.o f-M s ea t\\R
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f.Ac.en S e4 D-ree o WL Inspection ogsinst:
Vn G4)O Ryuiremente % wun I.u.a.hyg... %nd Th. %e o A rI &
.n M
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-T%l w c OR. :=_zM,tsa / _TTsoept, m plxu i t 1,' [ [ n n hope oNN T 11 Pu SiteIntegradtiMatbrxReviews
~;
ci who a,
PPR S ary review: $RPI iM8 hikWb hen 'v NFE An vwnn h. hd f u o nW 8,,oi, e v.
.m m.u. me e. w l, '
(
m f w 1_k_ d e tevw,ded e d./ Ee [ecI IPE I rtant Systems:
50 9'
=........
,Wtrk6hbNvF.
Projects Branch Chief / eni e sident Pers active:
wry 1ii4MLe
> M moc t'su-tv=1dnbes4.t?7$ NL'\\ nv \\. t c> A tmpOv'rt<t. ir dce w on b6(/6- 'T M' c rdx 1[t i mon Outstandin sT Be eo ~ l / T,bg -( --h'A}A 1.odging During Inspection: i d a y b a vi -.j. o ucow hM d'7 bD ..b. Y Y (_- in Charge Of Exit Interview: / Branch Chief's Instructions: / -l // /( / L. I i //W L '* v IA*d ITW4GC em inA T w f eur int 7rnu jw,q i* Wage:TO 966I-20-SO 3 ta'a wu. r . r-g_m v PREDECISIONAL INFORMATION
- INSPECTION PLAN FOR ST. LUCIE MAY 13-17, 1996 Inspectors: J. York Report Nos.: 50 335. 389/96 09 Inspection Plan:
-Discuss previous inspections in this area (C. Smith, SRI. etc) Discuss w1th 01 -Discuss results of employee concerrs inspection (:/22 tc 5/03) -Select a sample of 10 50.59s -Review Oversight Grcups action on these samples Review licensee procedure for safety evaluations with licensee and discuss program -Review any audits in this area -Sample several modifications where 50.59 process used L ,-o.. tros,ee a vne v m cu, ouvnew s w e .a. ux* tn or,AT-m-cn c.02-1996 18221#1 N ~ kI1 - #" ~' Approving Branch Chief: Date Submitted to Branch Chief: G2A% ~~ Date Projects Informed: 'Date Plan Provided to Frojects: Copies Provided: f e Maintenance tranch Chie $, 4 A a / 4 Projects tranch Chief: Projects Engineer: Original To Branch Files: \\ 1 D e 9e f LL M'd IT9u.SE P08 TOO i MdSNI LN3GIS3d AddnS h (MP:TO 966T-20-SO 4 ~ INSPECTION PLAN INSPECTION OF: St. Lucie with two days at Turkey Point INSPECTION DATES: June 17-28, 1996 with June 24-25 at Turkey Point REPORT NUNBER: 50-335, 389/96-09 will get later for Turkey Pt. (Resident Inspector Integrated Report) TYPE OF INSPECTION: Engineering Module 37550 with-emphasis on safety evaluations (50.59) PLANNED INSPECTION HOURS: Approximately 75 hours8.680556e-4 days <br />0.0208 hours <br />1.240079e-4 weeks <br />2.85375e-5 months <br /> INSPECTORS: J. York INSPECTION OBJECTIVES: (Inspection Procedures used as Guidance. Provide brief write-up on objective of inspection) At Turkey Pt. and at St. Lucie try to determine the effect of downsizing: -Review engineering backlog, average life of items, capital cutback of projects -Determine any change in engineering support to operations and maintenance.(planned or already in effect) -Review any areas in self assessment that has been or will be affected by downsizing -Open IFI for periodic followup of these areas. At St. Lucie only: -Continue to assess the quality and basis for 50.59 safety assessments that was started the week of May 13-17, 1996. REQUIREMENTS INSPECTING AGAINST: I N - s Observations will be compared for compliance with applicable licensee procedures, Technical Specifications, and the Updated FSAR. SITE INTEGRATION MATRIX REVIEW: (Provide a brief discussion of the major _ adverse trends noted in the area of inspection for the last year of matrix data) Will go over with SRIs when arrive at the sites. PPR
SUMMARY
REVIEW:
(Review the last PPR summary or SALP and note any trends or recommendations) negative St. Lucie-Salp 1.
Nothing negative in this area in PPR.
Only
. trend in configuration management.
Turkey Pt.-TBD later.
1 IPE IMPORTANT SYSTEMS:
TBD PROJECTS BRANCH CHIEF /SI"dIOR RESIDENT PERSPECTIVE:
(Include any request for inspections / review of certain issues)
St. Lucie-SRI said in a few cases for safety evaluations licensee may have used engineering judgement when supportive calculations would have been better.
OUTSTANDING ITEMS TO BE REVIEWED:
Prior to beginning this inspection, review status of DRS open items and add any to this inspection as needed.
LODGING DURING INSPECTION:
Motel:
Holiday Inn-Jensen Beach (407) 225-3000, TBD at Turkey Pt.
Licensee Contact Chris Wasik IN CHARGE OF EXIT INTERVIEW:
J. York 4..
o
BRANCE CHIEF'S INSTRUCTIONS:
APPROVING BRANCE CHIEF:
Date:
Date Substitted to Branch efk
[
l Date Projects Informed:
Date Plan Provided to Projects:
Distribution (After Branch Chief approval):
Approving Branch Chief:
C. Casto Inspectors:
J. York Project Branch Chief:
K.
Landis Project Engineer:
L..Mellon Senior Resident Inspector:
M. Miller, T. Johnson Original To Branch / Division Files:
Division of Reactor Safety g
9...
3
INSPECTION PLAN INSPECTION OF:
St. Lucie INSPECTION DATES:
July 22-26, 1996 REPORT NUMBER:
50-335, 389/96-11 (Resident Inspector Integrated Report)
TYPE OF INSPECTION:
Engineering (Core Inspection) Module 37550 PLANNED INSPECTION HOURS:
Approximately 40 hours4.62963e-4 days <br />0.0111 hours <br />6.613757e-5 weeks <br />1.522e-5 months <br /> INSPECTORS:
J.
York INSPECTION OBJECTIVES:
(Inspection Procedures used as Guidance.
Provide brief write-up on objective of inspection) 1.
Review adequacy of the licensee's FSAR review.
- 2. Review a sample of 50.59s generated to address these discrepancies.
3.
Review corrective actions in relation to FSAR items.
REQUIREMENTS INSPECTING AGAINST:
Observations will be compared for compliance with applicable licensee procedures, Technical Specifications, and the Updated FSAR.
SITE INTEGRATION MATRIX REVIEW:
(Provide a brief discussion of the major adverse trends noted in the area of inspection for the last year of matrix data)
)
Will discuss with SRI when arrive at the site.
{
SUMMARY
REVIEW:
(Review the last PPR summary or SALP and note any trends or recommendations)
St. Lucie-Salp 1.
Nothing negative in the PPR.
Only negative trend in configuration management.
IPE IMPORTANT SYSTEMS:
TBD PROJECTS BRANCH CHIEF / SENIOR RESIDENT PERSPECTIVE:
(Include any request for inspections / review of certain issues)
SRI st'ated that he had opened two URIs in this area, one for items identified by the RIs and the other for items identified by the licensee.
OUTSTANDING ITEMS TO BE REVIEWED:
l t
\\
i 1
Prior to beginning this inspection, review status of DRS open items and add any to this inspection as needed.
Two URI pened by the SRI in the area of the FSAR.
'l LODGING DURING INSPECTION:
Motel:
Holiday Inn-Jensen Beach (407) 225-3000 j
Licensee
Contact:
Chris Wasik IN CHARGE OF EXIT INTERVIEW:
J.
York BRANCH CHIEF'S INSTRUCTIONS:
j 7 ~ ##~ Id APPROVING BRANCH C IEF:
k k
Date:
6 Date Submitted to Branch Chief:
Date Projects Informed:
Date Plan Provided to Projects:
Distribution (Af ter Branch Chief approval) :
Approving Branch Chief:
C. Casto Inspectors:
J.
York Project Branch Chief:
M Project Engineer:
E.
Lea Senior Resident Inspector:
M. Miller Original To Branch / Division Files:
Division of Reactor Safety i
i j
l 1
t I
l I
imma m iOM P m (PER ROI 2211 REV. 41 f
i (Provide pprove copy to Projects two weeks before Inspection)
'}
- 7" b[
l wspection of:
on j
(Facility or Licensep4-.
(Dates)
Vype of Inspection: Specia Normal Shift j
Submitted by:
\\
Accomoanying Personnel:
]
Qutstanding items Reviewed and the Following Selyted for Inspection (Delete ano initial those not applicaole) l
(
) Previous enforcement matters.
O!L No.
1
(
) Previous open items. OIL No.
}
(
) Bulletins or Notices. OIL No.
l
(
) Nonroutine licensee reports.
OIL No.
l l
1
(
) TMl items.
l Date Submitted to Section Chief:
3 [?o 1
l Date Pro.1ects Inforsee:
3/2e j
Date Plan Provided to Pro.1ects:
9/9 b rent :
W mpl ete Casaments or j
(Optional)
Insoection Area or Module Inspected Completion Status (Optional) 4 I
j V
m ss e J f6 s s
6 i j
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4 Instructions by 5ection chief: 4nua nm ;
}
/
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/
~n i
l Approved byPOV %M 3/4 W '73 In Charge of (5ection catef)
(cate)
Exit Interview:
1 Location During Inspection Hote1/ Motel:
Telephone:
Licensee contact:
Telephone:
stribution: (After section chief Approval)
Report Museers:
roving ection Chief 9 ee g j
spectors Aeject Section Chief NOTE: Use back of Project Engineer Form if more Original to Branch File space needed.
Form RII.T28
p.
L
' INSPECTION PLAN (Provide approved copy to Projects two weeks before Inspection)
Inspection of:
on
// /-5!98 (Facility or Licensee)
/ (Date/)
4 Type of Inspection: Special/ Routine / Announced / Unannounced /Back Shift / Normal Shift
~i Submitted by: h.
' Accompanying Personnel: M. Thoma r H* W h i
Outstanding items Reviewed and the Following Selected for Inspection J
(Delete and initial those not applicable) 4
(
) Previous enforcement matters.
0!L No.
)
(~
)' Previous open items. 0!L No.
~
i
(
) Sulletins or Notices. OIL No.
]
l'
(
) Nonroutine licensee reports.
OIL No.
1-
};
.(:
) TMI items.
. 1 Date Submitted to Section Chief:
/0!A7 1_3 Date Projects Informed:
/o-/q.c7A' Date Plan Provided to Projects:
/, - A g - 9.3 i
l i
Current 1 l
- caplete Comments or j.
Optional)
Inspection Area or Module Inspector Completion Status (0ptional) l i; l' i
Instructions by Section chief:
f nN
.i'
- Imnw, Approved by:
L -
Weh
/ (// ct//J In Charge of
. (5ectiorr ght ef)
~f (Datea)
Exit Interview:
Location During Inspection Hotel / Motel:el. h s w P M A Telephone:fy o7) 2 25-3 700 Licensee contact: h A Lt. h Telephone: 7407) yt,R-4214
~
- Distribution: (After SectiorVChief Appp4 val)
Report Numbers:
Approving Section Chief C.dd 50 335/9g-og Inspectors Why b L4/M So-.SW/qq 55 y
l coject Section Chief M NOTE: Use back of
/
roject Engineer Je. h Form if more Original to Branch File space needed.
Branch Chief -(ES)
Form Ril-T28 i
-Turner (TSS).
.w-
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.,v w
f INSPECTION PLAN FOR ENGINEERING AND TECHNICAL SUPPORT FACILITY: ST. LUCIE REPORT NO. 50-335,389/93-25 INSPECTION DATES: NOVEMBER I-5, 1993 INSPECTORS: M. THOMAS, H. WHITENER, G. WISEMAN (LEAD)
PREREQUISITE:-
(I) PROJECTS HAS NOTIFIED LICENSEE OF THE INTENDED INSPECTION
-(2) INSPECTORS HAVE REVIEWED THIS PLAN AND HAVE REVIEWED IP 37500 AND IP 37700
.(3) INSPECTORS HAVE REVIEWED SALP INPUT FOR THE ENGINEERING AREA AND HAVE REVIEWED'THE ASSOCIATED INSPECTION REPORTS AND DRS ASSESSMENT BOOK j
OBJECTIVES:
-(I) TO EVALUATE THE LICENSEE'S ENGINEERING AND TECHNICAL SUPPORT ACTIVITIES l
'PARTICULARLY WITH RESPECT TO THE EFFECTIVENESS OF THE ENGINEERING ORGANIZATION IN THE PERFORMANCE OF ROUTINE AND REACTIVE SITE ACTIVITIES.
THIS INCLUDES ENGINEERING BACKLOGS.
(2) TO EVALUATE COMMUNICATIONS BETWEEN ENGINEERING AN9 OTHER ORGANIZATIONS SUCH AS MAINTENANCE, OPERATIONS, REGULATORY COMPLIANCE, AND CORPORATE ENGINEERING TO ASSESS THE EFFECTIVENESS AN0' TIMELINESS OF ENGINEERING SUPPORT DURING THE RESOLUTION OF EMERGING DEFICIENT CONDITIONS.
(3) TO EVALUATE INTERFACE AND OVERSIGHT CONTROLS OVER CONTRACT ENGINEERING WHERE APPLICABLE.
NOTE: INSPECTION GUIDANCE NUMBERING RELATES TO OBJECTIVES AB0VE INSPECTION GUIDANCE:
.I.01 Select several safety-related design ch Anges/ modifications for review from those implemented during.the recent refueling outage. Applicable attributes to be examined are described in Attachment I.
I.02 For the above design changes / modifications do the following:
- a. Examine the installed hardware to selectively verify that the installation conforms to the as-built drawings.
- b. Ensure ~ that post modification test procedures verify functional capability of the installed changes. Ensure any PMT changes to existing plant procedures were properly reviewed and approved.
I
l l
t 7
i
- c. Ensure that the licensee's evaluation of completed tests i
addressed test results which did not meet acceptance criteria, i
that. test deviations were resolved ;n consultation with the engineering organization, and that required retesting was accomplished.
.j i
1 1.03 For the above modifications review selected field change requests to verify that appropriate and' timely evaluations have been performed by the design / engineering organization.
2.01:
Identify recent plant nonconformances or deficiencies from the licensee's-condition reports, deviation reports, material nonconformance reports, or other similar' documents which identified problems within the last year. Also review licensee fl event reports, NRC bulletins, generic letters,'information notices, Part 21 notices, Part 50.72 notifications. ' Based ~upon
,the above information, select a sample of issues which required e
engineering involvement.
1 1
-During the above reviews, consider the engineering organization involvment in identifying and. resolving technical issues affecting-the plant.
Beyond the specific issue, a determination should have been made of the extent of the problem, its root cause and actions necessary to prevent recurrence. This should include an assessment of the engineering disposition of deficiencies identified from the Inservice Inspection (ISI) programs and response to operational matters, such as LERs, setpoint changes, or unanticipated system responses either during normal operation or during an event.
The engineering organization support to the maintenance department in the analysis of equipment performance trending data and recommend changes to preventive maintenance schedules resulting from analyses. The engineering ni -
organization identification of post-maintenance testing requirements and acceptance criteria; recommendations for troubleshooting of complex problems; specifications for the procurement of commercial grade parts; ensuring that unauthorized modifications are not performed as maintenance activities without proper review and approval'and maintenance work requests.
Assess the effectiveness of the engineering organization evaluation of external information such as vendor bulletins, safety operational evaluation reports, and NRC generic communications. The engineering groups should maintain records of such evaluations and should perform the evaluations in a timely manner.
Review the degree.of engineering involvement with plant procedure revisions, 10 CFR Part.50.59 and Part 21 evaluations, and Technical Specification or FSAR amendments.
Review the_ licensee's Probabilistic Risk Assessment (PRA),- if one is available, and its use in operational decision making. Assess whether actual equipment outage durations are evaluated with respect to the PRA assumptions forequipment outages.
2.02 Review organizational charts for the site and corporate engineering groups.
Procedures'and programs should be reviewed in
_ _~
l
'^
order to ascertain the licensee's expectations for the engineering
)
i organization. Observe whether the engineering staff. understand and are implementing management's expectations. Review the different engineering organizations and examine the amount of overlap and interface between them.
j L2.03 Determine, if the licensee uses system engineers-(SE), the role of
'l the SE and his/her knowledge of system requirements and plant design basis. SEs should be knowledgeable of the normal and accident ~ functions of their systems, the major components in their systems, and the requirements on those components. The engineers should conduct routine walkdowns of their systems. They should be 1
1 i
involved in all activities.on their systems, including planned maintenance, modifications, or testing. Review the number and j
complexity of the systems assigned to the SE to determine adequate
)
2 distribution of workload.
4 2
2.04 The distribution of engineering responsibilities between site and 4
corporate groups should be reviewed because the location of the engineering support staff away from'the site could affect the staff's familiarity with the plant and level of involvement in resolution of problems.
4 2.05 Evaluate the adequacy of staffing within the engineering organization to accommodate assigned work load through indicators such as: ability to respond to plant needs within required time frame, amount of overtime required,. backlog of work, and number of L
staffing vacancies. Assess the qualifications of engineering y
personnel.
2.06 Assess the adequacy of formal and informal training programs for r
the engineering staff.
In particular, review the adequacy of training provided for personnel authorized to perform 10 CFR 50.59 evaluations. Also assess the training provided to personnel who perform operability determinations and root cause analysis.
3.01 For the SG Replacement (where applicable) and M0V Design d
Calculation Projects, assess the extent and reliance upon contracted engineering organizations. Review the administrative i
controls in place for contractor activities and assess the adequacy, and timeliness, of the engineering follow-up on concerns identified by the licensee's contractors. Determine the degree to
.which the licensee engineering organization monitors the technical i
adequacy and assumes ownership of contractor work products.
ATTACHMENT 1 DESIGN CHANGE / MODIFICATION ATTRIBUTES TO REVIEW l.
Design changes / modifications were properly reviewed and approved by on-site and off-site review organizations, 2.
Appropriate operating procedure and emergency operating procedure changes were identified, and implemented, as part of the modification package.
3.
Appropriate operator training program revisions were identified as part of the modification package.
4.
Prior to each design change / modification being declared operable, the controlled copies of as-built documents used by the plant operators were either revised and distributed, or were legibly marked-up on an interim basis to show all changes relating to the design change / modification (s).
5.
Design changes / modifications selected were supported by a 10 CFR 50.59 safety analysis, and that appropriate FSAR revisions were planned or completed.
The associated 50.59 evaluations should be examined for technical adequacy.
6.
Necessary revisions for preventive maintenance, inservice inspection (ISI),
and inservice test (IST) requirements were appropriately identified as part of the modification package.
7.
For design changes / modifications that are partially completed ensure that the effects of partial completion of the modification were fully considered and the partially completed status was adequately assessed in a safety evaluation.
8.
The review of design change /.T.odification calculations, analysis, and design output documents should ensure that:
l Required technical, design verification, and independent design i
reviews have been performed.
There is technical consistency at design discipline interfaces.
Appropriate design inputs from codes and standards, and from the relevant design criteria are properly identified.
Design inputs are consistent with the plant hardware and configuration.
Calculational and analytical methodology complies with regulatory requirements, licensee design guides and commitments, and industry practices. Calculational assumptions are technically sound.
(? :i :e approved copy to Projects cre weet teio e Inspection)
'N5FECTI:s ;>N i
lnsoection of:
$ 7~
b u e.1 i on f 1 - /4 fue y '9 3 (Facihty or tierns (0ates nnounc
/ Unannounced /Bact shift ormalshp Type of Ins:ectign: };ecialhoutin
$vbmitti,0 ty: K,/T [.A,d,e,c,,I
_ _ _ companying Personne)
NA Outstandinq Items Rev e.ed and the Fo)1owing Selected for Inspection (Delete anc initial t ese not applicable)
(
) Previous enforce ent matters.
OIL No.
(
) Previous open items. O!L No.
(
) Bulletins or Notices. OIL No.
(
) Nonrouttne licensee reports.
Oil No.
(
) TM1 items.
Date Suomitted to Section Chief: 23 ysr
- 9 3 Date Projects Informed:
A3 yz,-<
5 3 Date Plan Provided to Projects: A3 ya, -,- 9 3 Current :
Complete Comments or (Optional) Inspection Area or Module Inspector Completion Status (Optional)
BY M con fa n < w Ecn w rs+ c o ~ ~
B6 ? s v c,er Anw+srr Ngamaw r e 77wis,<,w a 5/h cq Sywl ],ul' ev OtlT IS1 5i ia
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1 Instructions by Section Chief:
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(Date)
Exit Interview: /8 N #a,e location Ouring Inspection Hotel / Hotel: No t, orn TH.fr 'nubewt fi Telephone: /- pop - n,gn Licensee
Contact:
J,,, //ot. r Telepnone: y.,,y_ wf-;ffo Distribution: (Af ter Section Chief Approval)
Report Ni bers:
Approving Section Chief 7. /. dece re j
1nspectors it. t' C,+ditio o 50 - 3 3 f f 93*I>
Project Section Chief t.t.a.us NOTE: Use back,of ro-3pS /
93-17 Project Engineer it. ><s,s Form if more
/
Original to Branch File Space Needed.
Form Ril-T28 P
4 l
9NSPECTION PLAN (Provide approved copy to Projects two weeks before Inspection)
..spection of:
k !lACI8
/d / 'T on VlAME. S/-S b / 09 (Facility or Licensee)
(Dates)
Type of Inspection: Special/_ Routine / Announced / Unannounced /Back Shif_t/ Normal Shift _
Submitted by:
J. l 6 rem Accompanying Personnel: A,$ m/#rf, ff. h/Mj G,7-dMeA;cnselk, Outstanding Items Reviewed and the Following Selected for Insoection (Delete and initial those not applicable)
()jlS) P..,ia ; a ' crc; :-+ ette r.
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Date Submitted to Section Chief:,
5-LF -9 3 Date Projects Informed:
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Date Plan Provided to Projects: -
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/ MDate)
Exit Interview:
reh Location Durino Inspection E/ br-;ov (Wor /,,IrisvE ' e 4, 28 Telephone; f87-T19 -/070 Hotel / Motel:
-Licensee contact:
R, N/,/ gar-Telephone:
-R77-46 5 - ?SSC X3/97 Distribution:
(After Section Chief Approval)-
Report Numoers: -?S, ?@f /9 7- / /o Approving Section Chief
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!nspectors Project Section Chief Project Engineer Original to Branch File Form Ril-T28
INSPECTION PLAN (Provide approved copy to Projects two weeks before Insktten)
~
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!nspection of:
M.
///1-Jf)9d on sracmir.r uc.eniee) toet.o Type of Inspection: SpectaQEcutinRAnnounced/ Unannounced / lock Shift / Normal Shift
'$ubmitted by: /M Accompanytne Personnel: df, 4./Gt Outstandine itses-teviewed and the~ Followine Selected for Inspection l Delete and talttal those not applicable)
(
Previous enforcement matters. 0!L No.
(
revious open items. OIL No.
11etins or Notices. 0!L No.
4
(
N nroutine Itcensee reports. 0!L No.
{
(
TMI items.
Date Submitted to Section Chief:
.h Date Fredects. Infotee68:
4 mees + m-Date rien Provices to Pro.1ects:
Current 1 Complete Cassents or (Ootional)
Inspection Area or Module laspector Completten Status (Ostlemal) 94729 -
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Location Durine Inspection m
Motel /Motei:
MM Telephone: En J229 #r>v' 3
Ltcensee contact: M h#w Telephone: Arct)std,#- Vi?/
Distribution: (After 5ection Chief Approval)
Report ruebers:
Approving 5ection Chief Inspectors MXL at s~ 93-n i
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.3JiY 9_f- /3 Project Section Chief NOTE: Use back of Project Engineer Fors if more Original to Branch File space needed.
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(Dates) l
. Type of Inspection:hl/Routin
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A 'r,v 5_.
i Outstandine items Reviewed and the Followine Selected for Inspection (pelete and initial those not applicable)
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,3/3e>
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In Charge of 95ettlefrChief) 7 I
'(Date)
Exit Interview:
Location Durine Inspection Hotel /Rotal:
Telephone:
Licensee contact:
Telephone:
Distribution: (After section Chief Approval)
Report Numbers:
c77
/ /
growing 5ection Chief
.pectors esject Section Chief-NOTE: Use back of Project Engineer.
Form if more Original to Branch File space needed.
Form Ril-T28
I INSPECTION PLAN (Provide approved copy to Projects two weeks before Inspection)
Lude d!/e._ 2 3 J[Ta_cility or Licensee)
Ir.spection of:
on (Dates)
Type of Insoection: Special e/
Unannounced /Back Shift / h Sh ht..
Submitted by:
dv etj /d V Accernoanying Personnel:
M/4 Outstanding items Reviewed and the Following Selected for Inspection (Delete and initial those not applicable)
(
) Previous enforcement matters. OIL No.
(
) Previous open items. OIL No.
(
) Bulletins or Notices. OIL No.
(
) Nonroutine licensee reports.
OIL No.
.(
) TMI items.
Date Submitted to Section Chief:
419/93 Date Projects Informed:
4 W9/9 g Date Plan Provided to Projects:
_4 //q /9 5 Current 1 Complete Coments or (Optional)
Inspection Area or Module Inspector Completion Status (Optional) 7R75A l
7405/
7 4 0 <L c-G em /
4 Instructions by Section Chief:
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Approved by: *#,%4W"'ML 7/-r&T In Charge of j
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(Uate)
Exit Interview: No tJ// V Location Oy/ing Insbection Hotel / Motel:
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Telephone:
d_c 7._ 4-f )
13 2.3 Licensee
Contact:
Telephone:
Distribution:
(After Section Chief Approval)
Report Numoers: CO U C h L-/
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Approving Section Chief
- 3. Sid e.
O _3,yp/9 5
/
Inspectors
- d. c odid/
Project Section Chief K. 4.Mi Origtr.al to Branch File @s Project Engineer Branch Chief (EB)
Turner (TSS)
Form RII-T28
MSFECTICN
.W (Peni:e approved copy to Projects are =eet befo e inspection)
Inspection of:
37' l-u t,, t'
/p2-on f-9 A4 '13 (Factisty or (i nsee)
(Oates Type of Ins:vetion: Special outine/AnnouncefUnannounced/Backshift/orn.
shtft Submitted by: //# ( 4sterspa Accompanying Personnel Nut Outstandinq lt' ems Rev*ewed and the Following Sele:ted for inspection (Delete anc initial tscse not applicaele)
(
) Previous enforcetent matters.
OIL No.
(
) Previous open items. O!L No.
(
) Buliesins or Notices. OIL No.
(
) Nonroutine Itcassee reports.
Oil No.
(
) TMI items.
Date Subettted to Section Chief: 2. r wor 7 3 Date Projects Informed:
- 2. Y a,ne vs Date Plan Provided to Projects: 2 e e,,ne 9 3 Current t Complete Comments or (Optional) Inspection Area or Module Inspector Completion Status (Optional) l gar fm /ezri s n e ss e D 84'?fo ssa 86?ro Cdmos m A M ik
/ 4 13 As,tr#rx P** et m sH >e < 4' Td - 9 4 - 7 L Jce ca s s,o r s, u cxmas n y l
1 Instructions by Section Chief:
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l
/
/
1 Aoproved by: d blid/LL 3//f'/9'3 in Charge of (lection Chief)
'(0&te) Exit Interview: // dMA*d Location Durino I,v.pection j
Hotel / Mote 1: Hel.~hsy in ytm Benw St.
Telephone: I-ds0 Msst)/r Licensee
Contact:
- 3. c4 e/o 5,e f Te lephone :(y, >)- 4 4 4r - JA 2-Distribution: (After Section Chief Approval)
Report Numbers:
~
Approving Section Chief T'/ ()feeof 50 - 3 3 j# / 13 - 4 Inspectors A'./ Cste.to*a 93 09 Project Section Chief M**'5 NOTE: Use back of co-as Project Engineer /.d Se s,s Form if more
/
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Original to Branch File Space Needed.
Form RII-T28
5 i
INSPfC110W PLAll (Previde approved cePy to frejects one week before Inspection) i 12-n, 4d
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(Festlfty or W o'eWac ed/Unennevnc ed/IUkT@
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0!L No.
Yest e a --
Jate 59belttet to 3ectten Chief: _
m 3/v /f3 l
l,
(
3t
- 1) ate Projectstafersed:
I4/4f93 i
4
)ste Plan 7ter ded to Prefects:
Er14/f3 4
4 Currents coa. ente.,
co., tete to, tion.n raisectie. Ares.c x.4 vie raiouter co.eiette stetve footstaan I
Y
$\\'100 s
And c_a~ +%
z d
( C0kED L% l
@ e ^ G= 51.2 2 5e X 11 LP L.c)>.
g
-I iM
!. %s L. I i, 9M-sv.s?. 9.3.o7, k
i lastrvcitea: 6,sectten entef:-
p 4
~ m.
I MAR 31993n Charge of 5.Etrocl l
ADDreved by[M[7'1 %
(Oste) fait faterviews 6
i it.ceva. ru.n Hetel/Metelt 5 der..n,a
' ' feleshent: 4o 7-2. 2 '? -i o o 6
- LfceAsee Contacts _ uiwkde Telephones 407 -+r s -W7(,
Otstefbutten:.(After 5ectlen Chief Approvel)
Reeert Numbers Apprew' ng 5ectfee Chfef fas ectors -
ro-3W _
G-#
i Mit: Use back of Vo - x te -
32-oc Pro est fulfen Chfet
~-
- a....c t.tagi.neer
- c...
.l' ors f f more Pro e l
..... s.,e
INSPECTION PLAN,,,C.o., to,,o,em, t.
e..
..,e in mion)
Inspection of:
ST. LUCIE on 8-12. RB_.33 Facility or Licensee (Dates) 2.yne of Insoect ion: Rout ine, Announced, Normal Shi f t Sutmi t t ed bv:
Paul. T. Burnett Accant)any i no Pe r sonne I C. W. RAPP Outstanding items Reviewed and the Following Selected for Inspection (Delete and initial those not applicable)
(
) Previous enforcement matters.
OlL No.
(
) Previous open items.
Oil No.
7
(
) Bulletins or Notices.
OIL No.
( X) Non routine licensee reports.
LER No.
50-389/92-0008 Date Submitted to Section Chief:
ZZ JMl_.33 Date Proiects informed:
_5 JM8 93 Date Provided to Projects:
Current %
Conglete (Optional)
Inspection Area or Module inspector Comment, or Congletion Statue (optional 61705 Caiibration af NucIamr Instrumontation_.Systens_.-tiNatits E _
I 61706 Core Tharma1 Poner Evaluation tamiis.D_2 Review errors i n t he rma l nowe r _due_.1g dr i f t_ jig fendumter RTDs and f a i l u r e s t o ca l i b r a t e i ns t rarnan t s used_.im_the olant c a l o r ime t r i c - Un i t _L Instructions by Section Chief:
7
_./
jj Acoroved bv:
- F'h Ne~
/ /2 ? ' v
(Section Chief)
Date in charge of Exit interview:
P. T. Burnett Location Durino Insoection HoteI or Mote 1:
Ho1iday Inn. Jensen.Sch_Teiephone: 407#225-XMM Resident Insotr:
Telephone: 407/464-7822 Distribution:
Recort Nos.: 50-335/93-03 Approving Section Chief: R. V. Crlenjak 50-389/93-03 Inspectors: P. T. Burnett, C. W. Rapp
'roject Section Chief:K. D. Landis
'roject Engineer:R. P. Schin Branch Chief OB: T. A. Peebles
'Others:
H.A. Turner (TSS)
Original to Branch File:
INSPECTION PLAN (Provide approved copy to Projects two weeks before Inspection) r Inspection of: $h. I-Of Cs'e.
on / !4l-8[9J (Facility or Licensee)
/
(Datis) nounchnannounced/Back Shiftfrmal S Type of insp.ction: Special Submitted by: M.
Dry 14.5 Accompanying Personnel: _H.L. Wh,b er bf15N""
Outstandinq ltems Reviewed and the Following Selected for Inspection J
{ Delete and initial those not applicable)
(
) Previous enforcement matters. 0!L No.
(
) Previous open items. 0!L No.
l
(
) Bulletins or Motices. OIL No.
(
) Nonroutine licensee reports. OIL Mo.
(
) TMI items.
Date Submitted to Section Chief: /2 -/ r-9 L Date Projects Informed:
/2 -/ g. f 1 Date F1an Provided to Projects: / a-/d-9 2 1
Current 1 Complete Connents or (0ptional)
Inspection Area or Module Inspector Completion Status (0ptional)
/
'TL 25'15 / 110 Pakemme o F Sa h +v. Rela +d Check Wive.s Instructions by Section Chief:
s. b1 Approved by: //73/l/4#A"/M -
/ 2. - /1 -4 2 --
In Charge of 15ection Ch}df)
(Date)
Exit Interview:
location Durinq Inspection
~ A//.'7~/;omas Hotel / Motel:In dian R ver Telephone:/;@f'- 499-33 $9 Licensee contactGLm Astf. f t..h Telephone:(407 ) 4 t,g-4 2 / 2
~
Distribution:
(After Section Chief ApprovaF)
Report lumbers:
Approving Section Chief M. Branch So.33g /, g_o f Inspectors A1.Thm146 /f.WMfenev-S o-t s /I93.of Project Section Chief f(.La J;g NOTE: Use back of
/
Project Engineer R.Sc.b;n Form if more Original to Branch file space needed.
Branch Chief (EB)
Turner (TSS)
Form All-T28
i
- NSPI'CTION puul'.Provice approveo copy to Projects'ene week Defore
.nscectiont-1$neCt4cn of:
T.
C%
2n 35 10 " Ole 02 ff'
,Factitty or t, -
/ t0atesi i
2 -
De of insnaction:
Icectal outin ' nnounyUnannounceo/BacK Sh Normal Chift~ /
Submitted by: hkuor accompanying Personnel MW
' Outstandina It= Reviewed and the Followino Selected for insoection j-Delete and initial those not applicaole)
/
) Previous enforcement matters. OIL No.
) Previous'open items. OIL No.
) Bulletins or Notices. OIL No.
Nonroutine licensee reports. OIL No.
i IMI items.
i' I
Date submitteo to section Chief:
cr/nler Date Pro 1ects infomen:.
a/t t /4r j
Jate clan previoso to Pro 1ects:
6 Mr-3 j
Current Cosseents or
. Complete 4
j '
(Optional)
Inspection Area or Module Inspector Completion Status (Optional) i i
TL 2 rr rl i2.3 WennH z.Ou o&
KLvrs w nu oAa /Wer 2M i
4-
' Module Hrs Curren,1, AI s
P1anned Hes Con,g,},11,1 TlMir)ct 3I O
t s'
- nstructions by Section Chief:
1-Review TPPR Meetino Minutes
'Accroved by:
m W
J' In Charge of (Section Chief)
/(Da t'e ;
Exit interview: hb-WA' f
Location Ourino Insoection i
riotel/Motal:. (. % u
.%.,. Telennone:
M/na - co Licensee
Contact:
- 4. o.- &,
Teleonone:
m/ + %
Distribution:
(Af ter section Chief Approval) aeoort Numoers:
Approving Section Chief Inspectors Project Section Chief NOTE:
Use back of form-Ysp-I f if more' space neeoed 49'I Project Engineer-Or1ginal to Branen File I
-~
- s o
...=.
.. ~
_. - ~.
t f
l
'NSPECTION PLAN
.Provios aoorovec'c::oy to Projects one ween cefore
^.aspections
- 9seettion of:
$r 6 wie' on Jhy '9/~
~ 'oe of insnecti n la n
Unannounc a cx Shif
_l).
.h1TI Eubsttied bv: (( C#dierod Accomoanying Personnel 7. Yac 4 Outstandina Itaan. Reviewed and the Followina Selected for insoection J Delete and init1al those not applicaole)
(
) Previous enforcement matters. 31L No.
(
) Previous open items. OIL No.
i ) Bulletins or Notices. OIL No.
( ) Nonroutine licensee reports. OIL No.
) IMI items.
Date suositteo to section Chief:
7 J ar,, e yr Date cro1ects informea:
6 wa*- '9 r-Jate 3lan 0*ovicea c Protects:
7 we 'f r Current Cosuments or Comolete (Optional)
Inspection Area or Module
- nspector Completion Status (Optional)
Module Hrs Current Ai 12 Plannec Hrs Comolete gy>ro 20 70 4
I
- nstructions by Section Chief:
j Review TPPR Meeting Minutes c
AoDroved by:
/
LZlk '
b/7/95 In Charce of (Section Chief)
(0 ate)
Exit Interview:
CA"'vJ tocation Durina insoection c
rioteI/ Mote 1: fr,c,6e fuJirra 5#eYeoiicne:
1 - # s o - N e o < ') #
Licensee
Contact:
A. Arb rre Teleonone:
vo> - we - m o i
Distribution:
(After section Chief Approval) aeoort Numoers:
Approving Section Chief r./.An < m f.-33r/ff"'3 Inspectors g.A 6 4eA w re - M/ f r- <.3 Project Section Chief NOTE:
Use cack of form A Arm ' *'
if more scace needed Project r. inser A,.<f Cc vs Origine.
.o Branen File 1
,,.-p
w.
~
g-w
- - - - - - - - ~ ~ ~ - - - - " - - - - ' '
1 l
'NSPECTION 98AN
- Provios approveo copy to Projects one ween cefore
)
.nsoection) 1soect'~n of:
br L ucri on
' 4fut Y 'W
~
>ce of 'nsnect1 n ta Unannounc o Shif Snirt Submitted by:
[ 6 #, cia) Accompanying Personnel 7 se. 4 j
{
Outstandina Items ' Reviewed and the Followina Selected for !nsoection 1
- Delete ano inittal those not applicaole)
) Previous enforcement : natters. '31L No.
i
(
) Previous.open items. OIL No.
) Bulletins or Notices. OIL No.
R
(
) Nonroutine licensee reports. GIL No.
~
(
) IMI-items.
l g
3 -
- Jate sunmittaa to section Chief:
7We T I'
!4 Date oro1ects informea:
6 m,-
9 r
)
Date 31an Provicea :o Peo!ects:
7 m e- ' f C -
- i Current Cossents or
['
Complete (Optional)
Inspection Area or Module-
'nspector Completion Status (Optional) l t
1 l,
l Module Hrs Current AI s
Planneo Mrs comolete 4
- $t,Oro 20 70 5
I.
t
- nstructions by Section Chief:
Review TPPR Meetinp Minutes Sooroved by:
[EU' b!7/95 In Charce of (Section thief)
(Date)
Exit interview:
6^>OCd
-Location Durina Insoection y
HotallMotel: if n M y T'S k w Y eonone:
1~EDO~ HD&'Off o
Licensee
Contact:
g, /',Vv, rre Telennone:
Y o / - un - 7# 4 L-Distribution:
(After section Chief Approval) accort Numoers:
Approving Section Chief r.t. An < m f.-33f/#f3 i
1nsoectors$,1 C4ep o<a re - 3rt / 9 i-1.5 Project Section Chief NOTE: 'Jse back of form A Amm'
.f more soace neeoed Jroject Engineer A./ Ic w i
Original to Branen File e
l-
l
}NSPECTIONPLAN iProvide approveo cosy to Projects one weet before
.nssectionl asaction -<:
Sf. Lucie, 7 /a d 3n r k.13-/7, res-e (Facility or '.:censee)
(Dates j
vos of, insnaction:
50ec1al Routtne Announceo Unannounceo/Bact Shift Nolisel Shife
' Submitted by- [h Accompar.ying Personnel Outstandine It - Reviewed and the Followino Selected for Insnection I.
Delete and initial those not applicaole)
" " ;;- =^
_-7.t matters. OIL No.
-u (Previousopenitems.'OllNo.
94 -d 4 -O/
$Ef;th;;r,";;t::s. OIL No.
7g g i sensee reports. OIL No.
Date 5"hittaa to Sect 1on Chief:
- 2. - 2
'PS~
Date Pro 1ects Inforsnea:
- 2. - a - TF I
Data Plan Provicea to Protects:
7 iK~
Current Comments or Comolete (Optional)
Inspection Area or Module Inspector Completion Status (Optional)
B 2.70/ - D oernfre d.57h 6 4 of -&e-M& v u yr em..:=Im h w_=
s 7
1
.v i
' Module Hrs Current AI s
Planned Hrs Comolete Q2l}0 f W
0~
- nstructions by Section Chief:
O aevie, rppa a eting sinutes acoreved by:
vu A
'.S In Charge of (Section Chief)
- / pate)
Exit Interview: bd location Durino-Insnection Hotel /Motal:
'L d gaa f/ver Teleonone:
4 0 ~7 - 2 6 - 3 ~/ M
- Licensee
Contact:
Rick. Wa/kar. Teleonone:
40 7 -M-W Oistribution:
(After section. Chief Approval)
Reoort Numoers:
^
. Aoproving Section Chief -3nrr Insoectors L.,
Project Section Chief NOTE: Use oack of form W5 789 MM M
-L O if more soace neeoed
/
Droject Engineer Sc/Aln Original to Branen File d
+
w i--
e--+
=
4 INSPECTION PLAN (Provide approved copy to Projects two weeks before In Inspection of:
J7-h c /E T-//>- /7 //f on (Facility or Licensee)
(Dates)
Type of Inspection: $n;iel6 tine /AnnounceTJhenov,,c;4/05 Sh'ft Submitted by:
26 dW-15 @
4
[
Accanoanyino Personnel-Outstandinq ltems Reviewed and the Following Selected for Inspection l
(Delete ano initial those not applicable)
~
( dPrevious enforcement matters.
0!L No.
99-of-o/
- f y - o / - v4-(
) Previous open items. 0!L No. _.
4
(
) Bulletins or Notices. 0!L No.
j
(
) Nonroutine Itcensee reports.
0!L No.
~
l!
(
) TM1 items.
Date Submitted to Section Chief:
/>=//r-2
/
i Date Pro.1ects Inferised:
//.s of /I i
Date Plan Providea to Projects:
//, o/pr Current t 2
Complete i
(0ptional)
Inspection Area or Module Inspector Completion Status (Optional)
Comunents or 3 7.rro 1
i 1
I i
i Instructions ey Section chief:
m t;n s, AA. A.
L A.r.
27-94~ M - 02.0G, E E -ef-A ooo 2.
.W I A I
i
\\
l / //, /#/
/m 1 /
Approved by: V //7 h
//5///'y T In charge of (se
~ 6 chief)
/ (Oste)
Exit Interview:
ZEaNo Location Duri
. nspection Hote l / Mote l : ' /x n/m rr d~4 ruw h & 4 Telephone:
L1censee contact:
h 4 /-
9 o ? /z. t r - / N Telephone:
yo 7/n v -,. u Distribution: (After Section Chief Approval) i Approving Section Chief pe.es Report Numoers:
)
Inspectors 4MW 3;; /fc,,
1 Project Section Chief b o" NOTE: Use back of wr hr-o e Project Engineer
.M '*'
Original to Branch File Form if more space needed.
Branch Chief (EB) ca r.
Turner (TSS)-
Form AII-728 n
n..
.-m
..n
. - ~,.. - -
/
INSPECTION PLAN (Provide approved copy to Projects two weeks before Inspection)
Inspection of:
, bl4C.) f.,
onJbo-2t/[f5% y o-It/M 2#-Jf!94 (Facility or Licensee)
/
t'Datef) /
/
)
Type of Inso.s. tion: Special/ Routine / Announced / Unannounced /Back Shift / Normal Shift Submitted by: k T /1DtV)d s Accompanying Personnel: M.Mf//ey [ 7eg//
Outstanding items Reviewed and the Following Selected for Inspection b' d
dW (Delete ano initial those not applicable) i
(
) Previous enforcement matters.
OIL No.
(
) Previous open items. 0!L No.
(
) Sulletins or Notices. OIL No.
(
)- Nonroutine 11consee reports. OIL No.
i
(
) TMI items.
Date Submitted to Section Chief: 2-M-96 Date Pro.lects Informed:
2-7-45 Date Plan Provided to Projects: 10-75 2.24-95 Current 5 Complete Comments or (Octional)
Inspection Area or Module Inspector C-letion Status (0ptional) i O 9~1 F* t' A t7
/~) 4+=
n J
J 1 J J t.J N o-
[AAALHD A Instructions by Section Chief:
r),,, A.u c w1. t <_. + tu a
sft, 5'# r LA e1 fw su L,0 b - 2 ~ L. -
v naw aht*>---
n LM,
%d L f6 /A m. } A. f. c o.1-Al Dtz,
- R. Ww a n
+L LL L w,
/
/
O y
Approved by:
(( /J "Tfc..'--O ~
'/ < yff F In Charge of (5ectmfn/CMief)'
( Da te )~
Exit Interview: M. ~/~homa s Location During Inspection Hotel / Motel:
Telephone:
Licensee
Contact:
7 ten Half (407) qM-qsis Telephone:
Distribution:
(After Section'Chiff Approval)
Report Numgers:
Approving Section Chief C,Mo Ao-3g5/9g-05 lnspectors M. 7%rna f AD - g 29/ es - os Project Section Chief h'.Landid NOTE: Use back of
/
Project Engineer R. Sc.Ain Fonn if more Original to Branch File space needed.
Branch Chief (EB)c,ca,5f g Form RII-T28 Turner (TSS)
l.4 L
INSPECTION PLAN FOR ENGINEERING AND TECHNICAL SUPPORT FACILITY: ST. LUCIE I AND 2 REPORT NO. 50-335,389/95-05 INSPECTION DATES: MARCH 20-24, 1995; APRIL 10-14 AND 24-28, 1995 INSPECTORS: M. THOMAS (Lead)
M.S. MILLER (ST. LUCIE RESIDENT)
R.K. MATHEW (NRR SPECIAL INSPECTION BRANCH)
PREREQUISITES:
(1)
LEAD INSPECTOR AND/0R PROJECTS HAS NOTIFIED LICENSEE OF THE INTENDED INSPECTION.
.j (2)
INSPECTORS HAVE REVIEWED THIS PLAN AND IP 37550.
1 (3)
INSPECTORS HAVE REVIEWED SALP :NPUT FOR THE ENGINEERING AREA AND HAVE REVIEWED THE ASSOCIATED INSPECTION REPORTS.
(4)
REVIEW 0F INSPECTION FOLLOW-UP SYSTEM'S LIST FOR IDENTIFICATION OF OPEN ITEMS WHICH CAN BE REVIEWED FOR CLOSURE DURING THIS INSPECTION.
OBJECTIVES:
(I)
TO EVALUATE THE LICENSEE'S ENGINEERING AND TECHNICAL SUPPORT ACTIVITIES PARTICULARLY WITH RESPECT TO THE EFFECTIVENESS OF THE ENGINEERING 1
ORGANIZATION (SITE AND CORPORATE) IN THE PERFORMANCE OF ROUTINE AND REACTIVE SITE ACTIVITIES SUCH AS DESIGN CHANGES / PLANT MODIFICATIONS, ENGINEERING EVALUATIONS, ETC. THIS INCLUDES ENGINEERING BACKLOGS.
(2)
TO EVALUATE COMMUNICATIONS BETWEEN ENGINEERING AND OTHER ORGANIZATIONS SUCH AS MAINTENANCE. OPERATIONS, REGULATORY COMPLIANCE, TECHNICAL SUPPORT, AND CORPORATE ENGINEERING TO ASSESS THE EFFECTIVENESS AND TIMELINESS OF ENGINEERING SUPPORT DURING THE RESOLUTION OF EMERGING DEFICIENT CONDITIONS.
(3)
-T0 EVALUATE INTERFACE AND OVERSIGHT CONTROLS OVER CONTRACT ENGINEERING WHERE APPLICABLE.
NOTE:
INSPECTION PROCEDURE 37550 PROVIDES DETAIL INSPECTION GUIDANCE TO ACCONPLISH THE INSPECTION OBJECTIVES.
/
9' ENGINEERING AND TECHNICAL SUPPORT INSPECTION OUTLINE The following items are to be evaluated during the-inspection and assessment of the licensee's engineering and technical support program.
NRC Inspection Procedure 37550 provides details on the the items which should be addressed during the inspection.
1.
Design changes and plant modifications including both Major and Minor Modifications.
Evaluations should be made on recently completed modifications during both outage and non-outage and those scheduled for a future refueling outage.
2.
Evaluate TM programmatic controls and the various methods used for TM implementation (jumpers, lifted leads, etc.)
Review post implementation testing requirements for active TMs 3.
Engineering's' involvement in site activities and communications with other on-site and off-site organizations such as:
Prioritization of Modifications Operator work-arounds 50.59 Evaluations Maintenance work requests Request for engineering assists Review engineering dispositions for selected non-conformance/ STARS or deficiency reports Design change packages 4.
Backlog of work activities with engineering involvement.
Maintenance work requests Request for engineering assists i
Non-conformance or deficiency reports l
Design change packages 5.
Maintenance of design basis configuration program, i.e. drawing / document controls.
6.
Engineering organization staffing and training.
On-site Off-site / Corporate office System / Component engineers Staffing levels Training program 7.
Self assessment and independent audits of the engineering program.
s 8.
Independent Safety Engineering Group activities.
D
1 e
4 INSPECTION PLAN (Provide approved copy to Projects two weeks before Inspection) ispection of:
$4 Lule _
/.2//3_ /4-fq3
__ on (Facility or Licensee)
(Dates) i Type of Inspection: Special outi /
/ Unannounced /8ack Shift /
ft l
Sutunitted by:
[ W r.J // /
Accompanying Personnel:
A//A
~
f i
Outstanding items Reviewed and the Following Selected for Inspection 1
(Delete and initial those not applicable)
(
) Previous enforcement matters. 0!L No.
(
) Previous open items. OIL No.
(
) Bulletins or Notices. OIL No.
i -
(
~ ) Nonroutine licensee reports.
OIL No.
(
) TMI items.
Date Submitted to Section Chief:
//[22. /H j
Date Projects Informed:
n //g,/p Date Plan Provided to Projects:
1 i
trent 1 mplete Comments or 4
I (Optional)
Inspection Area or Module Inspector Completion Status (0ptional)
{
C6 On I 1' 17<R I
~
j i
Instructions by Section chief:
1
(
/
f fans
/
/
Approved by: Vhe%h n /r r / 9 y In Charge of ect GMief)
'lDate)
Exit Interview:
(,.yg t.) /v' V i
Lccation 0 ine ! pection Etel /Motal: Dw Lv Telephone:
40 7-4-6 / _ </ M 7 Licensee Ccntact: '
Telephone:
i Distribution:
(After Section Chief Approval)
Report Numoers:
<;'a _ M f/43 -J'i j
3 roving Section Chief J. B l u. ~ <_.
g,,, ug W 7 2 9 pectors 84.YcW /cy'
, reject Section Chief K. LQ j Project Engineer f.5d,~S Original to Branch File Branch Chief (EB)
Form RII-T28 Turner (TSS)
1,
f l
INSPECTION PLAN (Provide approved copy to Projects two weeks before Inspection)
Inspection of:
$l(ALR-26h on
]
(Factilty or Licensee)
/
(pates )
i
-)
Type of anspection: pecta / Routine / Announced / Unannounced /Back Shift /Nomal Shift Sutunitted by: E
- ded
- 4. M/#er M. HeIkrodt accom anyino personnei:
l Outstandinq ltems Reviewed and the Following Selected for Inspection i
(peiete and initial those not appitcable)
/
(
) Previous enforcement matters.
0!L No.
f
)
{ d Previous open items. 0!L No.
S e-sci / A a
l
(
) Bulletins or Notices. 0!L No.
j,
-(
) Nonroutine ifcensee reports.
O!L No.
i
('
) TMI items.
3 Date Submitted to Section Chief:
FI 4
Date Projects Informed:
Pre 6esea /u j
Date Plan Provided to Projects:
fru/o u r /u s
Current 1 l
w iete Comments or stional)
Inspection Area or Modul.e Inspector Completion Status (Optional) t
. re e_
atrc.et. A 4w; I
l.
a d
i Instructions by Section Chief:
i Approved by: M 'db i v7 7 W 4 SrIn Charge of (Sectiott Chief)
'(Date)
Exit Interview: 8 5/Nt/d Lccation Durinq Inspection i
Kdte1/ Mote 1:
Afory/o r Oddie/s thc4,84) Telephone: h 7-2W- /SB O
}
Licensee
Contact:
CJ, r /,r
/ v4 /ta.
' Telephone:
- O 7-4 e> 5 - +S V 6 i
Dittribution: (Af ter Section Chief Approval)
Report Numoers:
i Approving Section Chief C,0.0sPo,
Jyr, Jff / q y - / /
i taspectors ///, M,7/e6 41 t/c/bree,s
)
ject Section Chief A' /
NOTE: Use back of
.sject Engineer A. Scl <.a>, cl.5 i
Form if more n
Original to Branch File space needed.
Branch Chief (EB)
Form RII-T28 Turner (TSS) i
. -.. -~.
Inspection Plan for Motor-Operated Valve Inspection at St. Lucie Plant litt:
St. Lucia Report No.:
50-335,389/94-11'
)
Module:
Temporary Instruction 2515/109, Revision 1 Inspectors:
E. Girard (Lead) i M. Miller i
M. Holbrook (Contractor to NRR) patat:
May 2-6, 1994
'Assianments:
Open Items From Previous Inspections Are Assigned as Follows:
i Inspector Followup Item 50-389/93-25 Girard (Overall) (Niller to review design-basis and Holbrook to review test data calculation to demonstrate weak link not exceeded)
Concerns listed in the Summary of Inspection Report 50-335,389/91-18,to be inspected as follows:
Written Licensee Response Provided:
(1) - Girard (2) - Girard
[
No Written Licensee Response:
(1) - Holbrook (2) - Holbrook (3) - Girard (4) - Girard (5) - Miller 4
(6) - Girard (7) - Holbrook (8) - Girard Part 2 of TI 2515/109 (Revision 1)
Section 04.05 Verify that the licensee has performed design-basis reviews of the selected MOVs (including pressure locking and thermal binding of gate valves) - Miller Section 04.06 Verify that the licensee has determined adequate MOV sizing and switch settings - Holbrook Section 04.07 Verify that the licensee has demonstrated the design-basis capability of the selected MOVs (including M0V test failures and reportability of MOV capability determinations) - Holbrook
2 b
,/
l id.
l 2
1 i
~
Sect.on 04.08 Verify that the licensee has established a method for periodic verification of the design-basis capability of
]
the selected NOVs~ - N111er Section 04.09 Verify that the licensee is analyzing NOV failures, justifying corrective actions, and trending information
. pertinent to the selected NOVs (including licensee response to Limitorque Part 21 on AC motors) - Girard 4
(N111er to assess 10 CFR Part 21 response) 1 Section 04.10 Verify that the licensee is meeting the program schedule l
in accordance with its commitments - Girard i
Section 04.11 Verify quality assurance program implementation - Miller-5 i' Notor trakes Issue - N111er i
Preparation:
Each inspector should become familiar with'the information in the reference materials listed below.
Reference Material:
}1 Generic Letter 89-10 and supplements 1 through 6 Temporary Instruction 2515/109 Revision 1 i
NRR Nemorandum dated April-30, 1993, on NOV Inspections NRC Inspection Report 50-335, 389/91-18 (November 18,1991)
Licensee Response / Schedule Extension Letter dated February 14, 1992 i
NRC Acknowledgement Letter dated March 16, 1992 IFI 93-25-01 of NRC Inspection Report 50-335, 389/93-25 (Dec. 1, 1993)
Report:
l Each inspector has been assigned specific areas to be addressed.during the inspection. The assigned individual for each area will be i
responsible for obtaining any needed input from other individuals. Each inspector should prepare his input for the report. Report input should i
be provided to E. Girard for assembly into the inspection report by COS, May 13, 1994.
Direct inspection time should be reported under TI 2515/109.
I
~
u t
e,-..,
w
PLANT SUPPORT BRANCH INSPECTION PLAN
//
//
4 i
er uz Inspection Dates:
to Inspection of:
iI)lT/94 11 J' z z.j%
Report Nueber: %
77'D End Date of Integrated Report:
/
Feeder Report Due Date:
Type of Inspection: Plant Support (Health Physics / Emergency Preparedness)
(Announced / Unannounced)(Cge/ Regional Initiative /Special)
IP i or TI i:
%Ko
% 75 0
-r*r* - 133 Planned Inspection Hours: S D 9
9 Hours Completed to Date:
o o
e Percent Compi After Insp: EC / /o5 47 %
9 /zF 22 %
9 / 25 36 %
Inspector (s): Lead:
F WerGr r Accompanying:
sur e
Inspection Objectives:
(Inspection Procedures used as Guidance.
Provide brief write-up on objectives of inspection.
Consider including reliability of rad monitors, spare parts availability, laid-up rad waste systems, humidistat testing, and other recent plant issues.)
?+950 %ioh rue LM.rr bursar A,e SFFwLd1 /*D C u /DDn stc R L IM4)tTDM M/e
% sat Aank RrM-r1 cAu dA w.srv M D stwrn ts SM %nt. twvr wa r t. %S ~ TEAK l
bh150
.%s.n D Skh of14 t ~ffwB L)h572 Aifr'T. AAsb TEAA)(/9/1AYJAA.) '.)Y W/EMY/VE A4kT&A/A*L W=a: 7sAnsMr+7m> /.sme of esecr<ro ve wnre-
- IT 2C'l<
I' T IMucefMTM;90
'F %MD 49 f5A fM5 /M-I?9 / /OfAf ?/AT W
- Reminder - Obtain Performance Indicator Data ********
Outstanding Items To Be Reviewed:
/; onr._
Outstanding items NOT Being Reviewed:
Allegations To Be reviewed: (Use #s only)
C 04-4 -O/5D /-rx :.,3/A Projects Branch Chief / Senior Resident Perspective:
(Identify any request for inspections / review of certain issues) f
'PL)177 k$3 /Pf/Os_) AO/)/f0f/M 6fDu o f#Fh?' //) GSbfdM s
Requirements To Inspect Against:
(i.e., TS, FSAR, 10 CFR procedure; source of information - project engineers have TS, FSARs are in room 3126B, and the Examiners library has most licensee administrative procedures)
Ltcener Goutzutes Tot cauum> n uziou-nve pinrm rxAwwr-G C nritfif n f-A>T4 r-nA. /IG A t u t rR sh 9)-ftN4.-
Ch'b /**wti?LA T.S ' O/0l/ 'Af=*917'S a
TOR
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/1M//I TO$)fd.-
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~~t/-,ve pnr 7/ 7/pa f E /) st/Ajf.cf_5 (* c//#464S IFv' F.J i4-V- /? - 10 rev. 5/96
PLANT SUPPORT BRANCH INSPECTION PLAN (Page 2)
Plant Issues List Review:
(Consult the Assigned Inspector, the PIL, and provide a brief discussion of the major adverse trends noted in the area of inspection for the last year of data)
Pk w r>
w ws
& 1 t;wnwns mimi stwint wwn uesim rnmwxr cap <AM P LE tan s Rittaw fkus F A S4NC Of DFrnrinW 4%f R 5?v mu erisu-nM PPR Suussary review:
(Consult the Assigned Inspector, review the last PPR summary or SALP and note any trends or recommendations.
Identify where these are factored into your inspection.)
wu r p,e_, r er ix.p a -r m w r ar< w t r w e e.. m u m u w w ! s n o n a I w a i x p y, w
/
U.sr fff IPE Important Systems:
(List the top three or four systems; if licensee is working on any of these systems while you are on-site and high radiation or high contamination levels exist for the work, you may want to inspect this activity Lodging During Inspection: um,e owre s2n2.r,od Phone No. en? ng-Moo Address groer n._
Site
Contact:
9%-/ -r
@yac-m Phone No.
M'/ ett- ?55D 131'E In Charge of Exit Interview:
- ~ s h a -r Branch Chief's Instructions:
s Approval:
Date:I L
PS' Branch Chief
(
Date Submitted to PS Branch Chief:
/0 /2 4Iot, Date Projects Informed:
io/m t, e
Date Plan Provided to Projects:
/3/zd /cc Copies Provided To:
Projects Branch Chief K '"*5 Projects Engineer E.;eA Plant Support branch Chief g, p.g Original: To Plant Support Branch Files rev. 5/96
A t
3 J.
4
[
IEEPECTI(N PL&W Rev. 1/17/96 1
r INSPECTION OF St. Lucie l
\\
TYPE OF INSPECTION: ' Corrective Action Plan Inspection -
Routine, Announced, Normal Shift 1
j INSPECTION DATES:
January 22-27, 1996 REPORT NUMBER:
50-335,389/96-01 (Resident Inspector Integrated Report for 1/7/96 - 2/17/96)
}
INSPECTORS:
R. Schin, M. Thomas, R. Moore 3j i
INSPECTION SCOPE:
- j Review the licensee's implementation of actions outlined in their Corrective Action Plan (CAP); as presented by the licensee in j
meetings with the NRC on August 29 and November 1, 1995.-
Verify 1
that the CAP addresses.the areas identified by the NRC Root Cause Evaluation.
Review the following CAP areas:
resolution of long-standing problems, equipment perfonnance, personnel performance, j
procedure improvement, identification and correction of deficient conditions.
Also, review management oversight and line management accountability.
Assess the CAP scope, implementation,
)
1 and effectiveness.
3 4
7J INSPECTION PLAN DETAILSs See Attachment t
i OUTSTANDING ITSMS TO BE REVIEWED:
VIO 335/95-05-01, Failure to implement design requirement specified in PC/M 039-294.
I URI 335,389/95-05-02, Power supply upgrade for existing steam generator wide range level instruments.
i l INSPECTION NODULES:
40500; Effectiveness of Licensee Controls in Identifying, Resolving, and Correcting Problems (RI) 92903; Engineering Followup (RI)
LOCATION DURING INSPECTION:
Motel:
Holiday Inn 407/225-3000 k;
Licensee
Contact:
Ed Benken 407/468-4248 i
IN CIARGE OF EXIT INTERVIEW:
R. Schin j
BRANCE CEIEF'S INSTRUC'iIONS:
4 4
APPROVING BEANCE CNIEF:
O
/N Date:
//
t Distribution (Af ter Branch Chief approval) : See Page 2 1
l i
l
/*
- }
~.;
2 Distribution (Af ter Branch Chief approval) :
Approving Branch Chief:
C. Casto-Inspectors:
R. Schin,_M. Thomas, R. Moore j
Project Branch Chief:
K. Landis Project Engineer:
L. Mellen Senior Resident Inspector:
R. Prevatte / M. Miller Original To Branch Files:
Engineering Branch 4
'i h
.i 1
i 6
h Y
=
r
$h.
1 3
INSPECTION PLAN DETAILS ST LUCIE CORRECTIVE ACTION PLAN INSPECTION Use site integration matrix and inspection guidance of IP 40500, Effectiveness of Licensee Controls in Identifying, Resolving, and Correcting Problens, in reviewing the following areas.
Assess the scope, implementation, and effectiveness of the licensee's Corrective Action Plan in each area.
1.
Resolution of long-standing problems (M. Thomas)
{
Review licensee's new process for ensuring timely a.
resolution of deficiencies; Administrative Procedure on
" Assessment of Abnormal Plant Configurations or Significant Material Deficient Conditions on Plant Operation."
l b.
Review current outstanding "long standing, repetitive problems" and assess the licensee's identification of such problems and plans / schedules for resolution.
Review licensee records, discuss with senior resident inspector, i
c.
Assess the licensee's effectiveness in correcting such
{
problems during the Fall 1995 Unit 2 refueling outage.
Discuss with' licensee and senior resident inspector.
1 2.
Equipment performance (R. Moore) 1 a.
Review open operator workarounds, assess licensee performance in identifying and in reducing them.
Discuss with operators.
b.
Review the licensee's root cause procedure / process.
Review two recent root cause analyses.
Review process for determining post-maintenance testing c.
to be done to assure coerabilitv.
Review scope of post-maintenance testing for two recent significant modifications and two recent significant repairs.
d.
Review two procedures used by contractors recently for appropriate detail, step signoffs, QA inspections, and independent verification.
'3.
Personnel performance (R. Moore) a.
Review licensee's written and verbal communication of expectations to employees and contractors, and
-licensee's actions in identifying and responding to recent cases when these expectations may have been
____ _~
i
>f
)
t 4
i exceeded (superior performance) or may not have been net (substandard performance),
i b.
. Review licensee's tracking.and trending of personnel performance.
I c.
Review log keeping practices for events (including low level events) and event communication to management.
c.
Discuss results of this licensee act' ion item and l
current personnel attitudes with senior resident inspector, about six selected personnel (operators, maintenance personnel, engineers), and plant manager.
4.
Procedure improvement (R. Schin) i a.
Review Plant Policy 105 on technical review for first-1 time use of procedures under conditions different than i
originally intended, and the Infrequently Performed Test and Evolutions procedure.
b.
Review licensee policy on use of procedures when
{
initial conditions or precautions of procedure are not satisfied.-
c.
' Review several procedures for aufficient' detail in
{
' initial conditions' and ' precautions' sections of procedures.
l d.
Review licensee's procedure review / approval process for compliance with TS.
(in particular, for maintenance work orders that reference technical manual instructions)
Review the licensee's definition of procedure e.
compliance.
Discuss with selected operations and 4
maintenance personnel their understanding of procedure compliance.
f.
Review the licensee's Temporary Change Notice and Procedure Change Report logs, assess the recent increase in activity.
g.
Review three recently completed maintenance. work orders, involving'use of maintenance procedures and technical manual instructions, for appropriate quality and proper use of procedures.
h.
Review licensee schedule for upgrades of procedures and guidance ~for quality of procedure upgrades.
5 1
s
. ~. _ -
xE l
('
0 5
[
i.
Review the licensee's recel.t large increase-in 8
procedure changes (corrections) for safety significance-
[
and adequacy of the review process.
j 5.
Identification and correction of deficient conditions i
(M. Thomas) a.
. Review licensee's assessment of deficient conditions, including their identification and trending process.
b.
' Review licensee's staffing and use of Quality Assurance, c.
Review QA coverage of all former ISEG functions.
d.
Review.two recent QA audits for quality.
l 6..
. Management oversight and line management accountability (R. Schin)
- a..
Review upper management oversight of significant issues, including prioritization, assignment, scheduling, and tracking / followup.
b.
Review line management accountability for significant issues, including clear expectations from upper management and periodic reporting of status to upper
]
management.
1 Review the following Open Items:
1.
VIO 95-05-01 (SL1), Failure to implement design requirement 1
specified in PC/M 039-294.
(R. Moore) 2.
URI 95-05-02 (SL1 & 2), Power supply upgrade for existing steam generator wide range level instruments.
(M. Thomas)
{
i 1
l '
. l
i
.1 9,
ST. LUCIE/ TURKEY POINT INSPECTION PLAN Inspection Report Nos.: 50-335,389/ 95-17 and 50-250,251/95-17 j~
Inspection Dates: St. Lucie:
Nov. 6-17, 1995 Turkey Point: Nov. 27 --Dec. 8, 1995 Inspector:
R. Moore Inspection Scope: Procurement Engineering (PE), commercial grade procurement, item equivalency evaluations for obsolete replacement parts
-l Backaround:
l St. Lucie allegation RII-95-A-0065 ind Turkey Point allegation RII-95-A-0112 included several issues, with site procurement activity issues predominant.
These issues included the following:
1.
Qualification of procurement engineering staff, 2.
Failure to follow licensee procedures for material upgrade, i.e.
item equivalency evaluations and commercial grade dedication, 3.
Inappropriate revision of procurement documentation, and 4.
Improper classification of parts and equipment.
The alleger indicated the result of these issues was the installation of unqualified or substandard parts in safety related equipment.
This inspection will address the above issues. The inspection will review a sample of commercial grade dedications and item equivalency evaluations to determine if parts installed under these processes was adequately qualified. Additionally, the licensee's QA oversight of these processes will be reviewed.
The control and maintenance of the systems for categorization of equipment and parts (passport system and M&S catalog) 1 will be reviewed. Additionally, the qualification of receipt inspection QC personnel will be reviewed.
The specific issue regarding the qualification and use of Belzona Supermetal in safety related equipment will be included. Other issues addressed in the allegations which are not i
included in the above will not be addressed by this inspection.
The sample data base will include the time period from January,1994, to 1
November, 1995.
1
~
i<h INSPECTION GUIDANCE I.
Procedures
- Review licensee procedures for commercial grade dedication (CGD).
- Review procedures for replacement of obsolete parts and item equivalency d
evaluations (IEE).
- Review procedures for-revision and control of procurement documentation, specifically M&S catalog and passport. system.
- Determine who is authorized to make changes to procurement documents.
l
- Do' procedures allow changes to CGD or IEE packages without originator j
approval?. Does process require independent verification?
- Review status of St. Lucie QA finding regarding ' inappropriate change of IEE by a technical reviewer.
What are the responsibilities and limitations of a PE technical and i
- j quality reviewer? Were these exceeded?
II.
Procurement Engineering Qualifications 1
Review list of personnel qualified to perform CGI and IEE.
What training -and qualification was required by the licensee for these activities?
i Review list of qualified technical reviewers.
What training required?
Does it qualify the reviewer to make changes without the originator approval?
If so, are there limitations?
Discuss the CGD and IEE process with two pes.
Discuss reviewer process with two qualified reviewers.
- What is background of pes and reviewers?
What are the. interfaces with design engineering.
Can they be I
demonstrated?
1
.: Verify that training includer the following:
1 o Determining safety classification of an item.
0 Specifying design,
- material, and performance characteristics relevant to safety function.
j o specifying or performing commercial grade surveys.
o Preparation and review of procurement documents.
I
! ?
o Use of applicable procedures.
'a What are the qualifications / training of PE technical reviewers?
III. QC Receipt inspection 7-
from PE?
4
- How do the QC inspectors use the passport system or M&S catalog to verify proper parts were received?
1 a' From ~ sample of CGD and IEE, _ select a sample of Receipt inspectors and
,j verify qualification.
l
j
- How are receipt' inspection rejections documented?
- How are QC receipt inspectors qualified?
1..,. ;
n Q.
3 IV.
Sample i
- Select sample of 10 CGD from each site (list provided by site).
- Select sample of 10 IEE from each site (list provided by site).
- Verify associated PE was qualified.
- Verify procurement document was-not changed without originator approval.
- Verify safety function and critical characteristics (CCs) for the part were defined.
- Does documentation verify that critical characteristics were verified?
- What method was used to verify Ccs.
- Review receipt inspection documentation against CGD or IEE document.
- Verify proper classification of part in passport or M&S catalog.
- Was CGD or IEE adequate.to assure part installed in plant was adequately qualified?
- What are some common parts which are CGD or IEE?
i.e. switches, relays, solenoid valves, etc.
- If possible, review problem reports or performance history to determine if part performance has been reliable.
V.
Classificatiun of Parts
- What documents the classification of replacement parts and equipment?
i.e. passport or M&S catalog
- What is the procedure which provides guidance for maintenance and control of these documents / systems?
- Who is designated rssponsible for controlling these documents.
- Review revisions to the catalog or passport system related to changes in classification or designation of venders, part nos., etc.
- Does PE review these revisions by qualified individual?
are PE clerks inappropriately changing these doctments?
VI QA Audits
- Review any audits which included CGD or IEE activity in last 5 years.
- What problems were identified and were corrective actions effective?
- What problem reports identify deficiencies in the CGI or IEE process.
]
4
- Did audits review performance history of any CGI or IEE parts?
- Did audits review a sample of CGDs and IEEs for technical adequacy?
j
- Did auditors have any experience in this area.
- Are CGD and IEE processes identical or different at each site?
I i
l
(?
4 INFORMATION NEE 0E0 FROM LICENSEE i
1.
list of CGD from 1994 to present, new or active (from both sites) 2.
list of item equivalency evaluations 1994 to present new or active (both sites) 3.
Procedures and instruction for CGD and IEE
,).
. procedure for control of M&S catalog and passport database 4.
list of staff performing these functions j
5.
list of staff performing technical'and quality reviews of CGDs and IEEs 6.
list of qualification requirements for Procurement Engineers and technical reviewers; training outline or lesson plan
~
J 7.
List of revisions of updates or changes to the M&S catalog or passport listing of parts classifications 8.
list of expedited / emergency / urgent procurement form 1994'to present 9.
audit reports of IEE and CGD activities in last 5 years s
4 10.
any CGD or IEE of Belzona supermetal, purchase and use of Belzona on
]
safety related' equipment a
i i
i A
e
w l}.
t 1
5 PREPARATION 1.
Request and review licensee procedures prior to ensite inspection q
2.
Select initial sample of CGDs and IEEs and request documentation be available on arrival-at site 3.
Note: Turkey Point is a B31.1 plant, review code St. Lucie is an ASME Ill plant, review code 4.
Review the following documents:
ANSI N45.2.13-1976, QA requirements for Control of Items and 4
Services for Nuclear Power Plants RG 1.123, QA Requirements for Control of Procurement of Items and i
Services for Nuclear Power Plant GL 91-05, Licensee Commercial Grade Procurement -and Dedications Programs IP 38703 Commercial Grade Dedication IP 35746, QA Program (Procurement Control) j FPL Topical Quality Assurance Report Sections 4.0 through 8.0, for d
3
~
Procurement Document Control, Procedures, Control of Purchased Items
& Services R0! 1030, revision 6,
Processing - Allegations, Complaints, and Concerns Allegation Reports:
St. Lucie Ril-95-A-0065 and Turkey Point allegation RIl-95-A-Oll2 LICENSEE CONTACTS:
St. Lucie: Jerry Hoge, PE Manager (407-465-4238)
Turkey Point:
George Kuhn, PE Manager, (305-246-6854) 4
}
a
' f.
l INSPECTION PLAN (Prwth a copy to Projects two wets before inspection)
)
Inspection of:
ST. LUCIE NUCLEAR PLANT on 12/2-5/%
Facility or Licensee (Dates)
.Tvoe of Insoection:
Specia'/M{ sis /ki6cNgced/Unarncunccd/Sck Shift /M_tg Submitted by:
D.C. Payne Accomoanyino Personnel:
G.T.-HoDDer Outstanding Items Reviewed and the Following Selected for Inspection (oeiete ana initiai enose not appiscale)
(
) Previous enforcement matters. OIL No.
N/A
( X ) Previous open items. OIL Not 94-300-01
(-
) Bulletins or Notices. OIL No.
N/A
(-
) Non routine licensee reports. OIL No.
N/A 3 ate Submitted to Branch Chief:
11/25/96 Jate Proiects Informed:
- 08/08/96 Jate Provided to Prolects:
11/25/96 e
(Optional)
Inspection Area or Module Inspector Coments or Camletion Status (optional)
IP 71001 Licensed 00erator Reaualification Proaram Evaluation.
IP 92700 Insoect Ooen items (listed above) for closure.
s-IP 71707 Control Room Observations AL A M
\\
i l
i instructions by Branch Chief:
Acoroved by:
N
///L f4
/#' b8'ranenChief)
Date In charge of Exit Interview:
Payne j
Location Durina Insoection Hotel or Motel:
Holiday "nn Telephone:
561-225-3000 Licensee-Contact:
Mike A len (00ns Trna)
Telephone:
407 468 4161 Distribution:
Reoort Nos.
50-335.389/96-20 Approving Branch Chief:
T. A. Peebles Inspectors:
D. C. Payne i
G. T. Hopper
' Project Branch Chief: C. A. Julian Project Engineer:
S. Ninh Original to Branch File:
B. Michael G:\\0LFORMs\\lNsPPLAN.FRM - 3/3/95
f PLANT SUPPORT BRANCH INSPECTION PLAN Inspection of: ST tu o e-Inspection Dates: /d I /94 to /2/4 /W.
/
//
TED End Date of Integrated Report:
-r"E t Report Number:
Feeder Report Due Date:
-r w n Type of Inspection: Plant Support (Health Physics / Emergency Preparedness)
(Announced / Unannounced)(Core / Regional Initiative /Special)
IP # or TI #:
727fC Planned Inspection Hours: 24 Hours completed to Date: Fr Percent Compi After Insp:59 hor 56 %
t Inspector (s): Lead:
F t /w.a r Accompanying:
A/pe-Inspection Objectives:
(Inspection Procedures used as Guidance.
Provide brief write-up on objectives of inspection.
Consider including reliability of rad monitors, spare parts availability, laid-up rad waste systems, humidistat testing, and other recent plant issues.)
91Lm rRzv esv iw s.-c
% s-7 ion A nnem ure n e.sso a, inn. w w is m >J me er r CR A r r r r_ p e e
- hrMDL % ?_tnrfHuMt D MC V A +!* L'% 1/_ L r _ a k ti<l'V E F /t/) &
DerA &K C,A sse)ori 6-Reminder - Obtain Performance Indicator Data ********
Outstanding Items To Be Reviewed:
Acus Outstanding Items NOT Being Reviewed:
,M-Allegations To Be reviewed: (Use #s only) /b//E-Projects Branch Chief / Senior Resident Perspective:
(Identify any request for inspections / review of certain issues) t) r r'J w d-
</ftific-Requirements To Inspect Against:
(i.e., TS, FSAR, 10 CFR procedure; source of information - project engineers have TS, FSARs are in room 3126B, and the Examiners library has most licensee administrative procedures) n n racc rwr nsoc<
cor m crews-
- n.m,w
< nrm Ma u.
Dif?/*n t
- C-
%s '".d.ef f,/> A *f f
?Oj r$#f])f' t V la)h M4f 9 hnf M C G Cy c i !A// -
'b = A r t"
" t >,/) * /M,
- s t~bCC TC rev. 5/96
]
l[
- ') ",
PLANT SUPPORT BRANCH INSPECTION PLAN (Page'2)
Plant Issues List Review:
(Consult the Assigned Inspector, the'PIL, and-
. provide a brief discussion of the major adverse trends noted in the area of inspection for the -last year of data)
Poet Qvswan weg wM p m-ritse.
%nf NOMLrF MMdM
'") O d f EOuth & M, POOA RA b JDL8 fa It $L % d h*H bWo='
PPR Summary reviews (Consult the Assigned Inspector, review the last PPR summary or SALP and note any trends or recommendations.
Identify where these are factored into your inspection.)
P nuor A cnv > A-ris a provst -n s n pRetsw en sus a <t Ans
%ndn L tc !MM wis-16 D Y%ff G.A % ttlarC" M IPE Important Systems:
(List the top three or four systems; if licensee is working on any of these systems while you are on-site and high radiation or high contamination levels exist for the work, you may want to inspect this activity.)
/) A-Lodging During Inspection: wnies e, fri AAzr;rrox) Phone No.I M i7,r-Moo Address c n,4, r ci_ __
071 47-41'7f Site
Contact:
Aax r uenoM Phone No. 4 s
In Charge of Exit Interview:
r m,4 e-r Branch Chief's Instructions:
i Approval:
[
Date: /0 0
t PS 8tpnM Chief I
i Date Submitted to PS Branch Chief:
/o/z4/%
Date Projects Informed:
/o/z4/ac.
Date Plan Provided to Projects:
f o /24-/6 Copies Provided To:
Projects Branch Chief K uo6 Projects Engineer:
'E LEA Plant Support Branch Chief g g,%
Original: To Plant Support Branch Files rev. 5/96
n,,
4 INWECTION PLAN (Provide agrogcopy_to Projects two_ weeks 1before !n m
1 Inspection off D U d i C h YN on'
~
(Facility o Licensee)
' ggj g p (Dates)
Type of Inspection: Specia'/ Routine 1 ounced nannounced/Back Shi real SM Submitted by: b bYTdL M Accompanying Personnel:
i Outstandinq Items Reviewed and the Following Selected for Inspection I
(Delete and initial those not applicable)
(
)Previousenforcementmatters. OIL No.
LER .So r'?
(
) Previous open items. OIL No.
b" * "b
(
) Sulletins or Notices. OIL No.
(
) Nonroutine licensee reports. OIL No.
(
)TM! items.
Date Submitted to Section Chief: SW9 4 Date Projects Infonned:
7 t?g / 9 (r i
Date Plan Provided to Projects:
yl'ay l 9 (o Current 5 i
Complete Coments or (Optional)
Inspection Area or Module Inspector Completion Status (Optional) 1
- 4. L0 a e
)
eny72 K ITD isht49 c 4.(
v ca r i N Pro c.n ctM for Obwe t<6u. tm s
- r 7
- irt m
- 1 Anar,6,u m Wh
! ~ M L&t t au e 1 o,- e-Iw, A -
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Instructions by 5ection chief:
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Approved by:
'f#414 h J-2r-9t In Charge of gg T5ectidhCMief)
(Date)
Exit Interview:
4 Location During Inspection Hotel / Motel: 4 ik-ia o su
- lt/r#7& & 4 Telephone: '/07 - M
-3CCO Licensee
Contact:
Au cuie Telephone: tio 7 - u(2 o - 4 iW I
Distribution:
(After Section Chief Approval)
Report Numoers: W -c6 Approving Section Chief Inspectors
~
Project section Chief NOTE: Use back of Project Engineer Fonn if more Original to Branch File space needed.
Branch Chief (EB)
Form RII-T28 Turner (TSS)
IllSPECTI0ll PLAll c weo.s.v e,.sa.
e w -
Inspection of:
St. Lucie Nuclear Plant on Weeks of Mar 11 & 25 1996 FesAry er Usensee (Dateel e of Inss="*1on:
Initial examinations on normal shift submitted by onald F. Aiello Accompanyina-Personnel:
J. Nic1olaus, PNL -/-
f*/far?'^
Outstanding Items Reviewed and the Following Selected for Inspection insiet..w inaw se.
e seeme (N/A) Previous enforcement matters. OIL No.
(N/A) Previous open items. OIL No. 94-19-02.
A-m of i"-i ^=.:.a an SRO as an RO in REOL 94-19-03.
c_.:=a Pr=a-me m"m for Active s'=---
94-300-01. PrWwal AM-w:a for Removal of RCPS Prior to 500 (N/A) Bulletins or Notices. OIL No.
(N/A) Non routine licensee reports. OIL No.
Date Submitted to Branch Chief:
03/7/96 Date Projects Informed:
03/7/96 Date Provided to Projects:
03/7/96 Current %
Congdene (Ophonen inopeenen Area or Module inspeeter Commente er Congdeben Status lophonell Conduct Initial Examinations Mg, (C0 91gej '
O L,w p,. J C.
Co. m
$. rL. J Qu L y
v Instructions by Branch Chief:
Acoroved by:
T. A. Pe
.7 M4 (Seatum CNef)
Date In Charge of Exit Interview: R. Aiello Location Durina Inspection Hotel or Hotel:
Holiday Inn Telephone: (407) 225-3000 OcenseeContact:
Larry Rich Telephone:
(4071-468-4264 i
Distribution:
Report Nos.:
50-335.389/96-300
, roving Branch Chief: T. A. Peebles mspectors: R. Aiello, Region II; J. Nickolaus, (PNL)
Project Branch Chief: K. Landis Project Engineer: E. Lea Original to Branch File:
G:\\OLFORMS\\lNSPPLAN.FRM - 3/3/95
IllSPECTI0ld PUUI m = = is,,,,s e f e w %
Inspection of:
St. Lucie Nuclear Plant on Weeks of Mar 11 & 25 1996 Famimey or Usensee (Dataal Tvoe of Insneziion:
Initial examinations on normal shift Mh Submitted by: M onald F. Aiello Accompanyina Personnel:
J. Nic1olaus, PNL Outstanding items Reviewed and the Following Selected for Inspection co.a.t. en u.s m. n.t m (N/A) Previous enforcement matters. OIL No.
(N/A) Previous open items. OIL No. 94-19-02.
Area *-% of vaa.bba an SRO as an RO in PJ,QL 94-19-03. c.:Lu..a Prae =dairal CMance for Active I kannes 94-300-01. Procadairal MMance for Removal of RCPS Prior to 500 (N/A) Bulletins or Notices. OIL No.
(N/A) Non routine licensee reports. OIL No.
Date Submitted to Branch Chief:
__03/7/96 Date Projects Informed:
03/7/96 i
Date Provided to Projects:
03/7/96 Current %
Cerrolete (Oppenail hopeouen Aree or Module inspector Commente or Correleuen Status tapuonall Conduct Initial Examinations Instructions by Branch Chief:
Aporoved by:
T. A. Pe
_g -Yft
($encon CNef)
Date In Charge of Exit Interview: R. Aiello location Durina Inspection Hotel or Motel:
Holiday Inn Telephone: (407) 225-3000 Licensee
Contact:
Larry Rich Telephone:
(4071-468-4264 Distribution:
Report Nos.:
50-335.389/96-300 Approving Branch Chief: T. A. Peebles Inspectors: R. Aiello, Region II; J. Nickolaus, (PNL)
Project Branch Chief: K. Landis Project Engineer: E. Lea Original to Branch File:
GAOLFORMS\\lNSPPLAN.FRM 3/3/95
INSPECTION PLAN (Provide approved copy to Projects two weeks before Inspection)
Inspect 1on of:
k b CIO-on Id-/ N
- N [/d (Facility or Licensee).
(Dates)
Type of Inspection: Special
_h/ Unannounced /Back Shift 6nnal ShfM Submitted by:
krChi C.
C ro4)
Accompanying Personnel: NmL Outstanding Items Reviewed and the Following Selected for Inspection (Delete and initial those not applicable)
(
) Previous enforcement matters. OIL No.
(
-) Previous open items. OIL No. _
(
) Bulletins or Notices. OIL No.
]
(
) Nonroutine licensee reports. OIL No.
(
) TMI items.
Date Submitted to Section Chief:
2 - 2 tr - M Date Projects Informed:
2_.2 f._ S, g Date Plan Provided to Projects:
n _g-_ S.,4 4
Current 3 Complete Comments or (Optional)
Inspection Area or Module Inspector Completion Status (0ptional)
%P S 116 1
- % ta.i p n u.
Chikvaki ew a
f dc ITJ Lr CM G SnT 40 ((n.- )
4 i
e Instructions by Section Chief:
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i Approved by: N
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\\ VP7A/g /AV '1 L, In Charge of (Section cnief)
(D&te)'
Exit Interview: fuh C5h d Location During Inspection Hotel / Motel: ( 6,J e h, Gd fbce,FL Telephone: 4-o 7_-a-(/-u 2 3 i
Licensee contact:
Ro a wr-a.nt to Telephone: eo 7.-e-w ~7 D w Distribution:
(Af ter Section Chief Approval)
Report Numbers:
Approving %2a Chief Nht-u Inspectors, "'* C h a "
Project.SisD@ Chief L^^ *
- NOTE: Use back of Project Engineer L"
Form if more Original to Branch File space needed.
Beench2l$$f Form RII-T28 Technical Support Section (Turner)
X: h un k INSPECTION PLAN ~
i INSPECTION OF:
ST Lucie 1 & 2 INSPECTION DATES:
March 25-29, 1996 REPORT NUNBERS:
50-335,328/96-04 l
TYPE OF INSPECTION: Core (Maintenance and Surveillance)
INSPECTOR:
J. L. Coley INSPECTION OBJECTIVES: To evaluate the effectiveness of the licensee's maintenance and surveillance activities.
INSPECTION REQUIRENENTS:
Preplaning review of maintenance documents, TS, FSARs, PPR, SALP Reports, and Plant Status Report for this inspection will be performed the week of March 11-15, 1996.
ANALYSIS OF SITE NATRIX:
Matrix will be reviewed before inspection is performed as part of the preplaning review detai'ed above.
IPE INPORTANT SYSTENS:
High Pressure Safety Injection, Emergency Power Systems, and Component Cooling Water Senior Resident Perspective: The senior resident inspector stated that he would be back with me the week of March 11-15, 1996 to give me schedule of activities in order for me to perform my reviews. He also stated he wanted me to focus on procedure adequacy, post maintenance testing requirements, procedure adherence, and proper radiological controls in effect.
Since recent problems have been observed in these areas.
OUTSTANDING ITEMS:
As directed by SRI Lodging During Inspection: Holiday Inn 9 Jensen Beach 407-225-3000 In Charge of Exit Interview: Senior Resident Inspector (End of Month) Briefing with management at end of this inspection - J. L. Coley Branch Chief's Instructions: None to dateN)1
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i
~
Approving Branch Chief: P. Fredrickson M S MC s
Date Submitted to Branch Chief: 2-16-96 Date Projects Informed: 2-16-96 Date Plan Provided to Projects: 2-16-96
2 Copies Provided:
Maintenance Branch Chief: Chris Christensen, 2-16-96 Project Branch ~ Chief: K. Landis, 2-16-96 Project Engineer: E. Lea, 2-16-96 Orig!nal to Branch Files: Special Inspection Branch
,e i '
I PREPARATION WEEK PLAN ST. LUCIE MAINTIEANCE RULE BASELINE INSPECTION 13, 1996 SEPT M ER 9 4
Sectember 9 0900 - 1000 Inspectors / Observers meet in Region II IRC with Team Leader (initial brief/ overview of week effort) 1000 - 1200 Inspectors review IP 62706, NUMARC 93-01, and Palo Verde Inspection Report 96-09.
1300 Lunch 1200 1300 - 1600 Review other inspection notebook contents.
- Also, assignments for reports /LER reviews.
1 September 10 0800 - 0900 St. Lucie Program Overview (Group discussion) j j
0900 - 1000 PRA Insights (Walt and/or Jeff) 1200 Review of St. Lucie scoping for inclusion in Rule 1000 l
1300 Lunch 1200 1300 - 1400 Discussion of Inspector's review of reports & LERs for inclusion of systems in inspection effort 1400 1500 SRI /RI discussion of plant performance / areas worthy of MR inspection 1500 - 1600 Discussion and assignments for inspection of rule parts including assignment of systems for inspection September 11 0800 - 1600 Individual inspector / observer review of licensee supplied material /UFSAR/etc.
1
- q It" iq j
PREPARATION WEEE PLAN 1
ST. LUCIE MAINTEM&MCE RULE BASELINE INSPECTION
- 13. 1996 j
SEPT"*ER 9 September.12 0800 -1200 Inspectors continue with review of material associated with maintenance rule inspection.
Preparation of inspection plans for discussion with team leader.
1 j
1200 - 1300 Lunch q
i 1300 - 1400 Individual discussions between team leader and each I
inspector associated with inspection plans.
1400 - 1600 Group discussion of team approach to Maintenance Rule Baseline inspection at St Lucie.
Sect " ar 13 J
0800 - 1200 Final reviews and completion of individual inspection plans for St Lucie Baseline Inspection.
Plans must be submitted to and reviewed by team leader prior to completion of prep week efforts.
2
- p
.r PREPAEATIORf WEEK PLAN ST. LUCIM MAIMTEEAMCE RULE BASELINE INSPECTION
- 13. 1996 SEPTEMBER 9 ASSIGNMENTS:
04.1 Operator Knowledge of Maintenance Rule ALL M1.1 Scope of Structures, Systems &
GIBBS Components Included Nithin the Rule M1.2 Safety (or Risk) Deturmination ROGERS /
SEACKELFORD M1.3 Periodic Evaluation COLEY M1.4 Balancing Reliability and BEARDEN Unavailability ROGERS /
M1.5 Plant Safety Assessments Before Taking Equipment Out-of-Service SEACKELFORD M1.6 Goal Setting and Monit;oring for ALL (a) (1) SSCs EDG governors 1B2 EDG 4.16 kv AC safety-related Breakers U1 PORVs U1
'C' AFW Train Reactor Coolant Pump Seals M1.7 Preventative Maintenance and ALL Trending for (a) (2) SSCs M2.1 Material Condition Walkdowns ALL i
M7.1 Licensee Self Assessment HOLLAND E2.1 Review of UFSAR Commitments ALL E4.1 Engineer Knowledge of Maintenance Rule ALL 3
j.
-Cover Letter Cover Page Executive Sununary Report Details:
Summary of Plant Stacus Introduction I. OPERATIONS 04 Operator Knowledge and Performance 04.1 Ooerator Knowledce of Maintenance Rule (62706) i a.
Insoection Scone b.
Observations and Findinas c.
Conclusions II. MAIHTENANCE
.M1 Conduct of Maintenance M1.1 Scoce of Structures Systems, & Comoonents Included Within the i
Rule (62706) a.
Insoection Scoce i
b.
Observations and Findings c.
Conclusions Y
M1.2 Safety (or Risk) Determination (62706) a.
Insoection Scoce i
t
.e
-4 b.
Observations and Findinas c.
Conclusions M1.3 Periodic Evaluation (62706) a.
Insnection Scene 4
b.
.Qhservations and-Findinos s
?
i c.
Conclusions M1.4 Balancine Reliability and Unavailability (62706) a.
Insoection Scoce b.
Observations and Findinas P
c.
Conclusions
-I i
M1.5 Plant Safety Assessments Before ~'akina Ecuioment Out-of-Service (62706) a.
Inscection Scoce b.
Observations and Findinas c.
Conclusions M1.6 Goal Settina and Monitorinc for Ia)(1) SSCs I62706)
W o g. +
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ok a.
Tnanection Scoce b.
nhaervations and Findinas c.
Conclusions t
M1.7 Preventative Maintenance and Trendino for (a) (2) SSCs (62706) a.
Insoection Secre 4
b.
Qbservations and Findinas I
c.
Conclusions M2 Maintenance and Material Condition of Facilities and Equipment M2.1 Material Condition Walkdowns (62706) l a.
Insoection Score b.
Observations and Findinos w
c.
Conclusions i
NU Quality Assurance in Maintenance Activities M7.1 Licensee Self Assessment I62706) a.
Insoection Scoce I
e b.
Observations and Findinas i
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Conclusions i
III. ENGZEEERIEG j
4 E2 Engineering Support of Facilities and Equipunant I
E2.1 Review of Um4mtad Final Safety Analvain Renort (UFRA R
-C = 4emants (62706) l A recent discovery of a licensee operating their facility in a manner contrary to the UFSAR description highlighted the
~
need for-a special focused review that compares plant practices, procedures and/or parameters to the UFSAR descriptions.
While performing the inspections discussed in this report, the inspectors reviewed the' applicable portions-of the UFSAR that related to the areas inspected.
The i
inspectors verified that the UFSAR wording was consistent with the observed plant practi<:es, procedures and/or parameters.
???????????????? NEED TO MAEE SURE THIS IS DONE!!!!!III!Ii!I 1
E4 Engineering Staff Knowledge and Performance E4.1 Encineer Knowledae of the Maintenance Rule (62706) a.
Insoection Scone j
- j 4
b.
Observations and Findinos 4
c.
Conclusions I
q-
i V.
MANAGEMENT MEETINGS 4 -
X1' Exit Meeting Sununary 3
i I
1 i
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i MEMORANDUM FOR:
Distribution FROM:
William E. Holland, Reactor Inspector;(Team Leader)
I s
~
Maintenance Branch i
Division of Reactor Safety i
Region II 4
SUBJECT:
INSPECTION PLAN FOR ST. LUCIE UNITS 1 AND 2 MAINTENANCE RULE i
BASELINE INSPECTION Enclosed is the inspection plan for the Maintenance Rule Baseline Inspection at St.Lucie Units 1 and 2 that will be conducted during the period of September 16 through 20, 1996. The enclosed information is being forwarded to team members and NRR observers and includes the inspection scope, background, inspection methodology and guidance, schedule, team composition, and site l
logistics.
An entrance meeting with the licensee will be held Monday morning, July 16, 1996 at 9:00 a.m.
The formal exit meeting with the licensee is planned for Friday, July 20, 1996. A pre-exit review meeting will be held Thursday afternoon, July 19, 1996 at 2:00 p.m. (tentatively) at which time the team will discuss issues with NRC management to be presented at the exit meeting.
Related plant and inspection information will be contained within the Maintenance Rule Baseline Inspection Notebook under several Tabs. These notebook tabs will be provided the first day of the preparation week (September 9, 1996).
The information contained in these Tabs will be provided only.to team members and observers.
Enclosure:
As stated Distribution:
AFGibson, RII JRJohnson. RII SCBlack, NRR H0Christensen, RII KDLandis, RII RPCorreia, NRR DMVerrelli, RII RDGibbs, RII WCBearden RII JLColey, RII WGRogers, RII JLShackelford, NRR TABergman, NRR RKFrahm. Jr NRR WScott, NRR DRTaylor, RII/NRR MMiller, SRI, St.Lucie l
e
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1
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1 ENCLOSURE 1 8/30/96 St.Lucie Unit I and 2 Maintenance Rule Baseline Inspection I.
Insoection Objective The purpose and objective of the MR Baseline Inspections are to verify compliance with all parts of the Maintenance Rule at all' licensed commercial reactor sites. The " Maintenance Rule Baseline Inspection Guidance" and Inspection Procedure (IP) 62706 will be used during the baseline inspections which are scheduled to be accomplished within two years.
The results from the baseline. inspections would also serve as valuable information for NRR license renewal activities for any plant considering or
' applying for a renewed license.
II.
Backaround The Commission issued the Maintenance Rule (MR) 10 CFR 50.65 on July 10, 1991, to become effective in 5 years. As directed by the Commission, the first 2 years of the 5-year period were used by the staff to develop and issue regulatory guidance and the remaining 3 years for licensees to implement the guidance and for the staff to develop and. issue inspection guidance. The staff's expectation has been that all licensees will be in full compliance on the. effective date of the Maintenance Rule, July 10, 1996, without exception.
This inspection plan along with the referenced inspection procedures provides guidance to the inspection team to conduct the Maintenance Rule Baseline Inspection. Related inspection review / question sheets are included in several Tabs of the inspection plan notebook to assist each inspector in completing their assignments.
Supporting documents and references to the Maintenance Rule are included within Tabs of the inspection plan notebook.
III.
Inspection Scope t
The maintenance rule baseline inspections will be Regional Team Inspections which are under the Inspection Program described in MC 2515. These Regional Team Inspections are scheduled to be performed at all operating reactors.
'The team will use the guidance contained in the following documents to conduct this inspection: Tab 8, " Maintenance Rule Baseline Inspection j
Guidance / Checklist." Tab C "Related Inspection Procedure / Documents" which includes (IP) 62706. " Maintenance Rule." and various inspection review / question sheets which address each portion of the maintenance rule and are contained in several Tabs of the inspection plan notebook.
i During the first phase of the inspection (preparation week), the team will i
follow the guidance contained in related Tabs of the inspection plan notebook that address preparation week activities. Appropriate maintenance rule plant-1
c i
.[
information will be available as requested by the team leader using Tab Q,
" Pre-inspection Requested Items List." The following general areas will be covered during the preparation week:
.5 (1)
Review plant procedures to familiarize the team with plant layout 1
configuration, organization structure, and methods used by the licensee to implement the maintenance rule.
This review will include a verification and validation of the licensee's Maintenance Rule program as compared to 10 CFR 50.65, NUMARC 93-01, and Reg Guide 1.160.
Follow the guidance contained in Tab B, " Maintenance Rule Baseline Inspection Guidance / Checklist" and various other review / question sheets.
(2)
The team will independently review the plant UFSAR, E0P, and IPE/rRA to become familiar with SSCs that potentially should be included within the scope of the maintenance rule. This list will be used on site to validate the licensee's scoping activities.
(3)
The team will be briefed by the SRI /RI regarding licensee performance for the past two years.
In' addition, team members will independently review the St.Lucie Plant Issues Matrix to brainstorm selection of specific SSCs for review. Based on recent events, the backup shutdown facility will get priority consideration when selecting SSCs.
(4)
The team leader will select, with input from the team members, several SSCs that are within the scope of the Maintenance Rule and assign SSCs to inspectors to develop their individual inspection plans to complete the on-site vertical slice type inspection. Team members will review available data on the assigned SSCs during this phase of the inspection.
(5)
Each team member will attend PRA Briefing Session on Tuesday, September 10, 1996 (Facilitator: Walt Rogers and/or Jeff Shackelford).
(6)
Each team member will develop individual inspection plans for the SSCs assigned and furnish a copy of the individual inspection plan to the team leader on or before September 13, 1996.
(7)
The team leader will complete applicable portions of the Master Inspection Checklist. Inspection Prep-week Checklist, and finalize the Entrance Meeting Checklist.
During the on-site phase of the inspection, the team will follow the guidance contained in related Tabs of the inspection plan notebook that address on-site week activities.
During the on-site week the team will:
(1)
Assess the licensee's Maintenance Rule program using a deep vertical slice technique to accomplish the inspection objectives.
The term " deep vertical slice" refers to the in-depth review of selected SSCs, and completing a entire verification and validation process to ensure each SSC selected meets all aspects of 10 CFR 50.65 as described in IP 62706.
(2)
Assess the Maintenance Rule functional areas of the assigned SSCs looking for any programmatic weakness.
Concentrate on performance 2
s.
lf j
issues as previously identified in plant records _ to validate implementation of the Maintenance Rule.
.(3).
Perform a detailed walk-down of each assigned SSC (where possible) using IP 62706 as a reference document and the appropriate inspection =
guidance, checklist and data sheet as inspection instruction. Also, during observations of selected structures, inspection guidance provided-in Tab F,." Structural Inspection Guidance" to assist in reviewing the structural area.
(4)-
The team leader will tract and ensure completion of the Maintenance Rule Baseline. Inspection and indicate same in the applicable. portions of'the Master Inspection Checklist.
'!V.
Plant Specific Information
'St. Lucie Units 1 and 2 are C-E PWRs.
The plants are located on Hutchinson
- Island near Jensen Beach, Florida (approximately 40 miles North of West Palm
' Beach,FL.). These plants are operated by Florida Power and Light Company.
Plant background information including current Systematic Assessment of Licensee Performance (SALP) insights and plant data are provided in Tab D of the inspection plan book.
i V.
IImtec, tion Schedule j
i_
The team will prepare for the inspection during the week of September 9 - 13,
-1996 at the NRC Region II Office in Atlanta, Georgia.
The team leader will
)
provide any material'in addition to those provided by this plan that are needed.by the individual team members.
Team members should plan on i
participating in discussions with the team leader prior to the preparation week to discuss team assignments and final l'ogistical plans.
Each team member should ensure that his/her organization has submitted a good guy letter i[
through RII to St.Lucie (with a copy to the team leader) to allow for unescorted access prior to arrival for the inspection.
St.Lucie normal i
ji working hours are Monday through Friday, 7:30 a.m. to 4:00 p.m.
Appropriate l.'
team support and licensee participation has been coordinated beginning Monday, i
t September 16, 1996.
J Week of September 9 - 13, 1996 In-office review A detailed St.Lucie Maintenance' Rule document review will be conducted by the inspectors in the Region II Incident Response Center (29th floor) beginning at-9:00 a.m o.9 September 9, '1996 under the direction.of Bill Holland, Team Leader. ~ Prior to the preparation week, RII requested specific documents to be provided by.the: licensee for use by the' team members. During this preparation f
phase,'a review of the licensee's scoping process for Maintenance Rule SCCs inclusion will be conducted. Also,. team members will review the site's Maintenance Rule procedure and related programs'to become familiar with the R
3 i
t'
~
f processes and procedures used by the licensee to implement the requirements of the maintenance rule.
Each team member will attend a PRA Briefing on September 10, 1996.
Detailed inspection plans for areas assigned will be developed by the inspectors during this period. The individual team member's inspection plan is to be provided to the team leader on or before September 13, 1996.
Week of September 16 - 20, 1996 On-site Inspection Team members should arrive onsite at 7:30 a.m., September 16, 1996 for site specific training, badging and completion of other administrative requirements for unescorted access.
The normal expected time to complete the site specific training and badging is approximately one hour. The team meeting area will be inside the protective area and has been identified as a area within the Service Building.
The following team activities will be conducted on Monday September 16, 1996:
entrance meeting, pre-entrance and daily team meatings, l
overall plant tour (if desired), specific tours of selected SSCs (if desired),
and a licensee presentation on the Maintenance Rule Program.
The entrance i
meeting will be conducted at 9:00 a.m. on September 16, 1996 in a conference room in the Service Building after badging is completed. A team overview of the detailed inspections plans, last minute directions from the team leader and any related modifications will be conducted that morning as directed by the team leader. After the entrance meeting, the licensee will present their overview of implementation of the Maintenance Rule. The presentation should last approximately 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />.
The on-site inspection will commence thereafter.
Details of the daily, pre-exit and exit meetings are discussed in the next section. An internal NRC pre-exit meeting will be conducted at 2:00 p.m.
(tentative) on September 19, 1996. The exit meeting with the licensee will be conducted at 1:00 p.m. (tentative) on September 20. 1996.
Plan on departing the site after the exit meeting.
Please inform the team leader of your travel itinerary for all trips.
Week of September 23 - 27, 1996 Report Preparation The team will prepare inspection report input for the areas inspected.
This j
task will be conducted in the individual inspector's office unless the team leader requests otherwise.
Individual team member's report input should be received by the team leader on or before September 25, 1996 (Wednesday afternoon, c.o.b.).
After the report is organized, compiled, and developed by the team leader, and concurred on by the inspectors, the report will be i
reviewed by appropriate NRC regional management, changes incorporated by the team leader, and forwarded to HQ for review.
The report will be issued as a regional report within 30 days of the inspection exit (by October 20, 1996).
4
.y
- VI..
INSPECTION MEETINGS (1)
-INTERFACE AND COORDINATION MEETINGS Daily debrief meeting with.the-licensec (5:00 p.m. tentative) by the-team leader. Other team members, on occasion, may attend this meeting as coordinated with the team. leader.
Team meeting (4:00 p.m. each day) - each member of the team should BE PREPARED to BRIEFLY discuss findings (i.e.' concerns, problems, strengths) from the day's inspection.
Findings are to be documented (see Tab G) and given to the team leader each day prior to discussing them at the team meeting. -A notebook will be maintained by the team leader containing each team member's f idings. These finding sheets will assist during the pre-exit meeting with NRC L
management and during development of the inspection report.
(2)
NRC INTERNAL PRE-EXIT MEETING
.To be conducted September 19 at about.2:00 p.m.
To be attended by region and headquarters management.
Team members should generate a written five to ten minute (approximate) presentation on their findings and provide a copy to the team leader at least 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> prior to the pre-exit meeting. This presentation should address the following topics: inspector, areas (SSCs) inspected, findings with a brief summation. conclusion related to the effectiveness of the Maintenance Rule in the area inspected.
Also, each team member should be able to answer questions from NRC management on the inspector's finding sheets and their presentation.
(3)
EXIT MEETING Each team member rhall prepare written exit notes for their areas inspected. Where more than one team member inspects or assists in reviewing an area, the team leader will designate which inspector be responsible for preparation of the written. notes.
Each inspector will review his/her notes with the team leader for integration into the exit 4
presentation.
The team leader will present the inspection.-
findings /results at the exit meeting with the. licensee or.
' Friday, September 20, 1996.
. Licensee questions will be _ handled by the team leader.
On an as needed bases, the team leader will call on an inspector.to address an issue. Only'at that time should an 5
.+o
+i.
- a l 0
inspector address a question from the licensee. Questions that get too involved will be deferred until after the exit.
Team members should thoroughly discuss concerns with the licensee's contacts (and the team leader) during the inspection so that all that is necessary at the exit is a brief summary of the deficiencias, strengths, unresolved items, and observations, i.e. NO SURPRISES FOR THE LICENSEE OR THE NRC AT THE EXIT.
Findings are identified as discussed in NRC Manual Chapter 0610.
The exit meeting is tentatively scheduled for 1:00 p.m. on September 20, 1996. Make travel arrangements accordingly.
,i
i
,.el f b
VII. Team Members and Inspection Assiansents Team Leaber - Bill Holland, RII/DRS/M8 (404) 331-5544 i
Team Member -'Ron Gibbs, RII/DRS (404) 331-0346 SSCs assigned (vertical slice): Unit (s) *, (System (s) *, Train (s) *,
Structure (s) *, and Component (s)
- Selected programmatic reviews (i.e., scoping, assessments, etc).
Team Member - Bill Bearden, RII/DRS
. Unit (s) *, System (s) *, Train (s) *,
(404) 331-5572 SSCs assigned (vertical slice):
Structure (s) *, and Component (s)
- Selected programatic reviews (i.e., scoping, assessments, etc).
Team member: Jim Coley, RII/DRS (404) 330-2776 SSCs assigned (vertical slice): Unit (s) *, System (s) *,
Train (s) *,
1
-Structure (s) *, and Component (s)
- i J
i' Selected programatic reviews (i.e., scoping, assessments, etc).
Team member (PRA): Walt Rogers, RII/NRR (301) 415-2682 Assigned:
PRA/IPE assessment on the following SSCs
- Selected programatic reviews (i.e., risk ranking, expert panel, etc).
Team member (PRA): Jeff Shackelford, NRR (301) 415-2682 Assigned:' PRA/IPE assessment on the following SSCs
- Selected programatic reviews (i.e., risk ranking, expert panel, etc).
A observers:
NRR/HQMB observer - Tom Bergman, NRR/HQMB (301) 415-1021 NRR/HQM8 observer: Ron Frahm Jr., NRR/HQMB (301) 415-2986 NRR/HQMB observer: Don Taylor, RII/NRR (540) 894-5421 NRR PRA Contractor - Steve lyde Specific unit (s), system (s), train (s), structure (s), and component (s) will be identified by the team leader during the preparation phase of the inspection and assigned to each inspector.
These selected inspection samples will be designated based on current and historical performance, risk significance, and appropriate distribution of samples to cover both safety and non-safety related elements.
Inspection Review / Question Sheets will be used by each. inspector to complete each assigned inspection area.
In addition, general inspection guidance for the inspection of structures is contained in Tab F. " Structural Inspection Guidance' and for risk is contained in Tab R, " Risk Inspection Guidance." The NRR/HQMB observer expected conduct is contained in Tab S. " Maintenance Rule NRR Observer Conduct."
After insp'ection assignments have been made by the team leader, each inspector will use the appropriate guidance, checklist, and data sheets contained in several Tabs in the inspection plan notebook to complete the assignment.
7
t hlq VIII. Loaistics The St. Lucie site is approximately 40 miles North of West Palm Beach, FL.
Team members should make travel arrangements that support arrival at the site by 7:30 a.m. Monday, September 16, 1996. A map to the site is provided as Tab D.
The major airport nearest to the plant site is Palm Beach International
^
Airport. Motels in the area include the following: Holiday Inn, Hutchinson Island, Jensen Beach, FL - (407) 225-3000; Courtyard by Marrictt, Hutchinson Island, Jensen Beach, FL - (407) 229-1000.
Team members shall submit their request for orders, make their own motel and travel reservations and notify the team leader of their agenda. The per dies rate for St. Lucie depends on i
which county your lodging is in. For St. Lucie County the per diem is $52 for lodging and $26 for M&IE (Total 578).
For Martin County the per diem is $66 for lodging and $30 for M&IE (Total-596).
Travelers need to coordinate their
- travel plans to limit the number of rental cars going to/from the plant. At i
least two NRC travelers should be traveling to/from the plant in each rental
.}
car. Team members should arrive and depart at times suitable to support the team's objectives, possible after hour meetings, and to the inspectors _ liking i
provided they remain cognizant of rental car use and coordinate their schedules with the team leader.
i IX, inspection Documentation During the inspection, all potential findings will be documented and provided to the team leader on a copy of the Inspection Finding Form included as Tab G.
These completed forms are expected to be given to the team leader prior to discussion at the daily team meetings.
NRC Manual Chapter 0610 contains general guidance with regard to written input for the final inspection report. An outline of the final inspection report has been provided as part of the inspection plan notebook Tab E, " Maintenance Rule Baseline Inspection Outline."
In addition, the Maintenance Rule Team Inspection conducted at Palo Verde in July 1996, will be used as an example report.
l Each team member will be given the responsibility for writing assigned sections of the report and documenting.the findings related to the SSCs the inspector was assigned to perform a vertical slice. Draft inspection report 3
input should be submitted to the team leader on or before September 25, 1996, which is the Wednesday following the inspection (exit).
Please provide input l
in a word perfect.5.0 or 5.1 file, via e-mail to Bill Holland (E-mail, WEH).
X.
RITS Information insoectors
. Inspection Report Number: 50-335/96-13, 50-389/96-13 IMI Code: IENG IPE Code: RT Inspection Procedure: Reference IP 62706
i 8
- j
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A.
1 July 31, 1995
] '*
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I' PRELIMINARY NOTIFICATION OF EVENT OR UNUSUAL OCCURRENCE PNO-II-95-046 10 7
Thic preliminary notification. constitutes EARLY notice of events of POSSIBLE cofcty or public interest significance. The information is as initially
,rcc31ved without verification or evaluation, and is basically all that is
._.kn:wn by Region II staf.f (Atlanta, Georgia) on this date.-
y Facility Licaanse N-eaency Classification
' Florida Power & Light Co.
X Notification of Unusual Event Turkey Point 3 4 Alert MiCEi, Florida Site Area Emergency-j ' Dockets:'50-250,50-251 General Emergency Not Applicable i
j Flcrida Power.& Light Co.
1 Scint'Lucie:1 2 Flcrida Dockets: 50-335,50-389
(
Subject:
HURRICANE WARNING FOR TROPICAL STORM ERIN 1
~At Ebout'11:30 a.m., July 31, 1995, Florida Power and Light Company d:clared a Notification of. Unusual Event at both their Turkey Point and St.-Lucie sites-upon the declaration of a Hurricane Warning'for.
'ccutheastern Florida.
The facilities are. reviewing their procedures and fccility status while making preparations for the pending storm. Both
'. units at St. Lucia and Turkey Point are at 100 percent power.
R:gion II has dispatched the Emergency Response Vehicle (ERV) and support ctaff to Florida and-continues to track the storm in the Incident I
RIcponse Center. The ERV contains emergency communicating equipment.and personnel supplies.
.This information was received.by telephone from the NRC Resident
~Inzpectors onsite at Turkey Point and St. Lucia and is current as of 1:00
- p.m.
Th3 State of. Florida has been notified.
Contact:
A. BELISLE.
.(404)331-4196 i
i
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'" ~ ^ ' '
1 H
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![
d August
_1, 1995 PRELIMINARY NOTIFICATION OF BYENT OR UNUSUAL OCCURRENCE PNO-II-95-046A l
This preliminary. notification 4.onstitutes EARLY notice of events of POSSIBLE
~ccfety or public: interest signAficance. The information is as initially received without verification or'avaluation, and is basically all that is on.this-date.
known by Region II staff-(Atlanta, Georgia).
Facility Lie===ee Emeraency Classification-1 Florida Power & Light Co.
X Notification of Unusual Event Turkey Point.3 4 Alert
' Site Area Emergency
' Miami, Florida-
' General Emergency Dockets: 50-250,50-251-Not Applicable Florida Power & Light Co.
' Saint Lucie:1 2 Florida
. Dockets: 50-335,50-389
Subject:
HURRICANE ERIN At 11:00 p.m. on' July 31, 1995, Tropical Storm Erin was upgraded to a hurricane.
Both Turkey Point and St. Lucie sites continued to make prsparations for the hurricane.
St. Lucie-Unit 2 is being shutdown in j
anticipation of the hurricane.
Both units at Turkey Point are at 100%
power.
Region II personnel have arrived in Florida to augment the Turkey Point
'R00ident staff.
The Emergency Response Vehicle has also arrrived in Florida and is prepared to respond as needed.
The Region II State Agreement Officer has departed the Atlanta area for the State Emergency Crnter in Tallahassee, Florida.
R gion II personnel closely tracked Hurricane Erin's progress throughout tho evening from the Incident Response Center.
Hurricane Erin is located'at latitude 24.3 and longitude 76.00 as of 4
5:00 a.m.,TAugust 1, 1995.
The Turkey Point plant is located at latitude 25.4 and longitude 80.4.
The licenset is expecting hurricane winds at aidnight tonight at the Turkey Point site and is making preparations for l
the hurricane.
All four emergency diesels have been tested and two cperating crews designated to be on shift'during the passing of the hurricane have been conducting. simulator training for anticipated cc0narios.
'This'information-was received by telephone from the-NRC Resident In2pectors onsite at Turkey Point and St.' Lucia and-is current as of 8:30 i
i
.a.C.
j Ths State of Florida has been notified.
Contact:
~
A. BELISLE '
_(404)331-4196 Jf
/$
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tj - August 1,J1995' PRELM m *Y NOTIFICATION OF EVENT OR UNUSUAL' OCCURRENCE PNO-II-95-046B 4
Thio preliminary notification constitutes EARLY notice of events of.POSSIBLE
- -
- cafety or public interest significance. The information is as initially rcc31ved'without verification or evaluation, and is basically all that is
~
known by Region II~ staff-(Atlanta, Georgia) on this date.
Facility Lio==mee raency Classification Flcrida Power & Light Co.
X Notification of Unusual Event
'l ' Turkey Point 3 4 Alert i
].'Mic31, Florida Site Area' Emergency.
4 Dockets: 50-250,50-251
. General Emergency-
.l 4
Not Applicable 1. Florida Power &. Light Co.
)
Saint Lucie:12 f
Florida 4
' Dockets: 50-335,50-389
Subject:
HURRICANE ERIN j
f Hurricans' Erin is located at latitude 26.3 and longitude 77.7 as of L
2300 p.m.,
August 1, 1995.
The Turkey. Point plant is located at latitude-
- 25.4.and longitude 80.4..
The licensee is not projecting hurricane winds Et the Turkey Point site.
Both units at Turkey Point are at 100% power.
St. Lucie is located at 27.3. latitude and-80.4 longitude.
Both St. Lucia j
!7 units are being shutdown in anticipation of the. hurricane.
Unit 2 is in Hat. Standby Mode and Unit 1 is currently offline. ~Both units are proceeding to Hot Shutdown.
ii R::gion II personnel have arrived in Florida to augment the Resident l'
.ctaff.
The Emergency Response Vehicle has arrived at the St. Lucie site.
Tho Region II State Agreement Officer is at the State Emergency Center in Tallahassee, Florida.
I
-R gion II personnel are closely tracking Hurricane Erin's progress 1-thrsughout from the Incident Response Center.
This information was received by telephone from the NRC Resident In !pectors onsite at Turkey Point and St.- Lucie and,is current as of 2130 p.m.
'Tho State of Florida has been notified.
t Cantact:
=A.
BELISLE (404)331-4196 j
o f -
e
2
-?
i g,[ : :. August
.1, 1995.
1 PRELIMINARY NOTIFICATION OF EVENT OR UNUSUAL OCCURRENCE PNO-II-95-046C Thic preliminary notification constitutes EARLY notice of events of POSSIBLE acfsty;or;public. interest significance. The information.is as initially I
' received:without verification or evaluation,'and is basically all~that is known by Region.II staff-(Atlanta, Georgia) on this date.
i Facility Licensee Emergency Classification
]
L Flcrida Power & Light'Co.
X Notification of Unusual Event-Turkey Point'3 4 Alert Mic:21, Florida.
Site Area Emergency i
[f Dockets: 50-250,50-251 General Emergency
.l l
Not Applicable
!!?[. Florida Power & Light Co.
il Saint Lucia.1 2 U
Florida-LDockets: 50-335,50-389 jj
Subject:
HURRICANE ERIN - REGION II ACTIVATES INCIDENT-RESPONSE CENTER g-
!!.As of 9:00 p.m. Region II activated the Incident Response Center.
lj -Hurricane Erin is located at 26.7 latitude and 78.7 longitude as of
- i' 8300 p.m.,' August 1, 1995.
St.. Lucia is located at 27'3 latitude and 80.4 longitude.
Both St. Lucie units are shutdown in anticipation of the hurricane.
The licensee at St. Lucia has implemented their emergency
- : procedures and have established additional shift staffing.
Non essential E
p rconnel have been sent home.
Hurricane winds are anticipated onsite at p.
cbsut 11:00 p.m.
Currently St. Lucia is experiencing approximately d
40 mph winds.
!i The Hurricane Warning has been cancelled for Dade' County as of 8:00 p.m.
On August 1, 1995.
Upon arrival ~of hurricane winds at St. Lucie, an open communication line will be established between St. Lucia site, the Florida Power and Light's E3rgency Offsite Facility in Miami, NRC Headquarters, and the Region II Incident Response Center.
I
.R gion II personnel are at St. Lucie to augment the Resident staff.
The R2gion II State Agreement Officer is at the State Emergency Center in
=
Tallahassee, Florida.
A Region II manager is at the Emergency Offsite Fccility in Miami.
l Thio'information was received by telephone from the NRC Resident Intpactors onsite'at St. Lucie-and is current as of 9:00 p.m.
hTh3StateofFloridahasbeennotified.'
b
Contact:
A. BELISLE (404)331-4196 ol' 6-u,
<?.
2.
, 3 7, i
t,f.
_j
.. August 2,
1995 PARLIMINARY NOTIFICATION OF EVENT OR UNUSUAL OCCURRENCE PNO-II-95-046D 3.}
This preliminary' notification constitutes EARLY notice of events of POSSIBLE
'j cofety or public interest significance. The information is as initially
- received without verification or evaluation, and. is basically.all that is
-]
known by Region II staff (Atlanta,' Georgia) on this date.
i Facility Licensee Emergency Classification i
Florida Power'& Light Co.
Notification of Unusual Event ii Turkey Point ~3 4~
Alert i
Site Area Emergency jj Micni, Florida-General Emergency Dockets:
X Not. Applicable 50-250,50-251
'J 1
1 Florida. Power & Light Co.
d
.Scint Lucie 1 2 4I Florida'
,j Dockets:- 50-335,50-389
- 1 Florida' Power Corporation l4
. Crystal River 3 13-Crystal River, Florida
- }
Dockets: 50-302 i'
Subject:
HURRICANE ERIN Il Region II monitored the progress of Hurricane Erin throughout the cl evcning. At'10:50 p.m. on August 1, 1995, an open communications line was cctablished among the St. Lucie Site, the Florida Power and Light Company
[
En rgency offsite facility, Nuclear Regulatory Commission Headquarters cnd Region II Incident Reponse Center.
In anticipation of the storm's F
crrival, St. Lucie Units l'and 2 were placed-in Mode 3 by 3:00 p.m. on August 1, 1995.
Hurricane Erin came ashore about 20 miles north of the
.q
.St.-Lucie Plant at 2:00 a.m. August 2, 1995. Maximum wind speed at the j1
'St. Lucie site was approximately 40 mph.
On-site damage assessments were conducted at 4:00 a.m. with no damage noted.
Off-site damage assessment 4
W 10 underway.
i]
Tho storm is expected to pass almost directly over Crystal River around j
nosn today.
The Crystal River Technical Support Center has been staffed cince about 3:00 a.m. and has-maintained an open line of communication j~.with the NRC since that time.
The; Senior Resident Inspector is on site and monitoring licensee activities.
Tho 5:00 a.m. report from the National Weather Service downgraded the 1
hurricane to.a tropical storm and discontinued all hurricane warnings.
St. Lucie secured from an Unusual Event at 5:42 a.m.
Region II continues
- i. to monitor conditions at Crystal River.
This.'information is current as of 7:00 a.m.
Cantact:.
E. Marschoff
-(404)331-5089 1
k) { f/
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fe
-l-August 2,
1995
\\
PRELIMINARY NOTIFICATION OF EVENT OR UNU8UAL OCCURRENCE PNO-II-95-046E c
1 This prelimin.ary notification constitutes EARLY notice of events of POSSIBLE
. ~cafety or public interest significance. The information is as initially' r ceived without verification or evaluation, and is basically all that is i
1 kn:wn by' Region II staff (Atlanta, Georgia) on this date.
]
Facility Licensee Eneraency Classification Florida Power & Light Co.
Notification of Unusual Event a
Turkey Point 3 4 Alert 1 Micni, Florida Site Area Emergency 7 50-250,50-251 General Emergency-1 Dockets:
X Not Applicable o
, Florida Power & Light Co.
b Saint' Lucia 1.2 Florida Dockets: 50-335,50-389 i ;
Florida Power Corporation Crystal River 3 Crystal River, Florida Dockets: 50-302 j
Subject:
HURRICANE ERIN k
Rrgion II exited the Monitoring Mode'for Hurricane Erin at 8:30 a.m. on j : August 2,-1995.
Hurricane Erin was downgraded to a tropical storm in.the
- j. 5:00 a.m. report from the National Weather Service.
i i.!
Tho storm-has passed the Crystal River facility and entered the Gulf of I
Msxico.
Maximum winds experienced at Crystal River were approximately i
l 45 mph.
g Tho St. Lucie plant has verified there is no significant storm related denage either to the facility or on Hutchinson Island.
Evacuation routes
{
ora open and clear.
All 85 emergency notification sirens have been j
cuccessfully tested and the full staff is available onsite.
Florida 4
1 P:wer and Light plans to restart Unit 1_this afternoon, and Unit 2 this j
ovaning.
5 Ecgion II is continuing to track the progress of the storm, and Resident Inapactors are onsite at both Crystal River and St. Lucie monitoring licensee activities.
3-Tha State of Florida has been notified.
This information is current as of 1:00 p.m.
- l' Ccntact:
A. Belisle (404)331-4196
/
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1 f
POWER REACTOR" EVENT NUMBER:
29152 FACILITY: SAINT 11iCIE REGION:
2 NOTIFICATION DATE: 08/02/95
'~
'1 UNIT:.
[1] [] []
STATE: FL NOTIFICATION TIME: 21:58 [ET) i~
RX TYPE:.'[1] CE, [2] - CE EVENT DATE:
08/02/95 i
la EVENT TIME:
19:00(EDT]
I NRC NOTIFIED BY: SNYDER LAST UPDATE DATE:
08/02/95 HQ OPS OFFICER:
TIM McGINTY J
NOTIFICATIONS I
EMERGENCY CLASS: NOT APPLICABLE 10 CFR SECTION:
CHARLES CASTO RDO 1
- )<
AESF 50.72 (b) (2) (ii)
ESF ACTUATION BRUCE BOGER EO i.
i i
l 4
q.
]
UNIT SCRAM CODE RX CRIT INIT PWR INIT RX MODE CURR PWR CURR RX MODE
,J
j OTHER THREE RCP'S REMAIN IN OPERATION.
THE LICENSEE HAS NOTIFIED THE STATE AND LOCAL AGENCIES AND THE RESIDENT INSPECTOR.
UNIT 1 HAS A 1 gpm UNIDENTIFIED LEAKAGE AND 10 gpm IDENTIFIED LEAKAGE ALLOWABLE TECH SPEC, AND THUS THE UE DECLARATION IS PRECAUTIONARY.
A PRIMARY COOLANT SYSTEM SAMPLE DRAWN TODAY WAS NORMAL AT 0.15 2
micro-curies /ml.
THE CONTAINMENT RADIATION GASEOUS MONITORING SHOWS A VERY
~
. SLIGHT-INCREASE IN LEVELS.
SEE RELATED EVENT #29152.
i
,.5
- August 3,
1995 PEELIMINARY NOTIFICATION OF EVENT OR UNUSUAL OCCURRENCE PNO-II-95-047
' Thio preliminary notification constitutes EARLY notice of events of POSSIBLE cafety or public interest significance. The information is as initially 3,
ji r:coived without verification or evaluation, and is basically all that is known.by Region II staff-(Atlanta, Georgia) on this date.
Facility L$censee Emercanov Classification J
Flcrida Power & Light Co.
X Notification of Unusual Event Saint Lucia 1 Alert Hutchinson Island, Florida Site Area Enargency
.. Dockets: 50-335 General Emergency ji Not Applicable a
Subject:
STARTUP OF ST. LUCIE UNIT 1 POSTPONED TO REPAIR PUMP SEAL On August 2, 1995, at 9:25 p.m. (EDT) St. Lucie Unit 1 declared an.
'linunual Event due to a 2 GPM leak from the 1A2 reactor coolant pump seal E
y" to the containment sump.
(See Event Number 29153.) Unit 1 is being cooled down to Mode 5 and depressurized for repairs.. At the time of this event, Unit 1 was shut down in Mode 3 preparing for restart after Hurricane Erin had passed.
The licensee estimates the outage duration to be about seven days.
The NRC resident inspectors are following the ev0nt.
i.
j Th3 State of Florida has been notified of this event.
Th3 NRC received notification of this event at 9:58 p.m.
(EDT) on August 2 by phone call to the NRC duty officer.
Thio information is current as of 9:30 a.m. on August 3, 1995.
Ccntact:
R. SCHIN j
(404)331-5561 4
nn
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s
. _ ~......
lf' 17 y
[
DRP ONE-LINERS
{
Date:
Friday, August 4, 1995 u
i l
.- l.
~ Florida Power antt ' Licht Cnennany - St. Lucie,
~
During July 31 through August 2, Hurricane Erin approached 3
i south Florida and then passed over the St. 'Lucie nuclear plant (See Events Number 29137, 29138, and 29148; PNs number II ~
.046,
- 046A, 046B, 046C,. 046D, and 046E).
Following the t
Hurricane,-St. Lucie 2 will remain shut down for about seven l
a
- days to repair an RCP seal (See Events Number 29152 and 29153; PN number II-95-047).
I i
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a
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1
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-]
i e
POWER REACTOR EVENT NUMBER:
29137 FACILITY: TURKEY POINT REGION:
2 NOTIFICATION DATE: 07/31/95 UNIT:
[3] [4] []
STATE: FL NOTIFICATION TIME: 11:45 [ET]
RX TYPE: [3] W-3-LP,[4] W-3-LP EVENT DATE:
07/31/95 EVENT TIME:
11:25[EDT]
NRC NOTIFIED BY: RICK ADAMSON LAST UPDATE DATE:
07/31/95 HQ OPS OFFICER:
JOSEPH SEBROSKY NOTIFICATIONS' EMERGENCY CLASS: UNUSUAL EVENT 10 CFR SECTION:
THOMAS PEEBLES RDO AAEC 50.72 (a) (1) (i)
EMERGENCY DECLARED AL CHAFFEE EO AUSTIN FEMA l
UNIT SCRAM CODE RX CRIT INIT PWR INIT RX MODE CURR PWR CURR RX MODE 3
N Y
100 POWER OPERATION 100 POWER OPERATION 4
N Y
100 POWER OPERATION 100 POWER OPERATION EVENT TEXT UNUSUAL EVENT DECLARED DUE TO A HURRICANE WARNING BEING POSTED FOR THE 1
AREA.
i ALL EMERGENCY CORE COOLING SYSTEMS AND EMERGENCY DIESEL GENERATORS (EDGs)
ARE OPERABLE.
THE LICENSEE PLANS TO TEST THE EDGs LATER TODAY DUE TO THE d:
HURRICANE.
THE LICENSEE WILL EXIT THE UNUSUAL EVENT WHEN THE HURRICANE WARNING FOR THEIR AREA IS NO LONGER IN EFFECT.
THE LICENSEE HAS INFORMED THE RESIDENT INSPECTOR, STATE OFFICIALS, AND LOCAL OFFICIALS IN ACCORDANCE WITH THEIR EMERGENCY PLAN.
NOTE:
SEE EVENT #29138 FOR A RELATED EVENT.
i d
J
_.... ~._.. _. _..
.4 1M' i
'l
!I.
POWER l REACTOR EVENT NUMBER:
29138 FACILITY: ' SAINT LUCIE-REGION:
2 NOTIFICMION DATE: 07/31/95 UNIT:-
[1] :(2) -[ ]
STATE: FL NOTIFICATION TIME: 11:48 [ET]
i RX TYPE:. [1] CE, [2] CE EVENT DATE:
07/31/95 EVENT TIME:
11:28[EDT]
i NRC NOTIFIED BY: SCISCENTE LAST_ UPDATE DATE:
07/31/95 HQ OPS OFFICER:
DICK JOLLIFFE
)
NOTIFICATIONS 1
EMERGENCY CLASS: UNUSUAL EVENT j
10 CFR SECTION:
THOMAS PEEBLES RDO j
AAEC 50.72 (a) (1) (i).
EMERGENCY DECLARED AL CHAFFEE, NRR EO AUSTIN FEMA s
UNIT SCRAM CODE RX CRIT INIT PWR INIT RX MODE CURR PWR CURR RX MODE
.1 N
Y 100.-
POWER OPERATION 100 POWER OPERATION
?
2 N
Y 100 POWER OPERATION 100 POWER OPERATION j
EVENT TEXT
- UNUSUAL EVENT DECLARED DUE TO HURRICANE WARNING (TROPICAL STORM ERIN)
LICENSEE HAS DECLARED AN UNUSUAL EVENT DUE TO A CONFIRMED HURRICANE WARNING FOR THE EAST COAST OF FLORIDA FROM SEBASTIAN INLET SOUTHWARD THROUGHOUT THE p
.l.
FLORIDA KEYS DUE TO TROPICAL STORM ERIN (PRESENTLY LOCATED APPROXIMATELY 4
400 MILES EAST-SOUTHEAST OF FLORIDA) AND IS IMPLEMENTING THEIR SEVERE WEATHER PREPARATION PROCEDURE.
ALL EMERGENCY DIESEL GENERATORS AND ALL EMERGENCY CORE COOLING SYSTEMS ARE OPERABLE ON BOTH UNITS.
- l-'
LICENSEE NOTIFIED STATE OFFICIALS AND THE NRC RESIDENT INSPECTOR AND WILL NOTIFY OTHER GOVERNMENT AGENCIES AND LOCAL OFFICIALS AND WILL ISSUE A PRESS f
RELEASE.
t i
NOTE: 'SEE EVENT #29137 FOR A RELATED EVENT.
f
N
,3 POWER REACTOR EVENT NUMBER:.29148 i
FACILITY: SAIL-LUCIE REGION:
2 NOTIFICATICN DATE: 08/01/95 UNIT:
[1] [2] [ ]
STATE: FL NOTIFICATION TIME: 23:36 [ET]
RX TYPE: '[1] CE,- [2 ] CE EVENT DATE:
08/01/95 i
EVENT TIME:
23 :23 [EDT]
LAST UPDATE DATE:
08/01/95 NRC NOTIFIED BY: WOLAVER-i HQ OPS OFFICER:
TIM McGINTY NOTIFICATIONS EMERGENCY CLASS: NOT APPLICABLE 10 CFR SECTION:
REYES RDO t
i DDDD 73.71-UNSPECIFIED PARAGRAPH a.
4 f
UNIT SCRAM CODE RX CRIT INIT PWR INIT RX MODE CURR PWR CURR RX MODE 1
N N
0 HOT STAUDBY 0
HOT STANDBY l
2 N
N O
HOT STANDBY 0
HOT STANDBY
]
f i
EVENT TEXT i
THE LICENSEE REPORTED A PARTIAL' SUSPENSION OF SAFEGUARDS DUE TO THE HURRICANE AND CONCERNS'FOR PERSONNEL SAFETY.
THE HOO LOG CONTAINS l.
' ADDITIONAL DETAILS REGARDING THE REPORT. THE LICENSEE WILL RE-ESTABLISH FULL CAPABILITY AS SOON AS CONDITIONS ALLOW.
THE RESIDENT INSPECTOR HAS BEEN INFORMED.
- l t
a p
G i
?
- - - - - - - - - - - _ _ _ _ _ _. _ _. _, _ _ _ _. _, _ _ _ _ _,