ML20141C813
| ML20141C813 | |
| Person / Time | |
|---|---|
| Site: | Crystal River  |
| Issue date: | 03/27/1996 |
| From: | Landis K NRC OFFICE OF INSPECTION & ENFORCEMENT (IE REGION II) |
| To: | Beard P FLORIDA POWER CORP. |
| Shared Package | |
| ML20141C820 | List: |
| References | |
| FOIA-96-485 NUDOCS 9705190230 | |
| Download: ML20141C813 (88) | |
Text
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UNITED STATES NUCLEAR REGULATORY COMMISSION
, 'y "
REGloN 11 101 MARIETTA STREET. N.W.. SUITE 2900 3 ATLANTA, GEORGIA Mm2H199 -
/ March 27, 1996 Florida- Power Corporation Crystal River Energy Complex j Mr._P. M. Beard, Jr. (SA2A)--
Sr. VP,' Nuclear-Operations ATTN: Mgr., Nuclear Licensing.
l 15760 West Power Line Street ,
Crystal River, FL 34428-6708 I
1
SUBJECT:
PLANT PERFORMANCE REVIEW (PPR).- CRYSTAL. RIVER 3 i
Gentlemen: l
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- On February 28, 1996, the regional staff completed the semiannual Plant
' Performance Review (PPR) of Crystal River 3. .The staff conducts these reviews
! for all operating nuclear power plants to. develop an integrated understanding- l 1 of safety performance. The results are used by regional management to j facilitate planning and allocation of inspection resources. The PPR for Crystal River 3. involved the-participation of all technical divisions in
~
evaluating inspection results and safety performance information for the-period ~ September 1995 through February 1996. PPRs provide regional management with a current summary of licensee performance and serve as inputs to the NRC
. Systematic Assessment of Licensee Performance (SALP) and senior management meeting (SMM) reviews.
This letter advises you of our planned inspection effort resulting from the Crystal River 3 PPR review. It is provided to minimize.the resource impact on your staff and to allow for scheduling conflicts and personnel availability to be resolved in advance of inspector arrival onsite. The enclosure details our inspection plan for the next six (6) months. The rationale or basis for each I inspection outside the core inspection program.is provided so that you are aware of the reasons for emphasis in these program areas. Resident inspections are not listed due to their ongoing and continuous nature.
I During each NRC inspection planned .during this period, specific attention will be given to the verification of selected UFSAR commitments. Applicable !
portion (s) of the UFSAR that relate to the inspection activities will be ;
reviewed-and verificatlun made that the.UFSAR commitments have been properly implemented into plant practices, procedures and/or parameters. The goal is to determine the accuracy of the UFSAR'regarding-existing plant practices and conditions by providing specific attention to the UFSAR when performing various reactor inspections. Inspectors will not be judging.the overall completeness of the UFSAR; rather, the inspections will focus on identifying differences between the UFSAR descr.iption and the plant.
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BINDER 96-485 PDR .
FPC 2 We will inform you of.any changes to the inspection plan. If you have any questions, please contact Kerry Landis at 404-331-5509.
Sincerely, Kerry Lan s, Chief React Projects Branch 3 Division of Reactor Projects Docket No. 50-302
~ License Nos. OPR-72
Enclosure:
Inspection Plan cc w/ encl:
Gary L. Boldt, Vice President Nuclear Production (SA2C)
Florida Power Corporation Crystal River Energy Complex 15760 West Power Line Street Crystal River, FL 34428-6708 B. J. Hickle, Director Nuclear Plant Operations (NA2C)
Florida Power Corporation Crystal River Energy Complex 15760 West Power Line Street Crystal River, FL 34428-6708 ;
L. C. Kelley, Director (SA2A) !
Nuclear Operations Site Support Florida Power Corporation Crystal River Energy Complex 15760 West Power Line Street Crystal River, FL 34428-6708 Rodney E. Gaddy Corporate Counsel Florida Power Corporation MAC - ASA P. O. Box 14042 St. Petersburg, FL 33733 Attorney General Department of Legal Affairs The Capitol Tallahassee, FL 32304 cc: Continued see page 3
1:
l FPC' 3 i cc: Continued a
Bill Passetti i
- Office of Radiation Control l Department of Health and Rehabilitative Services 4
1317 Winewood Boulevard
- Tallahassee, FL 32399-0700 l' ' Joe Myers, Director
. Division of Emergency Preparedness Department of Community Affairs 2740 Centerview Drive Tallahassee, FL 32399-2100 Chairman Board of County Commissioners
' Citrus County ;
. 110 N. Apopka Avenue 1 Inverness, FL 34450-4245 Robert B. Borsum B&W Nuclear Technologies ;
i 1700 Rockville Pike, Suite 525 Rockville, MD 20852-1631 4
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CRYSTAL RIVER INSPECTION PLAN i
INSPECTION NUMER OF- PLAMED TYPE OF INSPECTION - COMENTS
- PROCEDURE / TITLE /PROGRAR AREA INSPECTORS INSPECTION TEMPORARY DATES INSTRUCTION .
t l INITIAL OPERATOR EXAMINATION 3 03/11/96 PREPARATION l
IP 73753 INSERVICE INSPECTION 1 -03/11/96 ISI - REACTOR VESSEL 10 YEAR ISI.
SERGE LINE FLAW. HPI N0ZZLES ;
INSPECTION .!
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, INSPECTION) SG INSPECTION, SG TUBE ISSUES IP 92702 FOLLOWUP ON CORRECTIVE ACTIONS FOR 1 3/I8/96 SETPOINTS VIOLATIONS AND DEVIATIONS f
IP 83750 OCCUPATIONAL RADIATION EXPOSURE 1 03/18/96 RP CORE INSPECTION IP 81700 PHYSICAL SECURITY PROGRAM FOR POWER 1 03/18/96 SAFEGUARDS REACTORS INITIAL OPERATOR EXAM 3 03/25/96 ADMINISTER EXAMINATION IP 92703 FOLLOWUP - ENGINEERING 3 04/08/96 CCHE REGIONAL INITIATIVE IF 92720 CORRECTIVE ACTIONS CORRECTIVE ACTION _ PROGRAM i IP 71500 BALANCE OF PLANT INSPECTION 1 04/08/96 MAINTENANCE TO SUPPORT 24 NONTH REFUELING INTERVAL IP 62700 MAINTENANCE PROGRAM IMPLEMENTATION IP 37550 ENGINEERING 2 04/22/96 CORE INSPECTION - FOCUS ON 50.72s/LERs, OPERABILITY, 50.59 EVALUATIONS, ENGINEERING SUPPORT TO OPS AND MAINT, SELF ASSESSMENT. ELECTRICAL MODIFICATIONS
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2 INSPECTION NUMBER 0F PUUglED TYPE OF INSPECTI0ll - ColWlENTS PROCEDURE / TITLE / PROGRAM AREA INSPECTORS INSPECTION TEMPORARY DATES .
INSTRUCTION IP 61726 SURVEILLANCE OBSERVATIONS 1 05/20/96 CORE INSPECTION IP 62703 MAINTENANCE OBSERVATIONS IP 37550 ENGINEERING 1 06/10/96 DESIGN BASIS & OPERA 8ILITY.
SUPPORT TO OPS AND MAINT IP 71500 BALANCE OF PLANT INSPECTION 1 06/24/96 NEW PROCEDURES TO SUPPORT 24 MONTH REFUELING INTERVAL IP 62700 MAINTENANCE PROGRAM IMPLEMENTATION IP 73753 INSERVICE INSPECTION (INTEGRATED SG 2 07/08/ % REGIONAL INITIATIVE - INTEGRATED INSPECTION) SG INSPECTION, SG TUBE ISSUES IP 92720 CORRECTIVE ACTIONS 3 07/15/96 CAP IP 81700 PHYSICAL SECURITY PROGRAM FOR POWER 1 07/22/96 SAFEGUARDS - REGIONAL INITIATIVE REACTORS IP 93808 INTEGRATED PERFORMANCE ASSESSMENT 5 07/22/96 IPAP PREP DNSITE PROCESS (IPAP) 07/29/96 IPAP PREP ONSITE 08/19/96 IPAP INSPECTION 08/26/96 IPAP INSPECTION IP 92702 FOLLOWUP ON CORRECTIVE ACTIONS FOR 1 09/16/96 SET POINTS & MAKEUP TANK CURVE VIOLATIONS AND DEVIATIONS IP 61726 SURVEILLANCE OBSERVATIONS I 09/16/96 CORE INSPECTION IP 62703 MAINTENANCE OBSERVATIONS IP 92903 FOLLOWUP - ENGINEERING 1 09/23/96 SERVICE WATER FOLLOWUP
, IP 42001 EMERGENCY OPERATING PROCEDURES 3 10/07/96 E0P UPGRADE PROGRAM INSPECTION IP 71500 BALANCE'0F PLANT INSPECTION 1 10/17/96 NEW PROCEDURES TO SUPPORT 24 MONTH REFUELING INTERVAL IP 62700 MAINTENANCE PROGRAM IMPLEMENTATION
, i 3
INSPECTION NUMBER OF PLA MED TYPE OF INSPECTION - COMENTS PROCEDURE / TITLE /PROGRAN AREA INSPECTORS INSPECTION TEMPORARY DATES !
INSTRUCTION
[
IP 82301 EVALUATION OF EXERCISES FOR POWER' 3 10/16/96 CORE INSPECTION REACTORS IP 82302 REVIEW OF EXERCISE OBJECTIVES AND i SCENARIOS FOR POWER REACTORS IP 71001 LICENSED OPERATOR REQUALIFICATION 2 11/04/96 OPERATOR REQUALIFICATION PROGRAN EVALUATION u
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SENIOR MANAGEMENT BRIEFING - ST LUCIE A. Plant Performance (See Attached Performance Power Profiles)
The unit was shutdown on August 1,1995, as a result of Hurricane Erin. A series of problems including RCP seal failure, both PORVs inoperable due to incorrect assembly, SDC relief valve problems, associated proble,m with several other relief valves, inadvertent spraydown of the containment, catastrophic piston failure on IB emergency diesel generator, and a leaking flange on a pressurizer safety valve have prevented the unit from restarting. With the unit down the licensee planned to coact a large number of operator-work-arounds and other plant deficiencies.' The next refueling outage is scheduled for April 4, 1996.
Unit 2 was shutdown on April 25, 1905, for approximately seven hours to replace a main turbine digital electro hydraulic power supply. Unit 2 was shutdown on August I as a result of Hurricane Erin and restarted on August
- 4. The refueling outage began October 9 and was expanded from 30 to 48 days.
B. A S_A1E SALP endina January 1994 SALP endina May 1992
. Operations 1 1 Maintenance 1 1 Engineering 1 1 Plant Support 1 Rad. Con. 1 Security 1 Emerg. Prep. 1 SA/QV 1 C. INPO INP0 assessment July 1995 - Category 1 INP0/WAN0 assessment April 1994 - Category 1 D. Precursor Events None E. PRA Insichts ,
CE 2 loop plant Internal CDF - 2.6E-6 Containment Type - Dry, Ambient Pressure Principal Risk Contributor - LOCA 49%
Transients 20%
SB0 10%
IPEEE Submittal Date - Unit 1: December 1994 (Non-seismic), September 1992 (Seismic); Unit 2: February 1995 (Seismic)
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f Enforcement History l
! No escalated enforcement in 1994. Enforcement conference on inoperable J
PZR PORV, September 25, 1995, with SLIII and base CP yet to be, issued.
Pending escalated enforcement on SDC relief valve lift with 4000 gallons j of RCS inventory spilled in the pipe tunnel. Enforcement panel is yet to l
, be scheduled.
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j G. Allecation Status -
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- H. Performance Indicators (See Attachedi i
j The previous six months has shown an increase in personnel errors l involving, the failure to follow procedures, inattention to detail, and i
the failure to maintain awareness of equipment status. The above occurrences and events that have taken place since July 1995, indicated a decrease in over all plant performance.
I. PPR Re1ulti _
i 1. Trends - The recent six months has shown an increase in personnel i errors involving the failure to follow procedures, inattention to detail, l failure to maintain awareness of equipment status, and inadequate i procedures. Operations performance overall has declined. Operators l respond well to events but do not always have a questioning attitude, 4 appear to have lapses in procedural use and compliance, and are not
! identifying concerns and holding plant support organizations accountable
! to correct plant deficiencies. The PPR panel agreed that all disciplines j art of each
- should inspection. reviewNRC procedure performed an adequacy Organizational andand management Programmaticoversight as p%Z, j assessment of St Lucie and presented it to the licensee on August 29, i 1995, identifying lack of detail and scope in procedures as the primary j root cause with contribution from lack of management commitment to program j implementation. The licensee performed an internal and independent external assessment and is implemting a corrective action program. The PPR panel agreed that the resident staff should continue to focus on the licensee's corrective action program (CAP). Since most of the licensee's
! CAP is to be completed by the end of 1995, DRS will conduct two weeks of f regional initiative inspection effort to review the CAP by January,1996.
i 2. Planned Inspections (See Attached Letter to Licensee) i 3. Site Integration Matrix (See Attached) 4 j J. Organizational Charts (See Attached) i 1
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MIPC0005 REGION 2 QUARTERLY ACTIVITY SCHEDULE 10/04/95 l SORTED BT FACILITT/ ACTIVITY START DATE PAGE 18 l ACTIVITT FAC ID NAME RESP LEAD TM ACTIVITY 09 ORG EMP SZ TARCT DT OCT 16 23 30 . 06 13 20 27 04 11 18 25 . )
NOV DEC 1 es====s====================== ===== ===== == ======== ===== ===== esses ===== sessa ===== ss=== ses== ===== ===== ===== =====
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5.. 2008 INPO QUTAGE MANAGEME 2201 KDL ~ 9 10/09/95 ***" *"" l STL1 A601 REC INSPECTION 2340 con i 10/16/95 "*" i STL1 5000 END CTCLE 11 0 01/06/% l t
STLt. A754 EP EXERCISE 2340 KFB 1 02/05/96 STL1 A800 FRP CORE (83750) 2340 WGR 1 02/26/96
-sTL1 A837 REC INSPECT!0N 2340 COR 1 02/26/96 STL1' A400 INITIAL PREP 2330 G0H 3 03/11/96 I
STL1 A401 INITIAL EXAM 2330 GON 3 03/25/96 !
STL1 A801 FRP CORE (83750) 2340 WGR 1 06/17/96 !
STL1 A900 SFGOS INSP 2340 1 07/22/96 ,
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Operational Period August 1. !
Tlirongli Sept ernher 12, 199fi 1 2 3 4, 100-: ,
Et; 80 - j.
I.
On October 26, 1994, the unit tripped free !00 percent power due to a !
loss of electrical lead. This was the result of arc-ever in a potential '
M transformer in the switchyard due to salt buildup. The licensee then '
O ' a ad = *a ' ' "'a " "' "* *** "' ' ch * ** **'a ****** ** *** a ar A 60 - days later. The unit was returned to service on November 29.
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- 2. On february 21. 1995, the unit was removed from service for the b replacement of pressurizer code safety valves which had been leaking by - i
.the seat since shortly after startup in November, 1994. The unft ses Z returned to service on March 8.
N 10 - .
o 3. On July 8, 1995, the unit tripped during turbine valve surveillance [
testing. It returned to power on July 12. !
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- 4. On August 1, 1995, the unit was shutdown as a result of Hurricane Erin.
- 4 gn Due to a series of equipment problems and personnel performance fssues,
%U- the unit is presently snetdown.
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PERIOD OF OPERATION ;
i Graph does not include power reductions ;
for routine repair.4, wat erbox cle.aning, or required repairs. :
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Operational l'erioll Augtsst _l, ,, ,
12, 1995 :
Tlirongli Sept eniber 1 2 .
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2 60-
- 1. On February 21, 1995, the unit tripped as a result of low steam ;
p The condition was the result of a feedwater generator water level. regulating valve closure after a steam generator water level controll l
Z level transaltter failed high. The transellter was replaced and the g an 9U- -
tenit was returned to service on February 25. i O -
DC 2. On August I,1995, the unit was shutdown as a result of therricane Erin. It was restarted on August 4, 1995 but.
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PERIOD OF Ol'ERATION o,
O Graph <loes not. include power redtielions 5,-
for rout.ine repairs,' waterbox clearting, & j or required repairs. E 3 j
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October 6, 1995 .
ST LUCIE Site Intearation Matrix Date Salp Ref. Cause IdentiGe4 Description J
F.A.
9/28/95 - MS R 9518 Equipnwn Failum Self Wnufying Laaking PZR SVs exunded forced outage .proWema widi tailpipe alignment.
9/20/95 MS R 95-18 Equipment Failure Self batifying Grounds in EDO l A/lB governor eossal wirieg reauhsd in load oscillations.
I' 9/15/95 OPSI IR 9518 Failure to Follow self Identifying Maint/ Ops did not provide clearnace for work on MS Procedures condenser waterbox cover. Vacuum severed worker's finger.
9/14/95 PS IR 95-18 Failure to Follow Licenace Secunty faile1 to take correct conta y action on Procedure coniputer failure.
9/10/95 OPS IR 9518 Failure to Use Self Identifying SG blowdown sent to incorrect system on RAB roof.
Correct Procedure Operator used wrong procedure. When identiGod did not back out of proceduto corvoedy, 9/9/95 MS IR 95-15 Weakness in Work Self identifying Laak on SV 1201 flange erunded owse, identified Screcrung and one month earlier but not worked.
Planrung 9/7/95 OPS R 95-15 Personnel Error / Licensee Unit 2 Main Generator overpressurized while filling inoperable with H2. Inattention by operators.
EquipmenuOWA 9/2/95 OPS R 95-15 Personnel Error NRC Weaknesses identiGed in logs relating to abnormal VIO 9515 equipment conditions and out of service equipnwas not logged (rnuhiple examples).
8/31/95 MS IR 9515 Personnel Error Self Idenufying Damaged cylinder and head on IB EDG due to loose lash adjustment.
. 8/30/95 PS R 95-15 Management and NRC Containment closure walkdowns by management were i
QC weaknesses inadequate and depended heavily on QC involvement to identify deficiencies.
8/30/95 MS IR 9515 Supervisory NRC Maintenance personnel not using proosdures for work oversight and in progress, worker suitude 8/29/95 OPS R 95-15 Personnel Error Licenace ~ Started IB LPSIpump with sucuon valve closed. (No VIO 9515 damsge to pump) 8/29/95 MS R 9515 Procedure Use NRC Maintenance journeyman not signing off procedure steps as work completed (previously ideati6sd as a weakness in May 1995L 8/23/95 MS R 95-15 Equipment self Identifying 2A HDP trip due to relay failure. Eight HDP tnpo in Failure / past year. Enginsonna solution avasiebie but not inadequate implemented.
Correcuve Achon 8/22/95 PS IR 9515 Personnel Error NRC QA failed to document a deGciency on containment sprey valve surveillance idenufsed in as audit.
8/19/95 OPS R 95-'15 Operator Error / Self Identifying verGIlof PWF. Spilled approx.10K gallons on Operator ground inside RCA. Opernaar work anseed on level Workaround conuel syssam and inanseasse to 6iling process by operator caused error.
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8/18/95 MS R 9515 Procedural NRC Procedurel weakases invoivag supervisory omenght Waa6a= and jourasyman qualifscadon.
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8/17/95 OPS LER UI 95- Procedural Self Identifying Spreydown of Unit I consauunset. STARpsocese did .
]'; 007 landequacy and not assign accountability forcorrective ecdon. Valve '
VIO 9515 Weekases/ aurvedlance preiube not documeened on STAR.
Operesor Work-l Around 8/9/95~ MS LER Ul 95 Maimenance/ Liensee lanperable Unit i PORVe due to e 005 Toadas errore .. . ;- ; inadequacy. (Valva assembled
, incorrectly) (Used ac~" dois omiy)
- 8/6/95 ENG LER Ul 95- Corrective Self Identifying LiAlag of Unit i SDC thermal relief due to preesdusel '
- 006 Action / Procedural revisene froen previous coriseesve encima. Inaperable i V109515 Weakasen equipment not logged.
I
{ 8/2/95 OPS LER UI 95- Procedure! Licensee I A2 RCP seal failure due to 'remagiog' at high 004 Weakasas/Feilure temperature.
VIO95-15 to Follow f, ' Procedurea 3
- 8/2/95 OPS LER UI 95-04 Operator Error Self-identifying Operator failed to block MSIS acesesion during cooldown.
l YlO 9515 4
7/29/95 MS R 95-14 Prodcedurel Self Identifying IACpersonnel auempt to test a level swiesh circuit Weaknese h could not actuais given symem conditions.
- 7/29/95 OPS R 9514 Operator Self Identifying .oine/ Reactor Trip due to test error.
Error / Procedure!
$ Weakneu I
j 7/29/95 MS R 94-14 Root cause Self Identifying Catastrophic failure of Unit 2 B train CEDM cooling
- Pending fan.
i l7/3/95 PS R 95-14 Secunty Self Idensifying Automobile paaned through norsnelly closed secutify f, Weakness gets to plant intake / discharge causie at beach. !l 4-
! Suberquent accident resuhed in vehicle lodged in !
discherse canal piping. l i 7/1/95 OPS R 9512 Weak Log NRC Weaknesses identified in lage rolessag to hemory Keeping
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jumper installation and outef-servise equqnnent. j i
7/1/95 MS R 9512 Maimenance Self Identifying Corrosion in transforiner fire prosection deluge symem ;
results in muhiple failures.
7/1/95 PS IR 95-12 Personnel Error NRC Three pieces of SNM found improperty tagged.
NCV 95-l2-02 7/1/95 PS R 9512 Program NRC Fire Protection program weekasases identified in fire-Weaknesses fighting techniques and respirator qualifacation program.
7/1/95 MS R 95-12 Personnel Error NRC . M&TEfound installed scrose bouery cell without J/Il NCV 95124I sushorustson I 6/3/95 MS R 95-10 Procedurel NRC Several exavapise of weak adheresse to proceduses.
Adequacy / including step signoffs and verifacesson, Adherence identified.
6/3/95 ' MS R 95-10 Poor Comrreanica- Licensee Poor communication / lack of dessalad imensuctson leado non to improper IB EDO governor id= Ham 6/3/95 MS R 95-10 Poot NRC HVAcayetems for both units poorly Meiseenance/ Proc maimanined/Operadas procedures ceasessed
~
edures numerous deficiencies. I 6/3/95 MS R 95-10 Poor Surveillance Licenses Missed esveral survea la-a= (7 day) on EDG.
NCV 95-1401 Tresking Syenom MS R 9549 Personnel Error Licensee Failure so Perform permannel air insk testing on aims.
l4/29/95 NCV 95 09 01
4/28/95 OPS IR 95 05 Correcuve Action NRC STAR /NCR program did not address evaluaung past Program operability I
waa k a= ==
4/28/95 MS IR 95 05 Maintenance Error Licensee .acore lastruments at IClFlange 8 nuswired ICI 3
ou. cut signale directed to wrong compuser points.
4/28/95 OPS IR 95-05 Weakness in NRC Weakness la addressing how enode would a&ct Temp Mod control room drawings.
Procedure 4/28/95 ENG IR 95-05 Failure to NRD Failure io document nonconformance regarding ICI NCV 95 05-04 Implernent flange 8 conditions.
Cornettve Action Program 4/28/95 MS IR 95-05 Design NRC Installation of wrong overload heater models it:
VIO 95-05-01 Implementation switchgear.
Discrepancy 4/1/95 OPS IR 95-07 Apparent Licensee Unit I expenanced an approximate 14 minute loss of NCV 95-07-02 Personnel Error shutdown cooling while shihing from one shutdown cooling loop to the other. The root cause was the
? closing of the wrong SDC suction isolation valve (the valve for the operating, vice adle, pump) on the part of the nperator.
4/l/95 MS R 95-07 Poor Adherence to Licensee Jumper Leh installed in ECCS venuletaan damper sAer NCV 95-07-02 J/LL and work complete.
Maintenance Procedures 4/1/95 OPS IR 95-07 Wuk Annunciator NRC Weak annuncistor response by roe contnbuted to Response loss of shutdown cooling event.
3/26/95 MS IR 94-09 Procedural NRC LPSi mechanical sasi housing outer cap misinstalled.
Weakness 3/26/95 OPS !R 9449 Operator NRC Operator failure to neognize out of-sight high Error /Proced-ural indication on EDO cooling water tank. Failure of Weakneu procedure to include instructions on draining tank.
3/04/95 ENG IR 95 04 Design Licenses SDC suction relief valve lih due to water hammer.
3/04/95 OPS IR 95 04 House- NRC Loose plastic debris found in Unit 2 fut pool area, keeping 2/27/95 MS IR 95-04 Equipment Failure Self Identifying Unit I was shut down for the replacement of 3 pressunzer , code safety velves. The valves were leaking by the seat.
2/21/95 OPS tR 95-04 Equipment Failure Self Identifying Unit 2 trip due to (silure of a SGWL control level tronaminer. Tennsmiuer failed high, resulting in closure of the FRV and a subsequent inp on low
- SGWL. (9544) 2/20/95 OPS 1R 95-04 Equipment Self Identifying 2B LPSIpump found air-bound during survedlance Anomaly testing. 'the licensee has theortzed that the migration of air in the system resulted in the condiuon as a result of previous surveillance testing. The pumps are not self-venung.
2/17/95 MS IR 95-02 Physical Condition NRC Numerous areas of corvoeion idemi6ed in Unit 1/2 CCW areas.
2/17/95 PS IR 95-03 Personnel Error NRC la two observed exercises, ECs failed to notify sistes (Training within 15 minutes.
Weakness 2/16/95 MS IR 95 04 Maintenance Self Identifying Imd shed of the 1 A3 IE 4160 bus due to inadverwat Error / jumper contact while replacing a degended vohage Procedural relay.
Weaknem
2/4/95 OPS IR 95-01 Operator Ucenses F:ilure io sangle Sfr within TS requend tiene frame VIO 95-01-01 Error /Com- following volums addition. Second occurnace in 2 murucations years.
2/4/95 OPS [R 95-01 Poor NRC Failure to idenufy and analyze Unit i has les flow
, Communications stratification 2/4/95 MS IR 95-01 Personnel Errort Self Identifying inadequase independers verification resuhed in CVCS VIO 95-0102 Pmgram leidown coraron valve failing to respond due to j Weakneca reverned lenda. Resulted in a ceamssion o(leadown flow, s
12/31/94 ENO [R 94-25 Engineering Self Identifying inadequase design control of NaOH emas comasction '
NCV 94-25-01 Design Error betwsen ECCS trains.
12/3/94 PS IR 94-24 Procedure Review Licensee Failure to perform TS-nquired penodic procedure
. NCV 94-24-01 Inadequecy revwws.
12/3/94 MS IR 94-24 Maintenance NRC Inadequate procesa for changes to vendor technical l VIO 94-24-02 Procedures manuals. !
Inadequaev 11/25/94 MS IR 94-22 Program Licenses The licensee's QA organization idaatiGod nuawrous weakness weaknesses in the implementation of the site's welding program. As a result, the Mainesasace Manar placed a stop work order ce welding acts.t.es. The stoppage lasted one week.
11/24/94 MS [R 94-14 Procedure Self-idenufying Unit i B side SIAS actuation due to a bissable module weakness which had not been adequately withdrawn from the '
- ESFAS cabinet during maintenance.
]
11/23/94 MS IR 94 24 Equipment Failure Self idenufying Unit i SlAS with unit in mode 5 due to common mode l failure of Rosemount transininers used for pressurtzer pressure channels. {I t
11/5/94 OPS IR 94-22 Operations, Licensee Wasie gas release on Sept. 10.1993, with NCV 94-22-03 Maintenance meteorological instruments out of earvice. j Ermrs i 10/26/94 MS IR 94-22 Weather-Related/ Self-Identifying Unit I automat.cally tripped due to arc over from a LER Maintenance potenust transformer due to salt buPdup on switchyard insulators.
9/30/94 OPS IR 94-20 Inconsistent NRC Local valve position indicators not snaintained MS Expectauons accurate. Procedures / training pttmded to opersiors on verifying valve position found week.
9/30/94 OPS [R 94-20 Opersuons. NRC Plant personnel not trained on IPE and not using it for Maintenance wort planning and scheduling.
Deficiency 9/30/94 OPS IR 94-19 Operauons NRC During requal exam, a licensed opermier exhibited an Weakness appannt disregard for EOPs.
9/30/94 MS IR 94-20 Personnel Error Ucensee ~ Maintenance personnel begin to work the wrong RWT isolation valve, threatening the operability of both trains of ECCS.
9/30/94 OPS IR 94-19 Operations Ermr Licensee Failun to notify the NRC of changes in saasua of NCV 94-19-01 licensed operstors' medical conditions.
8/29/94 OPS IR 94-20 Opersuons Errors NRC Operators placed i A EDO in an electncel lineup foi VIO 94-22-01 which TS-required surveillance testa had not been VIO 94-22-02 performed (with the safety-related swung bus powered frcm it). Also, related consmi roost nog entries appeared to be inaccurate.
8/28/94 OPS IR 94-20 Equipment Failure Licensee Unit I was taken offlina (Mode 2) to repeir a DEH leak. The urut was returned ce lima laser the saans
] day.
i 8/12/94 OPS IR 9018 Opereuons/ NRC m licanese was unnoeding new fuel for Unit I with a :
Maineensace Erme hoist greppte that was missing the safety leech aleeve )
and Lack of locaung pin. The safety slave fuasuomed by friction Enginsenns only.
Drawings /In-j specuon Cntens ;
7/14/94 M3 IR 94-15 Equipment Licensee /NRC During surveillance test. TCB 5 failed to spea due to LER U-2 94 Failure / Poor mechanical binding Oicenses). The licenses failed to 06 Management recognaza the condeson as aquinag a shandown per VIO94-15 01 Decision TS (NRC).
7/9/94 OPS IR 94-15 Equipment Failure Licensee Und 2 turbine was shut down med seesner power mduced to Mode 2 because the 281 RCP lower oil level indication showed a lesL The indesamma was later shown to be ermneous.
'i/8/94 OPS IR 94-15 Operator Error Licensee TS 3.0.3 entry due to placing 2Al LPSIpuesp and 2B LER U2 94-05 charging pump OOS at the masse time.
6/28/94 MS IR 94-14 Personnel Error / Licensee inoperable Uni 2 RAB venulation enheesst WRGM due NCV 94-14-01 Procedural to failure to connect sample linea. l LER U-2 94 Weakness i 04 6/6/94 OPS IR 94-14 Wenar Licensu Unia I inp from 1005 power during a severe thunderstorm due to debris blown screes two main l transformer output ternunals. j 5/28/94 PS [R 94-13 Poor Correcuve NRC Emergency supplies in contmi room less that stated in !
I DEV 94-I3-Ol Action FSAR.
5/6/94 ENG IR 94-11 Engineenns Error NRC Inadequate corrective action for MOVs which stalled l VIO 94-I I-O n during surveillances.
)
4/23/94 OPS [R 94-12 Mfg. Error Self Idnufying Unit 2 auto reactor trip from 305 power caused by l l
LER U-2 94 RPS cabines wiring error forinp bypass circuit, from 03 original unit construction.
I 4/23/94 MS IR 94-12 Equipment Failure Self-idenufying Following unit 2 trip, steam bypass symem operated unexpectedly and dropped RCS taany by seven degrees F.presounzer heaters tunned off.
4/21/94 OPS IR 94-12 Operator Licensee Unit 2 reactor power increased from 26 to 315 due to Insttenuveness positive hnC.
4/7/94 MS IR 94-10 Maintenance Error NRC Contractor personnel made and contractor QC
'/10 94 10-01 accepted pressunzer nozzle weld prop that did not meet procedural requirements for bevel angle.
Licensee engincenng had specified overly tight tolerences.
4/3/94 OPS IR 94-12 Opersuons Self-Identifying Unit I auto reactor trip due to unusual electrical lineup LER UI 94 N Prncedure Erme (isochronous EDO paralleled with offsita power (Lack of sufficient - through TCBs).
depth in review) 4/3/94 ENG IR 94-12 Surveillance Error Licensee Licensee discovered that the 4160 V(AB Bue] swing VIO 94-12-Oi bun components (C ICW Punip and C CCW Pump) would not sanp from the bus upon undervoinage ifthe bus were aligned to the B bus due to a maassag wire.
3/28/94 MS tR 94-09 Personnel Ermr Self Identifying Unit I auto reactor trip. Meimensase famanan opened LER Ut 94-03 generator exciter breaker on wmag unit 3/16/94 ENG IR 94-08 Engineenn NRC Regional inspector had two Unit 2 SL4 violations: 1)
VIO 94 08 01 Corneuve Action corneuve action for an 11/24/92 weist hamuser event VIO94-08 02 was done without documented insenessanas or procedures, resuhing in operating useil 3/94 with five snubbers on the SRV and PORV tadpques .
2.
- 2) Failure to wnte a m% suport for a damaged pipe suppen in Marsh 1994.
i 1
I 3/16/90 ENG IR 94-10 Equipenent Failure Licensee A Unit 2 pressuruer instrurners r-ta that had been l LER U 29442 repaired a year ago was found leaking while the urut was in Mode 5. The urut renwined shut down for repairs.
l 3/4/94 ENG (R 94-06 Enginsenns Licensee inadequata design controls on Unit 2 sequencer !
NCV-9446-02 Design Error charging pump loading block. )
3/4/94 ENG IR 94-06 Enginsenns Error Licensee Failure to report an EDG failure.
NCV 944641 2/28/94 ENG IR 94-09 Rsfueling Licensee /NRC Inadequate grappling of a fuel assembly caused by j NCV 94-0441 procedure & error in Recommended Move List and operator error in l operator error following procedure. (IR 9449) 2/17/94 OPS IR 94-05 Operator Error Licensee Pressuruer aux. spray isolation valve had been locked NCV 94-05-01 closed (vice open) since 3/27/93.
LER U2 94-01 :
l 2/11/94 PS IR 9442 Secunty Error Licenses Failure to provide required compenastory measures in I NCV 94-0241 response to a security computer system failure.
I 1/13/94 OPS IR 9441 Surveillance Self IdentiGed UVrelay test resulted in load shed of the I A3 4160 voh i LER UI 94 02 Procedure bus and a 1 A EDG auto start Weaknesse Component l Fahure i
1/9/94 OPS IR 9441 Equipment Fa;1ure Self IdenuGed Manual reactor inp feed pump controi circuit failure.
LER Ut 94-01 ]
3 I
1/2/94 - SALP penod 11 began l l
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ST LUCIE -
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P
l August 3, 1995 IMINARY NOTIFICATION OF EVENT OR UNUSUAL OCCURRENCE PNO-II-95-047 This preliminary notification constitutes EARLY notice of events of POSSIBLE safety or public interest significance. The information is as initially
, recsived without verification or evaluation, and is basically all that is known by Region II staff (Atlanta, Georgia) on this date.
Facility Licensee' Emergency Classification Florida Power & Light Co. X Notification of Unusual Event Saint Lucie 1 Alert Hutchinson Island, Florida Site Area Emergency Dockets: 50-335 General Emergency Not Applicable l
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 Unusual Event due to a 2 GPM leak from the 1A2 reactor coolant pump seal to the containment sump. (See Event Number 29153. ) Unit 1 is being a
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 avant.
I State of Florida has been notified of this event. l 1
The NRC received notification of this event at 9:58 p.m. (EDT) on August 2 by phone call to the NRC duty officer.
This information is current as of 9:30 a.m. on August 3, 1995.
Contact:
R. SCHIN (404)331-5561 e
4 July 10, 1995 l IMINARY NOTIFICATION OF EVENT OR UNUSUAL OCCURRENCE PNO-II-95-039 This preliminary notification constitutes EARLY notice of events of POSSIBL5.
safety 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.
FPcility Licensee Emercancy classification Florida Power & Light Co. Notification of Unusual Event Saint Lucie 1 2 Alert Jennan Beach, Florida Site Area Emergency, Dockets: 50-335,50-389 General Emergency X Not Applicable l
Subject:
MEDIA INTEREST - AUTOMOBILE DRIVES INTO DISCHARGE CANAL 3 At about 3:30 p.m. on Sunday, July 9, 1995, a sport utility vehicle drove
, through the owner controlled area and into the discharge canal near the bsant head wall. The three vehicle occupants safely exited the vehicle and ne one was seriously injured. The vehicle is now completely suomerged. The vehicle occupants were teenagers and were apparently looking for a place to surf.
The vehicle entered the discarge canal on the opposite side of the A1A hiahway from the nuclear units and about one-half mile from the nuclear i
- s. The area was fenced and posted for restricted access but an c .ss gate was open. There was no threat to plant safety. There has bosn local media interest.
2 The licensee notified the U.S. Coast Guard, Florida Marine Patrol, and the National Department of Transportation Response Center.
The NRC Senior Resident Inspector received initial notification of this event from the licensee at about 3:30 p.m. July 9, and responded to the site. The NRC residents are following this issue.
The State of Florida has been notified.
- This information is current as of 9
- 30 a.m. on July 10, 1995.
l
Contact:
R. SCHIN (404)331-5561 1
t UNITED STATES
- p d 88%go NUCLEAR REGULATORY COMMISSION 3 i REGION H o 101 MARIETTA STREET, N.W.. SUITE 2500 l ATLANTA, GEORGIA 30E3419e k...../ 'Ictober 10, 1995 Florida Power and Light Company ATTN: Mr. J. H. Goldberg President - Nuclear Division P. O. Box 14000 Juno Beach, FL 33408-0420
SUBJECT:
PLANT PERFORMANCE REVIEW (PPR) - ST LUCIE
Dear Mr. Goldberg:
On September 21, 1995, the NRC staff completed the semiannual Plant Performance Review (PPR) of St. Lucie. The staff conducts these reviews for all operating nuclear power plants to develop an integrated understanding of safety performance. The results are used by regional management to facilitate planning and allocation of inspection' resources. 'The PPR for St. Lucie involved the participation of all Regional Technical Divisions and NRR in evaluating inspection results and safety performance information for the period from March 1995 to September 1995. PPRs. provide regional management with a current summary.of licensee performance and serve as inputs to the NRC Systematic Assessment of Licensee Performance (SALP) and senior management
- meeting (SMM) reviews.
This letter advises you of our planned inspection effort resulting from the St. Lucie PPR review. It is provided to minimize the resource impact on your staff and to allow for scheduling conflicts and personnel availability issues to be resolved in advance of inspector arrival onsite. The enclosure details our inspection plan for the next 6 months. The rationale or basis for each inspection outside the core inspection program is provided so that you are aware of the reason for emphasis in these program areas. Resident inspections are not listed due to their ongoing and continuous nature.
We will inform you -of any changes to the inspection plan. If you have any questions, please contact K. Landis at (404) 331-5509.
. Sincerely, f
/$
111s W. Merscho Director Division of Rea. or Projects
! Docket No.: 50-335, 50-389 i License No.: DPR-67, NPF-16
Enclosure:
Inspection Plan cc w/ encl: (See page 2)
/ .
~
t i
FP&L 2 cc w/ encl:
4 D. A. Sager i
Vice President St. Lucie Nuclear Plant P. O. Box 128 Ft. Pierce, FL 34954-0128 H. N. Paduano, Manager
- Licensing and Special Programs Florida Power and Light Company P. O. Box 14000 Juno Beach, FL 33408-0420 J. Scarola Plant General Manager St. Lucie Nuclear Plant P. O. Box 128 Ft. Pierce, FL 34954-0128 Robert E. Dawson Plant Licensing Manager St. Lucie Nuclear Plant P.'O. Box 128 Ft. Pierce, FL 34954-0218 J. R. Newman, Esq.
4 Morgan, Lewis & Bockius 1800 M Street, NW '
Washington, D. C. 20036 l John T. Butler, Esq.
1 . Steel, Hector and Davis 4000 Southeast Financial' Center i Miami, FL 33131-2398 Bill Passetti Office of Radiation Control Department of Health and Rehabilitative Services .
1317 Winewood Boulevard
- Tallahassee, il 32399-0700 Jack Shreve 4
Public Counsel .
Office of the Public Counsel c/o The Florida Legislature 111 West Madison Avenue, Room 812 Tallahassee, FL 32399-1400 cc w/ encl: Continued see page 3
i FP&L 3 <
cc w/ encl: Continued Joe Myers, Director Division of Emergency Preparedness
-Department of Community Affairs i 2740 Centerview Drive Tallahassee, FL 32399-2100 Thomas R. L. Kindred .
County Administrator l St. Lucie County .
2300 Virginia Avenue l Ft. Pierce, FL 34982 l
Charles B. Brinkman Washington Nuclear Operations i ABB Combustion Engineering, Inc. i 12300 Twinbrook Parkway, Suite 3300 '
Rockville, MD 20852 f
i O
l
ST LUCIE INSPECTION PLAN IP - Inspection Procedure TI - Temporary Instruction Core Inspection - Minimum NRC Inspection Program (mandatory all plants)
INSPECTION TITLE / NUNBER OF PLANNED TYFE OF INSPECTION - CONNENTS PROCEDURE PROGRAN AREA INSPECTORS INSPECTION DATES IP 84750 Radioactive Waste Systems, 1 10/16-20/95 Core Inspection Water Chemistry Confirmatory Measurements and Radiological Environmental Monitoring
'IP 86750 Solid Radioactive Waste Management and Transportation of Radioactive Materials IP 38701 Procurement Program; 1 12/04-15/95 Regional Initiative -
. to address recent concerns in IP 38702 Receipt, Storage, and the procurement area.
t ri g am i/M k' IP 38703 Commercial Grade Procurement Inspection IP 40500 Safety Assessment 3 12/95 or 01/96 Regional Initiative Inspection IP 92720 Corrective Action Program 1-week to review the adequacy and status of the ongoing Safety Assessment and Corrective Action Program at St Lucie.
- _-_,.._.-ma -c._A__m._mm__. a__m a_. _ ___ _ _ - _ _ _ ...__m._____ -_.-_.m -._.___m_ __m.___.mmm_m__ - - ___1 -_ ___- ___ __m-_- *___J
INSPECTION TITLE / NUMBER OF PLANNED TYPE OF INSPECTION - CONNENTS PROGRAN AREA INSPECTORS INSPECTION DATES -
IP 61726 Surveillance Observation 1 11/95 1-week, Core Inspection IP 62703 Maintenance Observation 01/96 1-week, 03/96 1-week IP 82701- Operational Status of the 2 02/05-09/96 Core Inspection - EP Exercise Emergency Preparedness Program IP 82301 Evaluation of Exercises
'for Power Reactors IP 82302 Review of Exercise Objectives and Scenarios -
for Power Reactors IP 83750 Occupational Radiation 2 02/26-03/01/96 Core Inspection Exposure IP 84750 Radioactive Waste Systems, Water Chemistry Confirmatory Measurements !
and Radiological Environmental Monitoring ,
IP 86750 Solid Radioactive Waste Management and Transportatic:. of '
Radioactive Materials .
TI 2515/109 Inspection Requirements 1 or 2 TBD 03/96 Area of Emphasis - Inspection to for Generic Letter 89-10, close out Generic letter 89-10 Safety-Related Motor-Operated Valve Testing and ,
Surveillance '
Licensing Examination 3- 03/11-15/96 Operator Exam Preparation Preparation Initial Licensing 3 03/25-29/96 Scheduled Operator Exam Examination
. . - - . _ _ . . . . . -.-..- -.- - --- - ..-.-...-....-. -~ -.- _ - - - - .-
.....-- -... .-. ~.. - -.-- ... -
eO O e DA< e, . 12/04/96 FLOR IDA POW ER & LIGHT R RC3OR TIME: 00/13/07 t RADI ATION EXPOSURE MONITORING & ACCESS CONTROL SYSTEM - REMACS PAGE 1 ACCESS , RESTRICTED REPORT - ACTIVE PERSONNEL EFFECTIVE END l
' , l OPID . DATE DATE DEPT.,PIk# NAME CODE REASON DESCRIPTION
................ . . . . - - ............................. ....................................... ..g.................
017 Ti HP1 SEE UNIT 1 HEALTH PHYSICS SHIFT SUPERVISOR MOURING 09/04/96 041 II TRN NEEDS TRAINING DUNNE 12/03/96 I 044 WBC NEEDS BODY COUNT DUNNE 12/03/96 ;
044 MED MEDICAL DUNNE 11/13/96 i WBC NEEDS BODY COUNT DUNNE 12/03/96 013 017 MED MEDICAL VASILAS 09/12/96 ;
046 TRN NEEDS TRAINING D(NENE 12/03/96 i 061 TRN NEEDS TRAINING DtNENE 12/03/96 i TRN NEEDS TRAINING DUNNE 12/03/96 052 WBC NEEDS BODY COUNT DUNNE 12/03/96 '
047 TRN NEEDS TRAINING DLNENE 12/03/96 '
r41 NTC NEEDS TRAINING CLASS & BODY COUNT VASILAS 10/02 '
O44 -
DUNNE 11/21.
LOA LEAVE OF ABSENCE 030 09/03/2 NTC NEEDS TRAINING CLASS & BODY COUNT VASILAS 1 013 h MEDICAL DUNNE 10/31/96 MED 095 .
NTC NEEDS TRAINING CLASS & BODY COUNT VASILAS 10/02/96 ;
044 HPA SEE DOSIMETRY MOORE 11/20/96 :
014 NEEDS TRAINING DUNNE 12/03/96 [
039 TRN 11/26/96 MED MEDICAL MOORE 003
~ . l 4
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i II'I0m3ti n 13 this rccord wag gggggg a:ccMance uith tk Ticedam of Information
. euacious 4 : (o %
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\TE: A2/04/96 REPORT: DEXPC10R IME" 00:50:45 PAGE: 1 FLOR IDA POWER = LIGHT RADIATION EXPOSURE MONITORING & ACCESS CONTROL SYSTEM - REMACS I
a EXPOSURE
SUMMARY
REPORT
. l 41,
.g L SORTED BY: DEPT /NAME
. st.f ~ 44, dP M ENT:;004 - NPS ENERGYk LRVICE(l i
I -- TEDE -- - GUIDE / EXT - EXTREMITY ACCUM.
PID 5 QUAL NAME - MARGIN SITE YEAR SITE ANNUAL SKIN UPPER LOWER DAC HRS i
984 16 16 1000 4500 16 0 0 0.00 997 3 3 1000 4500 3 0 0 0.00
- 986 14 14 1000 4500 14 0 0 0.00 i 0 912 88 88 1000 4500 88 0 0.00 954 46 46 1000 4500 89 0 0 0.00
, 698 302 302 1000 4500 340 0 0 0.00 947 53 53 1000 4000 53 0 0 0.00 .
988 12 12 1000 4500 12 0 0 0.00 963 37 37 1000 4500 37 0 0 0.00 l X 952 48 48 1000 4000 48 0 0 0.00 !
XCG '470 530 530 1000 4500 530 0 0 0.00 980 33 20 1000 4500 20 0 0 0.00 4 981 19 19 1000 4500 19 0 0 0.00 ,
l X ! 810
- 190 190 1000 4500 190 0 0 0.00 l 1000 0 0 1000 4500 0 0 0 0.00 ;
767 233 233 1000 4500 233 0 0 0.00 ;
X 1000 0 0 1000 4500 0 0 0 0.00 l 0 0 0.00 '
775 225 225 1000 4500 225 727 273 273 1000 4500 291 0 0 0.00 i 1000 0 0 1000 4500 0 0 0 0.00 X 960 40 40 1000 4500 40 0 0 0.00 X 836 164 164 1000 4500 189 0 0 0.00 869 131 131 1000 4500 131 0 0 0.00 ;
846 154 154 1000 4500 172 0 0 0.00 '
i 1000 0 0 1000 4500 0 0 0 0.00 958 42 42 2000 4500 42 0 0 0.00 ;
1000 0 0 2000 4500 0 0 0 0.00 i
! X 538 1212 1212 1750 4500 1369 0 0 0.00 j 988 12 12 1000 4500 12 0 0 0.00 :
2000 0 0 1000 4500 0 0 0 0.00 i XG , 713 287 287 1000 4500 287 0 0 0.00 F 1000 0 0 100G 4500 0 0 0 0.00 t 850 150 150 1000 4500 150 0 0 0.00 j 992 25 8 1000 4500 8 0 0 0.00 :
1000 4500 353 0 0 0.00 i
. 671 329 329 !
936 64 64 1000 4500 64 0 0 0.00 l
- 1000 0 83 1000 4500 83 0 0 0.00 I
1000 0 0 1000 4500 0 0 0 0.00
. 1000 0 0 1000 4500 0 0 0 0.00 [
1000 0 0 1000 4500 0 0 0 0.00 [
1000 0 0 1000 4500 0 0 0 0.00 t 868 132 132 1000 4500 132 0 0 0.00 !
I
- 473 527 527 1000 4500 598 0 0 0.00 X 622 878 878 1500 4500 938 0 0 0.00 i i t
i i
I
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DATE: 12/04/96 PLANT: PSL i
TIME: 00:50:45 REPcDT: DEXPC10]
PAGE: 2 FLOR IDA POWER & LIGHT '
RADIATION EXPOSURE MONITORING & ACCESS CONTROL SYSTEM - REMACS EXPOSURE
SUMMARY
REPORT !
I g il g ;
SORTED BY: DEPT /NAME DEP bTk 004 -
hPSENERGk VIqi li
- I -- TEDE -- - GUIDE / EXT - EXTREMITY ACCUM.
PID 8 QUAI, NAME _' MARGIN SITE YEAR SITE ANNUAL SKIN UPPER LOWER Dhc HRS-0 0 0.00 i
929 71 71 1000 4500 84 945 55 134 1000 4500 134 0 0 0.00 1000 0 15 1000 4500 15 0 0 0.00 XG 914 86 86 1000 4500 86 0 0 0.00 I 875 125 125 1000 4500 135 0 0 0.00
! 719 281 281 1000 4500 281 0 0 0.00 939 61 61 1000 4500 61 0 0 0.00 1000 0 0 1000 4500 0 0 0 0.00 938 62 62 1000 4500 62 0 0 0.00 i
- ' X 0 0.00 988 12 12 1000 4500 12 0 1000 0 0 1000 4500 0 0 0 0.00 937 63 150 1300 4500 150 0 0 0.00 934 66 131 1300 4500 131 0 0 0.00 X
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.. . . . . ~~ . . . .
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PFJ04T: PSL 1 ATE: 12/04/96 REPORT: DEXPCIC2
."IMF : oO:50:45 PAGE: 3 FLOR I DA POWER & LIGHT
~
RADIATION EXPOSURE MONITORING & ACCESS CONTROL SYSTEM - REMACS EXPOSURE
SUMMARY
REPORT I
SORTED BY: DEPT /NAME
[{
- EP ENT 007 - COMBUSTION
-- TEDE -- - GUIDE / EXT . EXTREMITY ACCtM.
I PID 5 00AL NAME MARGIN SITE YEAR SITE ANNUAL SKIN UPPER LOWER DAC HRS
........._.._______............__........___.....___...______..___._..____.L.._____-_-_____...
m- mj e.1 1, 1, 1ooo .soe 1, o o o.oo i
I I
O h
I
- - . - - - . _ . ~ ~ . - ~ - . - - - - . ~ . - - . , . _ . . . - - - . - - - - - - - - - - - - - - - - - - - . - - . - - - - . - - - - - - - - - - . - - - - . . . - . - . . . . . . -
AATE: 12/04/96 PLANT: PSL RIME: 00:50:45 REPORT: DEXPC1CR PAGE: 4 FLOR IDA POWER & L 1GHT ,
RADIATION EXPOSURE MONITORING & ACCESS CON 1*ROL SYSTEM - REMACS EXPOSURE
SUMMARY
REPORT SORTED BY: DEPT /NAME 41 4 .M L 2EPg % 010 - ELECTRIbl INT l -- TEDE -- - GUIDE / EXT - EXTREMITY ACCUM.
PID # QUAL NAfE MARGIN S I T** YEAR SITE ANNUAL SKIN UPPER LOWER DAC HRS SX 921 79 79 1000 4500 79 0 0 0.00 SX 763 237 237 1000 4500 244 C 0 0.00 i 0 SX SX i f 978 997 22 3
22 3
1000 1000 4500 4500 22 3
0 0 0 0.00 0.00 i SXG / 743 257 257 1000 4500 257 0 0 0.00 .
SX 985 15 15 1000 4500 15 0 0 0.00 !
. SXG -
976 24 24 1000 4500 24 0 0 0.00 i SX 747 253 253 1000 4500 253 0 0 0.00 !
>l SX f 910 90 90 1000 4500 93 0 0 0.00 SX 908 92 92 1000 4500 92 0 0 0.00 ,
SK 1000 0 0 1000 4500 0 0 0 0.00 !
K 1000 0 0 1000 450C 0 0 0 0.00 0 0 0.00 '
! 923 77 77 1000 4500 77 SX 903' 97 97 1000 4500 100 0 0 0.00 ;
448 2 2 450 4500 2 0 0 0.00 ,
917 83 83 1000 4500 83 0 0 0.00 X 1000 0 0 1000 450C 0 0 0 0.00 SX 1000 0 0 1000 4500 0 0 0 0.00 450 0 0 450 4500 0 0 0 0.00
, SX i 982 18 18 1000 4500 18 0 0 0.00 l SX 975 25 25 1000 4500 25 0 0 0.00 l SX f 445 555 555 1000 4500 555 0 0 0.00 I 935 65 65 1000 4500 65 0 0 0.00 $
923 77 77 1000 4500 87 0 0 0.00 SX 1000 0 0 1000 4500 0 0 0 0.00 941 59 59 2000 4500 59 0 0 0.00 i SXG 1000 0 0 1000 4500 0 0 0 0.00 l SXCG 981 19 19 1000 4500 19 0 0 0.00 Y 996 4 4 1000 4500 4 0 0 0.00 792 208 208 1000 450C 226 0 0 0.00 SX y 957 43 43 1000 4500 43 0 0 0.00 i SX 998 2 2 1030 4500 2 0 0 0.00 SXCG 748 252 252 1000 4500 272 0 0 0.00 SX l 968 32 32 1000 4500 32 0 0 0.00 i YG 385 615 615 1000 4500 638 0 0 0.00 X
- 577 423 423 1000 4500 443 0 0 0.00 SX 957 43 43 1000 4500 43 0 0 0.00 1000 0 0 1000 4500 0 0 0 0.00 SX 861 139 139 1000 4500 139 0 0 0.00 i SX 952 48 48 2000 4500 48 0 0 0.00
, $XG 952 48 48 1000 4500 48 0 0 0.00 SX / 999 1 1 1000 4500 1 0 0 0.00 SX / 945 55 55 1000 4500 55 0 0 0.00
- - - . _ - - . . _ . . . - - - - . - . - . - . . . ~ ~ . - . . . . . ~ . - . . . . . ~ ~ . . . . - - . . . . - ~ . . .
DATE: 12/04/96 PLANT: PSL !
TIM 2: 00:50:45 1 REPORT: DEXPCICR
PAGE: 5 FLOR IDA POWER & LIGHT RADIATION EXPOSURE MONITORING & ACCESS CONTROL SYSTEM - REMACS EXPOSURE
SUMMARY
REPORT
- -d *
.g L SORTED BY: DEPT /NAME ,
k t e e s .s l DEP TMEN : 012 - HP UTILI RKENI
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-- TEDE -- - GUIDE / EXT - EXTREMITY ACCUM.
PID 8 QUAL NAME > MARGIN SITE YEAR SITE ANNUAL SKIN UPPER LOWER DAC HRS X 1215 285 285 1500 4500 302 0 0 0.00 [
! 0 0 0.00 XG 550 950 950 1500 4500 974 X 395 605 605 1000 4500 637 0 0 0.00 i X 457 543 543 1000 4500 543 0 0 0.00 824 176 185 1000 4500 185 0 0 0.00 SX 918 82 82 1000 4500 82 0 0 0.00 X 848 152 152 1000 45C3 152 0 0 0.00 t' X 596 404 404 1000 4500 414 0 0 0.00 X 884 616 616 1500 4500 631 0 0 0.00 SX 885 115 115 1000 4500 115 0 0 0.00 i X 710 290 595 1000 4500 628 0 0 0.00 ;
X 658 347 342 1000 4500 354 0 0 0.00 i 986 14 144 1000 4500 144 0 0 0.00 i ,
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ATE: 12 4/96 FIANT: PSL j IME: 00:50:45 REPCRT: DEXPC10R PAGE: 6 t FLOR I DA PONER & LIGHT RADIATION EXPOSURE MONI'!URING & ACCESS CONTROL SYSTEM - REMACS EXPOSURE SUP94ARY REPORT !
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PID 8 QUAL NAME
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MARGIN SITE YEAR SITE ANNUAL SKIN UPPER LOWER DAC HRS 450 0 0 450 4500 0 0 0 0.00 450 0 0 450 4500 0 -0 0 0.00 j 1000 0 0 1000 4500 0 0 0 0.00 R 0 0 0 0.00 450 0 0 450 4500 ~
450 0 0 450 4500 0 0 0 0.00
.l 450 0 0 450 4500 0 0 0 0.00 I 1000 0 0 1000 4500 0 0 0 0.00 ;
I 450 0 0 450 4500 0 0 0 0.00 l 1000 0 0 1000 4500 0 0 0 0.00 .
i 1000 0 0 1000 4500 0 0 0 0.00 R 0 0 0 0.00 450 0 0 450 4500 450 0 0 450 4500 0 0 0 0.00 l 330 120 120 450 4500 120 0 0 0.00 !
450 0 0 450 4500 0 0 0 0.00 450 0 0 450 4500 0 0 0 0.00
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i DATE: 1 /04/96 PLANT: PSL TIME: 00:50:45 REPORT: DEXPC10R
. PAGE: 7 ,
FLOR I DA POWER & LIGHT
, RADI ATION EXPOSURE MONITORING & ACCESS CONTROL SYSTR1 - REMACS EXPOSURE
SUMMARY
REPORT
- ' i l
,-4 L SORTED BY: DEPT /NAME idL-s th ::h. 1 ' !
DEvem mra a : 014 . HEALTH pl SS p
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't a -- TEDE -- - GUIDE / EXT - EXTREMITY ACCUM.
PID 5 OUAL NAME J MARGIN SITE YEAR SITE ANNUAL SKIN UPP$R LOWER DAC HRS t a SX 402 598 598 1000 4500 618 0 0 0.00 l 1 SX 562 438 438 1000 4500 450 0 0 0.00 SX 354 646 646 1000 4500 707 0 0 0.00 r SX 108 292 292 1000 4500 307 0 0 0.00 999 1 1 1000 4500 1 0 0 0.00
/ SX 657 843 843 1500 4500 859 0 0 0.00 f SX 552 948 948 1500 4503 964 0 0 2.12 SX 253 1247 1247 1500 4500 1311 0 0 1.00 SX 970 30 30 1000 4503 30 0 0 0.00 XG 999 1 1 2000 4500 1 0 0 0.00 1000 0 0 1000 4500 0 0 0 0.00 X 760 240 240 1000 4500 240 0 0 0.00 SX 618 382 382 1000 4500 397 0 0 0.00 SX 639- 361 361 1000 4500 361 0 0 0.00 i SX 824' 176 176 1000 4500 176 0 0 0.00 1000 0 0 1000 4503 0 0 0 0.00 1000 0 0 1000 4503 0 0 0 0.00 X 755 245 245 1000 4500 264 0 0 0.00 KG =
571 929 929 1500 4500 944 0 0 0.00 X 547 453 453 1000 4503 453 0 0 0.00 758 742 742 1500 4500 742 0 0 0.00 1000 0 0 1000 4500 0 0 0 0.00 6 SX 892 108 108 1000 4500 129 0 0 0.00 i SXG 913 87 87 1000 4500 97 0 0 0.00
', SK B41 159 159 1000 4500 163 0 0 0.00
' SX 495 1005 1005 1500 4500 1126 0 0 0.00 SX 368 632 632 1000 4503 632 0 0 0.00 SX 763 237 238 1000 4503 238 0 0 0.00 SX 381 619 619 1000 4503 645 0 C 0.00 SX 579 421 421 1000 4500 442 0 0 0.00 It SX 664 336 336 1000 4500 336 0 0 0.00 SK 1404 96 96 1500 4503 99 0 0 0.10 SX 363 1131 1271 1500 4503 1306 0 0 0.00 SX 700 300 300 ~1000 4500 300 0 0 0.50 SXG "
892 108 108 1000 4503 108 0 0 0.00 X 837 163 163 1000 4500 163 0 0 0.00 'l X 865 135 135 1000 4500 135 0 0 0.00 i SX 940 60 60 1000 4503 60 0 0 0.00
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- 754 246 246 1000 4500 246 0 0 0.00 K 450 0 0 450 4500 0 0 0 0.00 3X 614 386 386 1000 4500 411 0 0 0.00 1X 690 310 310 1000 4500 330 0 0 0.00 3X 616 884 884 1500 4500 895 0 0 0.00
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PLANT: PEL ATE: 12/d4/96 REPORT: DEXPCIER 8
IME: 00:50:45 PAGE:
FLOR I DA POWER & LIGHT RADIATION EXPOSURE MONITORING f. ACCESS CONTROL SYSTEM - REMACS EXPOSURE SLM4ARY REPORT
. , l SORTED BY: DEPT /NAME
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ePdENTse15 . .EAI.T,P.,i,k,,_p EXTREMITY ACCUM.
-- TEDE -- - GUIDE / EXT -
MARGIN SITE YEAR SITE ANNUAL SKIN UPPER IX)WER DAC HRS PID 8 QUAL NAME 4500 24 0 0 0.00 WK (W/ 976 24 24 1000 1000 4500 114 0 0 0.00 886 114 114 e
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! PSL PLANT: }
DATE: 12/04/96 REPORT: EEXPC10R i TIME: 00:50:45 PAGE: 9 j FLOR IDA POWER & LIGHT j RADIATION EXPOSURE MONITORING & ACCESS CONTROL SYSTEM - REMACS l
EXPOSURE
SUMMARY
REPORT t SORTED BY: DEPT /NAME j hg g l i
L ARTMENT: 017 - 'I & C !
I EXTREMITY ACCUM. I
-- TEDE -- - GUIDE / EXT -
PID 8 QUAL NAME MARGIN SITE YEAR SITE ANNUAL SKIN UPPER LOWER DAC HRS !
680 320 320 1000 4500 320 0 0 0.00 i R X / 0 0 0.0C !
X !77 423 423 1000 4500 425 I52 148 148 1000 4500 148 0 0 0.00 '
l 1000 0 0 10C0 4500 0 e O- 0.00 X 0 0 0.00 X t,01 399 399 1000 4500 419 !
g 30 30 1000 4500 30 0 0 0.00 l t 970 '
O.00 j
X 296 704 704 1000 4500 753 0 0 l 1000 4500 429 0 0 0.00 l' 571 429 429 0 0 0.00
' 416 584 584 1000 4500 628 0 0 1000 4500 0 0 0 0.00 1000 0 0 0.00 0
1000 0 0 1000 4500 r 11 11 1000 4500 11 0 0 0.00 !
X 989 0 0 0.00 1000 0 0 1000 4500 0 841 159 159 1000 4500 159 0 0 0.00 Y 4500 0 0 0 0.00
- 1000 0 0 1000 577 423 423 1000 4500 433 0 0 0.00 l SXG 4500 211 0 0 0.00 i SX 789 211 211 1000
.15 15 1000 4500 s 'i 0 0 0.00 t
' 985 0 0 0 0.00 )
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669 331 331 1000 4500 331 0 0 0.00 l 271 271 1000 4500 271 0 0 0.00 t i SXGli 729 0 0 0.00 I 976 24 198 1000 4500 198 !
t 415 585 585 1000 4500 679 0 0 0.00 X \' > 686 314 314 1000 4500 326 0 0 0.00 1000 0 0 1000 4500 0 0 0 0.00 }
R 110 1000 4500 110 0 0 0.00 i SX 890 110 1070 0 0 1000 4500 0 0 0 0.00
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874 126 126 1000 4500 126 0 0.00 YG 1000 4500 139 0 0 0.75 861 139 139 l
X 1237 263 263 1500 4500 263 0 0 0.00 i 526 474 474 .1000 4500 525 0 0 0.00 i X 0 0 0.00 i X
687 313 313- 2000 4500 327 r ,
1148 352 352 1500 4500 352 0 0 0.00 l SX i 86 0 0 0.00
{ =* 914 86 86 1000 45C0 2000 0 0 1000 4500 0 0 0 0.00
., 0 0 682 818 818 1500 4500 858 0.00 ,
581 919 919 1500 4500 972 0 0 0.00 ,
X ^ i 14 0 0 0.00 986 14 14 1000 4500 r i
SX 4f I 475 525 525 1000 4500 537 0 0 0.00 i 609 391 391 1000 4500 424 0 0 0.00 SX 4500 356 0 0 0.00 654 346 346 1000 l 799 201 201 1000 4500 201 0 0 0.00 i
[ 694 306 1000 4500 328 0 0 0.00
' ISXG gf 306 t
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PLANT: PSL DATE: 12'/04/96 REPORT: DEXPC10R TIME: 00:50:45 PAGE: 10 FLOR I DA POWER & LIGHT RADIATION EXPOSURE MONITORING & ACCESS CONTROL SYSTEM - REMACS
~
j EXPOSURE SUP94ARY REPORT yd . , .
, h i SORTED BY: DEPT /NAME DEPETMEN : 017 -I & C C 1 - GUIDE / EXT - EXTREMITY ACCUM.
-- TEDE --
UPPER LOWER DAC HRS PID # QUAL NAME .!. MARGIN SITE YEAR SITE ANNUAL SKIN 0 0 1000 4500 0 0 0 0.00 X 1000 0 0.00 i f / g 1000 0 0 1000 4500 0 0 '
1000 0 0 1000 4500 0 0 0 0.00 983 17 17 1000 4500 17 0 0 0.00 ,
SX 531 0 0 0.00 4
SX 492 508 508 1000 4500 918 82 82 1000 4500 97 0 0 0.00 SX '
40 0 0 0.00 960 40 40 1000 4500 190 190 1000 4500 190 0 0 0.0C X 810 0 0.00
' 1000 0 0 1000 4500 0 0 647 853 853 1500 4500 920 0 0 0.00 i Y 0 0 0 0.00 1000 0 0 1000 4500 84 84 1000 4500 92 0 0 0.00 SXCG 916 0 0 0.00 SX ' 436 564 564 1000 4500 605 956' 44 44 1000 4500 44 0 0 0.00 ;
719 281 281 1000 4500 281 0 0 0.00 X 387 0 0 0.00 SX 613 387 387 1000 4500 1000 0 0 1000 4500 0 0 0 0.00 i 555 445 445 1000 4500 445 0 0 0.00 !
!XG 436 0 0 0.00 581 419 419 1000 4500 .
+
940 60 60 1000 4500 60 0 0 0.00 t SX 4500 301 0 0 0.00 SX 701 299 299 1000 i
706 294 294 1000 4500 331 0 0 0.00 SX 66 0 0 0.00 i 934 66 66 1000 4500 ;
554 446 446 2000 4500 489 0 0 0.00 XG 1000 4500 363 0 0 0.00 661 339 339 898 102 102 1000 4500 102 0 0 0.00 X 264 0 0 0.00 749 251 251 1000 4500 698 802 802 1500 4500 814 0 0 0.00 720 280 280 1000 4500 301 0 0 0.00 g
546 954 954 1500 4500 1002 0 0 0.00 X }'
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PLANT: PSL 6 ATE: 12/04/96 REPORT: DEXPC10R !
FIM2: 00:50:45 PAGE: 11
- FLOR I DA POWER & LIGHT l RADIATION EXPOSURE MONITORING & ACCESS CONTROL SYSTEM - REMACS I
l EXPOSURE
SUMMARY
REPORT l.
-l L SORTED BY: DEPT /NAME
>EP fhf TMENT 027 - Maintenan l gg Se rvid e
-- TEDE -- - GUIDE / EXT - EXTREMITY ACCUM. t PI N OUAL NAhE I MARGIN SITE YEAR SITE ANNUAL SKIN UPPER LOWER DAC HRS 626' 874 946 1500 4500 965 0 0 0.00 i
/ SXG 0 0 0.00 1000 0 0 1000 4500 0 j / 1000 0 0 1000 4500 0 0 0 0.00
< 7 910 590 890 1500 4500 973 0 0 0.00 972 28 28 1000 4500 28 0 0 0.00 K 0 0 0.00 938 62 62 1000 4500 62 t 971 29 29 1000 4500 29 0 0 0.00 -
934 66 66 1000 4500 66 0 0 0.00 !
SX 0 0 0.00 i SX 1000 0 0 1000 4500 0 i
938 562 850 1500 4500 909 0 0 0.00 j f 1000 4500 0 0 0 0.00 1000 0 0 !
1000 0 0 1000 4500 0 0 0 0.00 l X 0 0 0.00 SXC 1000, 0 0 1000 4500 0 ;
983 17 17 1000 4500 17 0 0 0.00 i 917 83 83 1000 4500 83 0 0 0.00 l 601 1549 1652 2150 4500 1693 0 0 0.00 l SX l 0 0 0.00 !
X 950 50 585 1000 4500 649 782 218 218 1000 4500 236 0 0 0.00 827 173 173 1000 4500 173 0 0 0.00 796 204 204 1000 4500 204 0 0 0.00 999 1 1 1000 4500 1 0 0 0.00 i SXG 0 0 0.00
+ SX 989 11 11 1000 4500 11 .
977 23 23 1000 4500 23 0 0 0.00 i 953 47 47 1000 4500 47 0 0 0.00 j SX 0 1524 0.00 X 700 1450 1450 2150 4500 0 976 24 24 2000 4500 24 0 0 0.00 1000 0 0 1000 4500 0 0 0 0.00 !
i
' 807 193 193 1000 4500 193 0 0 - 0.00 i 2000 0 0 1000 4500 0 0 0 0.00 i 1441 709 709 2150 4500 729 0 0 0.00 SX 0 0 0.00 L SX 730 270 270 1000 4500 282 953 47 47 1000 4500 47 0 0 0.00 ,
X 847 653 872 1500 4500 927 0 0 0.00 i
- 0 0
- 827 173 173 1000 4500 173 0.00 1 1000 0 0 1000 4500 0 0 0 0.00 i Y 979 21 21 1000 4500 21 0 0 0.00 t f
681 319 319 1000 4500 319 0 0 0.00 !
1000 0 0 1000 4500 0 0 0 0.00 i 802 198 198 1000 4500 216 0 0 0.00 !
Y 570 430 430 1000 4500 451 0 0 0.00 i
- 1004 746 746 1750 4500 797 0 0 0.00 i 871 129 129 1000 4500 129 0 0 0.00 !
171 1329 1558 1500 4500 1654 0 0 0.00 l 789 211 211 1000 4500 232 0 0 0.00 (
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PLANT: PSL ATE: 12/04/96 REPORT: DEXPC1CR ,
IME: 00:50:45 ~
PAGE: 12 !
FL0R I DA POWER & LIGHT 4 RADIATION EXPOSURE MONITORING & ACCESS CONTROL SYSTEM - REMACS EXPOSURE SUt94ARY REPORT
, }
SORTi 4
- DEPT /NAME d
EP T 020 - Maintenanc ic i
? j EXTREMITY ACCLM .
1 -- TEDE -- - GUIDE / EXT -
7 5 MARGIN SITE YEAR SITE ANNUAL S*' UPPER IDetER DAC HRS PID QUAL N . ...................._......................................... _ ........................ ;
80 2000 4500 ou 0 0 0.00 920 80 0 0 0.00 (
45 1000 4500 45 X [ 1000 955 0
45 0 1000 4500 0 0
0 0
0 0
0.00 0.00 SX 1000 0 0 1000 4500 0.00 i' 746 754 754 1500 4500 815 0 0 SX SX XG l 862 698 138 302 138 302 2000 1000 4500 4500 138 322 0
0 0
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SX 907 93 93
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! I PLANT: PSL DATE: 12/04/96 REPORT: DEXPC10R i TIME: 00:50:45 PAGE: 13 ?
FLOR IDA POWER & LIGHT !
RADIATION EXPOSURE MONITORING & ACCESS CONTROL SYSTEM - REMACS ;
! EXPOSURE StD94ARY REPORT j j i SORTED BY: DEPT /NAME DEPARTMENT: 021 - MECH MAINT. g
-- TEDE -- - GUIDE / EXT - EXTREMITY ACCT.M .
PID 5 QUAL NAME '
MARGIN SITE YEAR SITE ANNUAL SKIN UPPER IhWER DAC HRS r
/ SX 997 3 3 1000 4500 3 0 0 0.00 SX 998 2 2 1000 4500 2 C 0 0.00 797 203 203 1000 4500 219 0 0 0.00 959 41 41 1000 4500 41 0 0 0.00 851 149 149 1000 4500 149 0 0 0.00 983 17 17 1000 4500 17 0 0 0.00 ,
896 104 104 1000 4500 104 0 0 0.00 t 895 105 105 1000 4500 105 0 0 0.00 t 1000 0 0 1000 4500 0 0 0 0.00 l SX 886 114 114 1000 4500 114 0 0 0.00 i 842 158 158 1000 4500 150 0 0 0.00 '
1000 4500 20 0 0 0.00 !
\ 980 907 20 93 20 93 1000 4500 93 0 0 0.00 +
I 882 118 118 1000 4500 132 0 0 0.00 996 4 4 1000 4500 4 0 0 0.00 [
1000 0 0 1000 4500 0 0 0 0.00 l 981 19 19 1000 4500 19 0 0 0.00 i 971 29 29 1000 4500 29 0 0 0.00 869 131 131 1000 4500 131 0 0 0.00 !
1000 0 0 1000 4500 0 0 0 0.00 [
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I PLANT: PSL f i rE: 12/Od/96 REPORT: DEXPC100 MO: 00:50:45 PAGE: 14 i FLOR IDA POWER & LIGHT t
RADIATION EXPOS' IRE MONITORING E ACCESS CONTROL SYSTEM - REMACS I i
EXPOSURE SUpf4ARY REPORT g
,#4 j a SORTED BY: DEPT /NAME CAM t 23 - OPERATIONS $ 1 t,
t EXTREMITY ACCUM.
-- TEDE -- - GUIDE / EXT .
SITE ANNUAL SKIN UPPER LOWER DAC HRS i PID 8 QUAL NAME -
.........-.u- ............................................................................
MARGIN 1000 SITE 0
YEAR 0 1000 4500 0 .........................
0 0 0.00 0.00 f
SX 0 1000 4500 0 0 0 SX 's 1000 0 0 0 0.00 f i 877 123 123 1000 4500 123 SX 1000 4500 0 0 0 0.00 !
1000 0 0 0 0 0.00 l SX 0 0 1000 4500 MI - i 1000 0 0 0.00 766 234 234 1000 4500 0 0.00 KG 0 1000 4500 0 1000 0 0 0 0.00 X
B66 134 134 1000 4500 134 SK 1000 4500 259 0 0 0.00 l SX 745 255 255 0 0 0 0.00 [
t, 1000 0 0 1000 4500 0 0.00 SX 1000 4500 129 0 ;
j 871 129 129 0 0 0.00 '
SX 804 196 196 1000 4500 197 SX 1000 4500 296 0 0 0.00 ,
SX 704 296 296 0 0 0.00 l 941 59 59 1000 4500 59 0 0.00 i I SX 1000 4500 316 0 706 294 294 0 0 0.00 i 0 0 1000 4500 0 ' ;
SK 1000 4500 0 0 0 0.00 1000 0 0 1000 0 0.00 SXCG 1000 4500 79 0 l SXCC 921 79 79 0 0 0 0.00 1000 0 0 1000 4500 0 0.00 SK 71 71 1000 4500 71 0 SX 929 17 0 0 0.00 i 983 17 17 1000 4500 0 0.00 1000 4500 152 0 l 848 152 152 0 0 0 0.00 SX 0 0 1000 4500 xG 1000 4500 239 0 0 0.00 !
772 228 228 1000 0 0.00 X 15 1000 4500 15 0 1000 0 0 0 0.00 X 182 182 1000 4500 182 'I [
X 818 0 0 0 0.00 1000 0 0 1000 4500 0 0.00 t X 0 0 1000 4500 0 0 X 1000 4500 0 0 0 0.00 !
1000 0 0 1000 0 0.00 X 1000 4500 449 0 X
569 431 431 0 0 0 0.00 1000 0 0 1000 4500 12 1000 4500 12 0 0 0.00 X 988 12 0 0 0 0.00 1000 0 0 1000 4500 X 1000 4500 15 0 0 0.00 i 985 15 15 0 0 0.10 i X 576 1000 4500 625
- 424 576 13 0 0 0.00 987 13 13 1000 4500 N, 1000 4500 225 0 0 n 00 '
775 225 225 0 0 K
787 213 213 1000 4500 213 .0 1000 4500 90 0 0 0.00 .
910 90 90 0 0 0.00 X 215 215 1000 4500 238 X 785 4500 131 0 0 0.00 i 869 131 131 1000 X 2 1000 4500 2 0 0 0.00 998 2 0 0 0.00 XG 292 292 1000 4500 292 i X 708 4500 24 0 0 0.00 J
976 24 24 1000 i X
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t PLANT: PSL j OATE: 12/04/96 REPOHf: DEXPC10R ,
TIME: 00:50:45 PAGE: 15 '
FLOR I DA POWER & LIGHT RADI ATiON EXPOSURE MONITORING & ACCESS CONTROL SYSTEM - REMACS j EXPOSURE
SUMMARY
REPORT ;
l y g gggg* ,
g- SORTED BY: DEPT /NAME aEPJ0tWENh 023 - OPERATION . CLEAl
-- TEDE -- - GUIDE / EXT - EXTREMITY ACCtM .
8 QUAL NAME MARGIN SITE YEAR SITE ANNUAL SKIN UPPER LN ER DAC HRS
'SX
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696 304 304 1000 450C 304 0 0 0.00 ;
SX 872 128 128 1000 450" 120 0 0 0.00 l SX 931 69 69 0 C' 69 0 0 0.00 i SXG 987 13 13 s ,.u o 4506 13 0 0 0.00 j SX le50 0 0 1000 450C 0 0 0 0.00 l SX 1000 0 0 1000 4500 0 0 0.00 r SX 655 345 345 1000 4500 37' O 0.00 l SX BPS 191 191 1000 4500 I? O 0.00 l SX 953 47 47 1000 4500 . 0 0 0.00 i SX 633 367 367 1000 4500 367 0 0 0.00 SXCG 901 99 99 1000 4500 99 0 0 0.00 l SK 2 932 68 68 1000 4500 68 0 0 0.00 1000 0 0 1000 4500 0 0 0 0.00 i SX 0 0 0.00 SK 1000 0 0 1000 4500 0 !
SX 981 19 19 1000 4500 19 0 0 0.00 t SXG 1000 0 0 1000 4500 0 0 0 0.00 [
SXCG 8 169 169 1000 4500 184 0 0 0 00 ;
-k J 6.o 352 352 1000 4500 352 0 0 0 j 1 SX 0 0 JO SX 1000 0 0 1000 4500 0 +
SX 1000 0 0 1000 4500 0 0 0 0.00
'SX 877 123 123 1000 4500 123 0 0 0.00 SXCG 952 48 48 1000 4500 48 0 0 0.00 SX 874 126 126 1000 4500 137 0 0 0.00 SX 877 123 123 1000 4500 124 0 0 0.00 SX 977 23 23 1000 4500 23 0 0 0.00
- SX 1000 0 0 1000' 450C 0 0 0 0.00 i SX 853 147 147 1000 4500 147 0 0 0.00 SXG 972 28 28 1000 4500 28 0 0 0.00 SX 785 215 215 1000 4500 226 0 0 0.00 X 1000 0 0 1000 4500 C 0 0 0.00 [
i XG 600 400 400 1000 4500 416 0 0 0.00 j SK 915 85 85 1000 .4500 85 0 0 0.00 ,
SX l 979 21 21 l1000 4500 21 0 0 0.00 5 SX ,
l 902 98 98 ludu 4500 98 0 0 0.00 !
SX !* 802 198 198 1000 4500 198 0 0 0.00 4500 0 0 0 0.00 I SX 1000 0 0 1000 SX I 427 573 573 1000 4500 584 0 0 0.00 !
SX 919 81 81 1000 4500 81 0 0 0.00 l SXCC' 633 367 367 1000 4500 385 0 0 0.00 a 649 351 351 1000 4500 356 0 0 0.00 j XG .
<2A 172 172 1000 4500 1 0 0 0.00 }
0 0 SX e 118 118 1000 4500 0.00 f X louw 0 0 1000 4500 0 0 0.00 l X 868 132 132 1000 4500 132 0 0 0.00 j 1
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DATE: l'2/04/96 PLANT: PSL TIME: 00:50:45 REPORT: DEXPC10R j PAGE: 16 ;
FL0R IDA POWER & LIGHT t RADIATION EXPOSURE MONITORING & ACCESS CONTROL SYSTEM - REMACS I
}
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TIME: 00:50:45 REPORT: DEXPC10R PAGE: 38 i l
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, aATE: :12/04/96 REPCST: DEXPC102 :
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- YIME: 00:50:45 PAGE: 53 l A
FLOR I DA POWER & LIGHT ,
RADI ATION EXPOSURE MCNITORING & ACCESS CONTROL SYSTEM - REMACS EXPOSURE SUb94ARY REPORT l
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PAGE: 54 l FLOR IDA POWER & LIGHT RADIATION EXPOSURE MONITORING & ACCESS CONTROL SYSTEM - REMACS EXPOSURE SL994ARY REPORT i l
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-DATE: 12/04/96 REPORT: DEXPC10R TIME: 00:50:45 PAGE: 55 FLOR I DA POWER & LIGHT ,
RADIATION EXPOSURE MONITORING & ACCESS CONTROL SYSTEM - REMAC3 J EXPOSURE SUf91ARY REPORT .
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PAGE: 58 FL0R I DA POWER & LIGHT RADI ATION EXPOSURE MONITORING & ACCESS CONTROL SYSTEM - RE Q EXPOSURE
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' { EXPOSURE StM4ARY REPORT t
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ATLANTA, GEORGIA l
1 I
PLANT STATUS REPORT ST. LUCIE -
SEPTEMBER,1995
PLANT STATUS REPORT FOR ST. LUCIE (9/95) '
4 TABLE OF CONTENTS PART 1 - FACILITY DESCRIPTION 1.1 FACILITY / LICENSEE....................................Page 2 I.2 UTILITY SENIOR MANAGEMENT ...........................Page 2 1.3 1.4 NRC STAFF............................................Page 2 LICENSE.INFORMATION..................................Page 3 1.5 PLANT CHARACT ERI ST I CS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 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 10 i PART 2 - PLANT PERSPECTIVE l
2.1 GENERAL PLANT PERSPECTIVE............................Page 11
) 2.2 SALP HISTORY (Past Two SALP Periods) . . . . . . . . . . . . . . . . .Page 11 3 2.3 SELECTED SALP AREA DISCUSSIONS . . . . . . . . . . . ..........Page Il i 1 PART 3 - SIGNIFICANT EVENTS '
, 3.1 SIGNIFICANT EVENTS BRIEFINGS (Past 12 Months)........Page 16
- 3.2 ENFORCEMENT STATUS / HISTORY (Past 12 Months)..........Page 16 PART 4 - STAFFING AND TRAINING
- 4.1 OPERATIONS STAFF - 0VERALL.......................
4.2 WORK FORCE ..........................................Page ....Page 17 16 4.3 OPERATOR QUALIFICATION /REQUALIFICATION PROGRAM.......Page 17 4.4 PLANT SIMULATOR......................................Page 17 4.5 INP0 ACCREDITATION...................................Page 17 l PART 5 - INSPECTION ACTIVITIES S.1 OUTSTANDING ITEMS LIST
SUMMARY
.......................Page 18 5.2 . MAJOR INSPECTIONS....................................Page 18 5.3 PLANNED TEAM INSPECTIONS.............................Page 18 S.4 INFREQUENT INSPECTION PROCEDURE STATUS...............Page 18 5.5
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SIMS STATUS (OPEN TMI ITEMS).........................Page 18 ATTAC19 TENTS
- 1. PERFORMANCE INDICATORS
- 2. ALLEGATION STATUS
- 3. NRR OPERATING REACTOR ASSESSMENT
- 4. ORGANIZATION CHARTS
- 5. POWER HISTORY CURVES
. 6. MASTER INSPECTION PLAN (NOT INCLUDED)
- 7. SITE ACTIVITY SCHEDULE
- 8. SITE INTEGRATION MATRIX
- 9. PERFORMANCE ANALYSIS GRAPH m
2
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PART 1- FACILITY DESCRIPTION i 1.1 FACILITY / LICENSEE I
- FACILITY: St. Lucie Units 1 and 2 !
PLANT LOCATION: Hutchinson Island near Port St. Lucie, Florida LICENSEE: Florida Power and Light Co. (Corporate Office in Juno l Beach, Florida) '
I 1.2 UTILITY SENIOR MANAGEMENT c -
! CORPORATE:
)
J. L. Broadhead (Jim), Chairman of the Board and CEO !
j J. H. Goldberg (Jerry), President, Nuclear Division '
SITE:
D. A. Sager (Dave) - St. Lucie Plant Vice President C. L. Burton (Chris) - Services Manager L. W. Bladow (Wes) - Nuclear Assurance Manager H. F. Buchanan (Hank) - Health Physics Supervisor R. L. Dawson (Bob) - Licensing Manager D. J. Denver (Dan) - Site Engineering Manager H. L. Fagley (Herman) - Construction Services Manager -
P.'L. Fincher (Pat) - Training Manager R. J. Frechette (Bob) - Chemistry Supervisor P. Fulford (Paul) - Operations and Testing Support Supervisor J. Marchese (Joe) - Maintenance Manager W. L. Parks (Bill).- Reactor Engineering Supervisor C. A. Pell (Ash) - Outage Manager L. A. Rogers (Lee) - Systems and Comp 6nent Engineering Manager-J. Scarola (Jim) - Plant General Manager J. A. West (Jeff) - Operations Manager C.--fi Wood (Chuck) - Operations Supervisor 1.3' NRC STAFF REGIONIf, Atlanta,GA:
S. D. Ebneter (Stew), Regiona1' Administrator, (404) 331-5500 i L. A. Reyes (Luis), Deputy Regional Administrator (404) 331-5610 B. A. Boger (Bruce), Acting Director ORP, (404) 331-5623 l D. M. Verrelli (Dave), Branch Chief, (404)'331-5535 K. D. Landis-(Kerry), Section Chief, (404) 331-5509 i R. P. Schin (Bob), Project Engineer, (404) 331-5561 E. Lea (Edwin), Project Engineer, (404) 331-7096 SITE: i R. L. Prevatte (Dick), Senior Resident Inspector, (407) 464-7822 !
M. S. Miller (Mark), Resident Inspector, (407) 464-7822
1 .
3 NRR:
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, S. A. Varga (Steven), Director, Division of Reactor Projects-I/II, (301) 504-1403 J. A. Zwolinsky (John), Deputy Director, Division of Reactor Projects-1/II, (301) 504-1335 D. B. Matthews, Deputy Director, Project Directorate II-2,
, (301) 415-1490
- J. A. Norris (Jan), Senior Project Manager, Project l Directorate 11-2, (301) 504-1483 AE00:
. S. Israel (Sandy), Reactor Operations Analysis Branch, (301) 415-7573 1.4 LICENSE ~INFORMATION
- Unit 1 Unit 2 i
Docket Nos. 50-335 50-389 I License Nos. OPR-67 NPF-16 Construction Permit Nos. CPPR-74 CPPR-144 Construction Permit issued 7/1/70 5/2/77 ,
Low Power License NA 4/83 -
Full Power License 3/1/76 6/10/83 Initial Criticality 4/22/76 6/2/83 1st Online 5/17/76 6/13/83 Commercial Operation 12/21/76 8/8/83 1.5 PLANT CHARACTERISTICS Descriotion Units 1 and 2 Reactor -Iype 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 DE11GLINEQRETlDM 1.6.1 REACTOR INTEGRITY Reactor Pressure Ves pl (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 I
i l
I i 4 l span possible. Presently, a program is evolving for RPV life
' extension beyond the projected 40 years, potentially to 60 years, i 4
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 j
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 i . RPV life expectancy exceeds 60 years. Low leakage core designs j' are now used for economic reasons, however the low leakage designs provide even greater life expectancy.
i j Reactor Coolant Pressure Boundary 1
{ On this CE plant, ECCS-to-RCS injection points are isolated by at l
least two check valves and one closed MOV. High pressure safety injection (HPSI), low pressure safety injection (LPSI), and j containment spray (CS) pumps' common containment sump suctions are i
isolated from the containment sump by one closed MOV in conjunction with a closed seismic piping system. The CS headers i
are isolated from containment by one closed MOV and a check valve '
i in conjunction with a closed seismic piping system. CVCS has the
- normal complement of two automatic actuation isolation valves.
I. 1.6.2 ' REACTOR SHUTDOWN 1
{ Reactor Protection System i'
The reactor protection system provides protection for the reactor futt and its cladding by providing automatic reactor shutdowns (B
, trips) based on input from reactor power, reactor coolant i pressure, coolant temperature, coolant flow, steam generator l~ prefssure, and containment pressure. The RPS is a redundant four-channel system that operates on a two-out-of-four logic.
ATWS Protection ATWS protection, 09tside the normal reactor protection system, is
' initiated via the ESF pressurizer pressure. signal. It actuates by o,'ening contactors in the output of the CEA MG sets, thereby l interrupting corarol element assembly power at its source. This '
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.
l 5
1.6.3 CORE COOLING l
- Feedwater System I
The main feedwater pumps are motor driven with each delivering 50
- percent of the flow required for full power.
- Turbine' Bvnass/ Steam Da=a'Canacity
, 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 the capability of ,
dumping nine percent steam flow to the atmosphere. 1 Auxiliary Feedwater Systgm 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 Coolino 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 Asihdicatedabove,theLPSIpumpsalsoprovidedecayheatremoval 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 automatic isolation valves and various relief valves in the system.
1.6.4 CONTAINMENT Pressure Control / Heat Removal There_Are two containment spray pumps and four containment fan coolers available per unit to suppress pressure spikes and cool 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.
4 1
n 6 l 1
Hydrocen Castrol 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 i manner, the temperature of containment atmosphere flowing through
! the recombiner, the recombiner units recombine hydrogen and oxygen i
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 a three independent 240 KV lines that share a right of way and i interconnect, with FPL's grid on the mainland approximately 10
- miles West af 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 ,
l independent of other plant systems except vital DC power for -
i control of starting. A Station Blackout (SBO) cross connection is installed and tested. This cross-connection serves the emergency
- busses directly and ' reduces cross-connect time to less than 15 minutes. .
) DC' Power Two trains of vital batteries per unit have been routinely tested y for four-hour DC load profiles. Recently, due to cell repl.acement, they have been tested for three-hour battery capacity instead. Ttie 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 l 4
cross-connected to the safety-related swing bus if needed.
Instrumentation Power i Each unit has four inverters, two powered from each vital DC j train, that-provide four trains of instrumentation power.
St.: tion Blarkout Resolution Status Unit 2 is a four-hour "0C coping" plant per the original license 4
while Unit 1 is subject to the station blackout (SBO) rule of 10
! CFR 50 li3 requiring additional licensee action (unit-to-unit cross-connect of 4160V bus).
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1 l 7 l 1.6.6 SAFETY-RELATED COOLING WATER SYSTEMS Intake Coolina Water (Service Water)
Intake cooling water (ICW) for each unit originates in a common canal called the Intake Canal. The canal level varies with the l
tides since it is filled by a level difference between the Atlantic Ocean and the canal. One 16-foot and two 12-foot p
i diameter pipes pass under the beach to connect the ocean and canal. The intake pipe ends in the Atlantic'are covered by intake structures (rebuilt in 1991) intended to limit flow velocities. -
particularly vertical velocity, to reduce marine life entrapment. ,
After use, ICW returns to the ocean through a Discharge Canal and i l under-beach pipes. .
Each unit has two trains of ICW plus a swing pump that can be aligned to either train electrically and physically. The licensee !
has converted the deep draft ICW pumps from externally (water) lubricated to self-lubricated to increase reliability of the i lubrication water source. The 100 percent (each) capacity pumps '
take suction from the intake canal via a canal intake structure using traveling screen debris protection. The intake canal structures adjacent to the ICW pump suctions are continuously.
injected with a hypochlorite solution to' reduce marine growth in the associated piping and heat exchangers. Commencing 3/92, l periodic injection of a clamicide at the intake structures, primarily to control marine growth affecting the turbine condensers, has also somewhat reduced marine growth affecting the 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 :
heat exchangers. The discharge from the heat exchangers returns via the discharge canal to the ocean.
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Increases in debris and silt in the heat exchangers during-1993 indicated that the intake canal needed dredging.
As of September 1993, the utility was routinely cleaning main condenser waterboxes at reduced power and obtaining necessary dredging permits from the state and Corps of Engineers.
The canal was dredged in December 1993 and January 1994 with insediate results.of reduced waterbox fouling.
Closed Coolino Water Systems l
Each unit has two trains of Component Cooling Water (CCW). The l arrangement of two pumps and a swing pump mimics the ICW system. !
- ._ _ __ ~ _ _ . . _ _ _ _ _ _ _ _ . _ . _
8 The swing pump can be aligned to either train. The 100 percent (each) capacity pumps drive water through the CCW/ICW heat exchangers and then on i.6 the heat loads, mainly the containment
, fan coolers and the shutdown cooling (decay heat) heat exchangers (which also can operate as containment spray heat exchangers).
Additionally, CCW cools a variety of bearings, seals, and oil coolers for the HPSI, LPSI, and CS pumps. A non-safety-related portion of the CCW system cools reactor coolant pump seals and the
. spent fuel pool. This section isolates upon engineered safety features actuation.
j 1.6.7 SPENT FUEL STORAGE I
Wet storage capability exists up to the year 2002 (Unit 2) and
- 2007 (Unit 1),
i 1.6.8 INSTRUMENT AIR SYSTEM Instrument air compressors and driers, installed several years ago on each unit, provide all instrument air for Unit 2 and all but containment air for Unit 1. These have increased instrument air -
reliability. Unit 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 0perations Facility: 10 miles West of site.
I-95/ Midway Rd. Exit Techni. cat- Support Center: Onsite, Adjacent to Unit 1 Control Room Operational Support Center: Onsite, 2nd floor of North Service Building The last annual emergency preparedness exercise was in May,1995. This exercise was not formally evaluated by the NRC. The next emergency preparedness exercise is scheduled for February,1996.
Since St. Lucie site has a high probability of hurricanes, communications facilities were improved following the Turkey Foint experience with Hurricane Andrew in August,1992. Improvements include:
High Frequency Auto-link with other FPL sites and NRC.
._...__..___._______._-..______..__._._7
=
g Enhanced 900 MHZ System for site and mobile communications, with !
i radios also in the licensee's EOF and county emergency facility.
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Cellular phones with hardened antennas.
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Hardened Local Government Radio antenna ties.
- , 1.8 'pRESENT OPERATIONAL STATUS (9/19/95) j i
The unit was ' shutdown on August 1,1995, as a result.of Hurricane Erin.
3 A' series of problems including RCP seal failure, both PORVs inoperable j- due to incorrect assembly, SDC relief valve problems, associated i problems with several other relief valves, inadvertent spraydown of the i
containment, catastrophic fa Mure of IB emergency diesel generator, and 'I a leaking flange on a pressurizer safety valve have prevented the unit !
- from being restarted. With the unit down, a large number of operator-i, work-arounds and other plant deficiencies are pscheduled to be corrected. The next refueling outage is scheduled for April 4,1996. 4 Unit 2 was shutdown on April 25, 1995, for approximately seven hours to i
replace a main turbine digital electro hydraulic power supply. The unit !
j was down powered for several days in June and July to clean condenser ;
[ water boxes. The unit was shutdown on August 1, 1995, as a result of o
Hurricane Erin. .The unit was restarted on August 4, 1995. Power was i
reduced from August'17 through 29 to clean condenser water boxes and repair various secondary plant deficiencies. The next refueling outage y is scheduled for October 9, 1995. ]
i ,
l Availability Factors:
I 1991 81.0 100.0
- 1992 96.5 75.2 l' '1993 74.0 71.8
! 1994' 86.8 79.6 1 1995 (through 7/95) 93.9 98.3 j Cuniulative (through 7/95) 77.7 83.7 4
F 1.8.1 UNIT 1 OPERATING HISTORY (Past Twelve Months from 8/1/94) 1 ~
j Unit 1 operated continuously during the past 12 months with the following exceptions:
i licit I reduced power and entered mode 2 on August 28, 1995, to {
repair a DEH leak. The unit was returned to power approximately l 18 hours2.083333e-4 days <br />0.005 hours <br />2.97619e-5 weeks <br />6.849e-6 months <br /> later on the -same date. l On October 26, 1994, the unit tripped from 100 percent power due to a. loss of electrical load. This was the result of arc-over in 1 a potential transformer in the switchyard due to salt buildup. l The licensee then entered a unit refueling outage, which had been ]
l
10 4
i scheduled to begin four days later. The unit was returned to service on November ~29, 1994.
On February 21, 1995, the unit was removed from service for the replacement of pressurizer code safety valves which had been
- leaking by the seat since shortly after startup in November,1994.
The unit was returned to service on March 8,1994.
l ' On March 4, 1995, the unit experienced a 14 minute. loss of shutdown cooling. The apparent root cause was operator error by a
' reactor' operator placing one loop of SDC in standby. The operator .
apparently closed the suction valve to the operating, vice ,
i standby, pump.. The operator in question has denied the error.
The licensee is considering disciplinary action and has relieved
, the operator of licensed activities. u 5
I On June 11, 1995, the unit was down powered to 40 percent to j p jumper out a cell on 18 safety related battery.
i j
On July 8, 1995, the unit. tripped during turbine valve surveillance testing. It returned to power on July 12, 1995.
On August 1,1995, the unit was shutdown as a result of Hurricane
! Erin. Due to a series of equipment problems and personnel '
- performance issues, the unit is presently shutdown.
! l.8.2 UNIT 2 OPERATING HISTORY (Past Twelve Months from 8/1/95)
Unit 2 operated continuously during the past 12 months with the F following exceptions:
! )
i
{ On February 21, 1995, the unit tripped as a result of low steam i generator water level. The condition was the result of a fee.dwater regulating valve. closure after a steam generator water level control level transmitter failed high. The transmitter was j replaced and the unit was returned to service on February 25,
- i 1995. I L On April 25, 1995, the unit was shutdown for approximately 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> '
l to replace a main turbine DEH" power supply.
4
] On August 1,1995, the unit was shutdown as a result of Hurricane
- Erin. It was restarted on August 4,1995, but operated at reduced
- power from August 17 through 29, 1995, to clean condenser water boxes and repair equipment problems.
3 1.9 OUTAGE SCHEDULE AND STATUS
, Unit l's last refueling outage began on October 26, 1994, and ended on
- November 29, 1994. Major activities included
- refueling; reactor vessel L nozzle and flange weld ISI inspection; installation of a permanent cavity seal ring; replacing reed switches for several CEAs; integrated i
4 .
4 E
[ 11 safeguards test; steam generator tube inspection and plugging; steam generator sludge lancing; repair of refueling water storage tank; several instances of reduced inventory / mid-loop operations; replacement I of ICW/CCW LOOP logic [HFA latching relays) with pull-to-lock switches; removal [ collection] of Rx vessel neutron flux dosimetry; modification l of EDG skids to allow access underneath; inspection of ECCS sump area; replacement of a main transformer; modification of containment spray i
! NaOH addition. piping; and mechanical, electrical, and I&C systems j maintenance.
Unit 2's last refueling outage began on February 13, 1994, and ended a
- j. April 17, 1994. Major outage activities included: refueling; steam generator tube inspection and plugging; low pressure turbine blade replacement; emergency diesel generator inspection; replacement of two I
' reactor coolant pump mechanical seals; and mechanical, electrical, and I&C systems maintenance. The next Unit 2 refueling outage is scheduled for October, 1995.
P A R T. 2 -
PLANT PERSPECTIVE 2.1 GENERAL PLANT PERSPECTIVE A SALP presentation was conducted on February 17, 1994, covering the SALP period of May 3, 1992, through January 1, 1994. The facility was '
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 l performers after experiencing five unit reactor trips in the first half of 1994.
2.2 SALP HISTORY (Past 2 SALP Periods)
The last.SALP period, SALP Cycle.10, ended on January 1, 1994. The i current SALP period ends on July 1, 1995.
ASSMT. -
OPS RAD MNT/SURV EP SEC -ENG/ TECH SAQV PERIOD 5/1/89 - 1 1 ~2 1 1 1 1 10/31/90 11/1/90 - 1 1 1 1 1 1 1 5/2/92 PLANT OPS MAINTENANCE ENGINEERING PLANT SUPPORT 5/3/93 - 1 1 1 1 1/1/94 2.3 SELECTED SALP AREA DISCUSSIONS (9/1/951
i' I
- ._.,.. 1
)
- 12 i
! .Since July 1995, there has been a series of events that led to i questioning the plants overall performance. These have included: a i
- Unit 1 turbine. trip due to procedural weakness, operator performance and i
- supervisory oversight; the attempt to restage an RCP seal using
- inadequate and inappropriate' procedural guidance which led to the L failure of the second and third stage seals, a main steam isolation L signal due to inappropriate operator response, an inadvertent reactor i protection system actuation due to inattention to detail by.an operator,
! both pressurizer relief valves being inoperable due to incorrect ,
- assembly during a refueling outage, an inoperable shutdown cooling
- '
relief valve.due to incorrect setpoint margins (a generic problem ,
1- involving several valves), the spray down of containment due.to an '
i inadequate procedure and operator error coupled with an existing
- i. operator-work-around. These and several other recent deficiencies 4 l involving weak procedures, a general lack of procedural compliance, i equipment failures, and personnel errors clearly indicate that the :
i plants past high level of performance has declined. Both units were i shutdown on August 1,'1995, for Hurricane Erin. Unit 2 immediately 1 restarted but Unit I remained shutdown. The above problems have led to ,
j several plant management changes, an overall evaluation of the recent L plant problems by a plant requested independent assessment team and a
- root cause evaluation by the NRC. In a meeting with the NRC on August ,
j 29, 1995, the licensee committed to use the results of the independent i assessment team to develop an action plan for improvement.
Plant Ooerations .
Summary of Previous Assessment Within the current SALP cycle, previous assessments have noted a potential decline in Operations' performance. Noted indicators.
included five reactor trips in the first six months of the cycle.
No common root causes were identified. Operator actions with regard to the noted trips were generally good. Two entries into reduced inventory operations during the Unit 2 outage were noted as' excellent. Procedural weaknesses which indicated a lack of rigor in the review process were noted, as was the fact that temporary changes to procedures were on the increase (indicating increasing attention to procedural adequacy).
Management activities in response to the increase in operational events was determined to be strong, with an increase in overall focus directed at plant operations. The corrective actions program was enhanced, consolidating several programs into one which involves daily management reviews of all documented conditions.
The previous assessments concluded that Operations remained si.rong in the current period, that management actions were aggressive in dealing with ideatified weaknesses, and that increased attention to procedural adequacy may be warranted.
v .
i
[ 13 Last Six Months The previous six months has shown an increase in personnel errors
! involving, the failure to follow procedures, inattention to
! detail, the failure to maintain awareness of equipment status,.and i weaknesses in logkeeping. Only one reactor trip, a turbine trip
, due to operator error, occurred during this time span. Operator
! response to that event was excellent. -Overall response to plant f
startups, shutdown, power maneuvers has been good. Several
- findings indicated weaknesses in personnel performance,' procedural
{ adequacy, inattention to detail, weak logkeeping, equipment .
- . failures, poor communications, and living with operator-work-
- arounds. They include
Overpressurizing the main generator
- Not logging equipment out of service Starting a LPSI pump with the suction valve closed l
Overfilling PWT 4
- Spray down of Unit 1 Containment
[
Turbine trip due to operator error
. *- STAR /NCR not evaluating past operability ,
Temporary modification not shown on CR drawing -
Loss of SDC, operator closed suction isolation valve
- Weak annunciator response on loss of SDC !
Operator failed to identify level out of sight on EDG cooling water tank
- Spent fuel pool housekeeping Failure of SGWL Rosemount transmitter (maintenance)
- 2B LPSI pump found airbound
- Failure to sample SIT within TS required time frame following volume addition (second occurrence in 2 years)
- -., Failure to identify and analyze hot leg flow stratification Strengths Strengths have been identified in operator response to trips, transients, and power maneuvers. Post job or evaluation briefings have overall been timely and thorough ;
with the exception of several recent events.
Weaknesses See paragraph 1 above.
Conclusion Operations performance has declined in the past six months.
Operators respond well to events but do not always have a questioning attitude, appear to have lapses in procedural use and compliance, and are not identifying and forcing
i i.
g plant support organizations to correct plant deficiencies.
Logkeeping and attention to detail have led to an increase
- in errors.
Maintenance / Surveillance l Summary of Previous Assessment s
I Maintenance was assessed as category 1 in the previous SALP.
j The previous assessments made during the current'SALP cycle
. indicated that the' performance level of maintenance .
! activities had not abated. Strong perfo miance had been 4
noted in the support of the. Unit 2 outage, and housekeeping
- and plant preservation activities were deemed good. I
! Last Six Months
?
During the past six months, 24 maintenance activities were observed in varying levels of depth. One violation involving the installation of incorrect size motor overload L heater was identified. Three potential violations
- involving, inadequate surveillance, inadequate post <
maintenance tests, and two inoperable PORV are currently l
} being evaluated. Two non-cited violations involving '
i inadequate control on jumpers were identified. Workers were found to be well skilled and trained overall. Problems have l been noted in procedural adequacy and use. .
!' Twenty-two surveillance activities were observed. Two non-cited violations involving the failure to perform j surveillance within specified time limits were identified.
These were the result of a weak surveillance tracking system.
Strengths i
The licensee continues to use and improve on their !
online maintenance procedure and implementation. '
Overall maintenance activities performed under this program were well~ planned and executed. The craft work force is motivated and overall skill level is high. The licensee has completed the development of their maintenance rule and it will be in place and operating by the end of September. The predictive
~ maintenance organization continues to provide early indication of pending failure and assists in root cause evaluation of equipment failures.
Weaknesses Weaknesses have been identified in the following areas:
- - -. . ~ . _ - - - - . . - . . - - - - . . - . - . . . . - . - - . - . . . - . - - . - . . . . - -.
{ _
j 15 Procedural adequacy
- Procedural compliance Installation of incorrect parts.
Personnel errors in work performance Surveillance tracking system )
i
- Equipment failures Control of lifted leads / jumpers 1 l Consnunications l Conclusion 1
- Maintenance performance has declined. Equipment failures ;
i~ have impacted plant operation. Craft personnel are not !
- identifying and correcting procedural deficiencies and are '
using procedures as general guidance. Individual and group
[ performance is generally excellent for high visibility jobs,
- but attention to detail appears to lapse on routine work.
!~ Enaineerino i
! Summary of Previous Assessment i
I The previous assessments for this SALP cycle' concluded that engineering was generally strong. Good support of the Unit '
{ 2 outage was noted, as was good QA with respect to fuel 4'
fabrication and receipt inspection.
Last Six Months Engineering at St. Lucie remains strong. The trend in the number of issues over the past two quarters has gone down.
However, a number of issues in the area organizational Recently.
- _ . there was an up/progr=
ward turnconnunication in the numberhave arisen. issues of engineering '
during the recent shut down. Those issues are being inspected. In the: aggregate, St. Lucie Engineering has provided valuable support to Operations and Maintenance throughout the past year.
{
Conclusion ~
Engineering continues to perform well. No weaknesses have been identified in this functional area.
4 Plant Suonort Radioloaical Controls The radiation protection program continues to adequately maintain external and internal radiation exposures ALARA and within 1
i 4
16 regulatory limits. . The licensee adequately incorporated revisions to the radiation protection program for implementation of the new
. requirements of.10 CFR Part 20. The licensee continued efforts to reduce respirator usage while maintaining personnel exposures TEDE ALARA. The licensee maintained adequate control of radioactive i material to include adequate radiological survey activities. !
Fearoency Precaredness The licensee continues to maintain an effective EP program. -
Security Security upgrades made prior to the last SALP were notable. The licensee continues to maintain a very effective security program.
1 Fire Protection l
The licensee continues to maintain an effective fire protection ;
program, i Housekeeoino ,
Housekeeping has been generally very good.
I PART 3 -
SIGNIFICANT EVENTS j 3.1 SIGNIFICANT EVENTS BRIEFINGS (Past 12 Months) l l
Unit 1: None this period Unit 2: Failure of a GE AK-25 Trip Circuit Breaker T. -
3.2 ENFORCEMENT STATUS / HISTORY (Past 12 Months)
Currentlyi there is one escalated enforcement actions pending at St.
Lucie.
PART 4 -
STAFFING AND' TRAINING 4.1 OPERATIONS STAFF - OVERALL (9/95)
Average performance of the operations staff has been noted. Control room demeanor of personnel is above average.
Number of Shifts: (RCO, SRO) Five shift rotation, 8-hour shifts; (NPO, ANPO, SNPO) Five shift i rotation, 8-hour shifts. 1 Number of SR0s: 38 active /13 inactive / 51 total I Number of R0s: 23 active /l inactive / 24 total i
1 4
17
- Total Licensed Operators
- 61 active /14 inactive / 75 total
) 4.2 WORK FORCE (8/94)
EEL Contractor 4
Plant personnel (excluding 699 122 disciplines below)
Training 64 0 Quality Assurance /ISEG/ SPEAK 0UT 39 0 t Materials Management 47 0 I Security 11 122
)
- j. Site Engineering 48 0 4.3 OPERATOR OUALIFICATION/REOUALIFICATION PROGRAM (Past Two Years) 4.3.1'REQUALIFICATION PROGRAM Last Inspection - 9/26/94, Inspection Report 50-335,389/94-19 Next Inspection'- 10/96 4.3.2 INITIAL EXAMS '
Last Exams 10/17/94 - 2 RO 2 passed for 100%
9 SRO 9 passed for 100%
Next Exam 3/25/96 - 6 RO 4.3.3 GENERIC FUNDAMENTAL EXAM-Next Exam 10/3/95 - 1 applicant 4'4- PLANT SIMULATOR The simulator. is on site and fully certified to meet ANSI /ANS 3.5, 1985.
4.5 INPO ACCREDITATION All training _ programs are maintaining INPO accreditation. The site specific simulator has been used for training since 1988 and has been fully certified for approximately 5 years. NRC inspections in the form of operator examinations at the simulator have found no serious.
problems.
i-l 18 ;
[ PART 5. - INSPECTION ACTIVITIES 3 1
5.1- INSPECTION FOLLOWUP OPEN ITEMS
SUMMARY
(UNITS 1 AND 2 COMBINED)
(10/6/94)
?
! Pre Change from Division ~ y_ M Last Reoort f- DRP O 18 -
12
- , DRS 0 14 7 -
j- DRSS ._q _.1, -I h Totals 0 33 -6 Note: Each item that applies to both units is counted as one item.
5.2 MAJOR INSPECTIONS IR-No. Qg.tg Iy.gg :
89-02 1/89 RG-1.97 ,
89-03 3/89 NDE 89-07 3/89 EQ 89-09 3/89 Design Control ,
89-24 10/89 Maintenance Team Inspection I 89-27 11/89 E0P Followup 90-09 4-5/90 OSTI ,
91-03 u. 2-3/91 EDSFI l 91-18 9/91 MOV (no negative findings)91-201 9-10/91'- Service Water Inspection 4 92-14 7/92 Emergency Preparedness Program 92d7 7/92 EDSFI Followup .
33-01 1/93 Check Valves '
94-11 5/94 MOV Followup 95 '05 6/95 Engineering !
5.3 PLANNED TEAM INSPECTIONS ,
None 5.4 INFREOUENT INSPECTION PROCEDURE STATUS
~
.No core mo'dules are overdue at this time.
5.5 SIMS STATUS - OPEN TMI ITEMS There are no open TMI items.
p m
b h
NRR ASSESSMENT FOR ST. LUCIE September 1995 1
i l
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 anticipates l closure after an audit to be conducted later this year.
-Unit I will be replacing steam generators in 1997. The licensee is well into planning for the event.
-Recent events at the plant may be an idication of deteriorating performance.
Contact:
Jan A. Norris 415-1483 l;
I
]
- J
i 1
l PREDEC:SIONAL
- i I
i egea: i )
5~ ~ -" - - " ~ ' ' Si- -
ST. LUCIE 1 ee.u r , e %,
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PREDECISIONAL ST. LUCIE 1 'S*
- 5 " ' = 5 5"'" * ="" "'
- eer Grouo: Comoustion Engineering * < c ::C l ~ '
32-3 to 95-2 *renos cno Cewetioes **'
H,ont 3evfGlions I'Om Seif _'er.c zeer Grouc Median Snort erm _ona Term r
OPERATONS (including startuo) :ecune e ve n ese Better
. i Automatic Scrcyns While Critical .
l l 022 -
-0.34 i t
Sofety System Actuations - o -
-3.44 i l i
a Significant Event: . : -
I: 1 4
Sofety System foikses . ;;; .
i i .__ ': )
Cause Codes (ALL LERs) I
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i l Sofety System Actuotions -
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4 i
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c.e M 0 -
] o.11
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. Not Calcated f or Ooerot.onoi Cycw
ST. LUGlE ~1 Trends & Deviations eneoecisiow^'
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Shaded Regions: Inadequate phase time in last 2 quarters to update calculations
PREDECISIONAL i
PI EVENTS FOR 94-4 NONE PI EVENTS FOR 95-1
DESC : A REACTOR TRIP RESULTED FROM A LOW STEAM GENERATOR LEVEL AFTER A STEAM GENERATOR LEVEL INSTRtMENT FAILED MIGH, CAU$1NG THE FEED REGULATING VALVE TO CLOSE.
PI EVENTS FOR 95-2 NONE 4
4 1
, l
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d PRIDECISIONAL 4
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a :: ores. *: 41 i statuo i ST. LUCIE 2 -
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PREDEC:SIONAL 5 = * *' 5 ' ""'" =
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m.
- eer Grouo C:mous:.cn Enginee<ir g = , c COC :
12-3 to 95-2
- ems :nc Cevictions 3 evictions From
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Automatic Scrcms WMe Criticci - lc - c.e
- I Sofety System Actuations - ,' a -
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PREDECISIONAL l
j ST. LUCIE 1
)
l PI EVENTS FOR 94-3 )
i
, NONE '
- PI EVENTS FOR 94-4 i SSF 10/23/94 LERf ?!3594006 50.728 27940 4 PWR HIST
- CONDITION EXISTED IN ALL MODES UP TO 100% POWER $!NCE 1978.
GROUP : CCBITAIMMENT AND CONTAINMENT !$0LAT10N GROUP SYSTEM : REACTOR CONTAllFMENT BUILDING
! DESC
- A DESIGN ERROR COULD MAVE ALLOWED CROSS TRAIN PRESSURIZATION OF AN IDLE CONTA!NMENT SPRAY PtBIP s RESULT!NG IN A RELIEF VALVE LIFTING AS CONTAINMENT SUMP INVENTORT LOSS TO THE AUMILIARY BUILDING l IN EXCESS OF DESIGN LIMITS. t
a- DESC : A REACTOR TRIP FOLLOWED A MAIN TURRINE TRIP. THIS OCCURRED WNEN A FAULTED SWITCH YARD POTENTIAL TRANSFORMR CAUSED A ttAIN GiNERATOR LOCKWT.
SSA 11/22/94 LER# 33594009 50.728: 28060 PW MIST: COLD SMUTDOWN ;
DESC , BOTM EDGS STARTED ON AN $! AS. ONE EDG LOADED ITS SUS WHEN AN ASNORMAL ELECTRICAL LINEUP COMINED WITH ADDIT!DNAL LOADING FROM THE S!AS CAUSED THE BUS BREAKER TO OPEN.
SSA 11/22/94 LER8 33594009 50.728: 28060 PWR HIST: COLD SMUTDOWN DESC AN SI AS DCCURRED WHEN TWO OF FOUR PRESSURIZER PRESSURE TRANSMITTERS DRIFTED MIGH DUE To ENTRAPPED HYDROGEN. THE CHARGING PUMPS WERE SECURED BEFORE THE LTOP SETPOINT WAS REACHED.
SSA 11/24/94 LEPs 33594010 50.728: 28068 PWR HIST: COLD SMUTDOWN DESC : AN INADVERTFNT SAFETT INJECTION ACTUATION SIGNAL CCCURRED DURING REACTOR PROTECTIVE AND ENGINEERED SAFEGUARDS SYSTEM TESTING WNEN A PRESSURIZER PRESSURE BISTABLE TRIPPED. THE CAUSE WAS A DEFICIENT PROCEDURE. .
PI EVENTS FOR 95-1 SSA 02/16/95 Leas 33595001 50.728 28400 PWR MIST: POWER OPERATIONS AT 100% i DESC WWILE RESTORING A SAFETY RUS TO A NORMAL LINEUP FOLLOWING RELAY REPLACEMENT, THE BUS WAS DEENERG12ED. THE EMERGENCY DIESEL STARTED AND LOADED ONTO THE BUS.
PI EVENTS FOR 95-2 NONE i
h 9
NRR ASSES 8 MENT FOR ST. LUCIE september 1995 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 anticipates closure after an audit to be conducted later this year.
-Unit 1 will be replacing steam generators in 1997. The licensee is well into planning for the event.
-Recent events at the plant may be an idication .of deteriorating performance.
Contact:
Jan A. Norris 415-1483 I
9
October 19, 1994 ST LUCIE l Briefing Paper for November 1,1994, Senior Management Briefing 4
A. Current Plant Status Unit I has been operating at power since June 11, 1994. The next refueling outage is scheduled for October 31, 1994.
Unit 2 has been operating at power since July 15, 1994. The next fefueling outage is scheduled for October 1, 1995.
B. Manaaement The licensee made the following organization changes effective September 1, 1994:
C. A. Pell, former site Services Manager, became Outage Manager, reporting directly to the Site Vice President. C. Scott, former Outage Manager, reports to Mr. Pell.
J. West, former Operations Supervisor, became Services Manager.
C. Wood, former Assistant Operations Supervisor, became Operations Supervisor.
. L. McLaughlin, former Licensing Manager, was added to the Steam Generator Replacement Project Team, reporting to R. Sipos.
R. Dawson, former Maintenance Manager, became Licensing Manager.
J. Marchese, former Turkey Point Construction Services Manager, became St. Lucie Maintenance Manager.
Also, D. Denver, from FPL nuclear technical support in Juno, became site Engineering Manager. He replaced J. Hosmer, who left FPL.
C. Plant Performance The units have experienced more reactor trips than usual. During the last year, there were six reactor trips plus one unit shutdown and one unit offline for maintenance:
November 2,1993 - Manual trip of Unit 2 in response to increasing main generator hydrogen temperature.
January 9, 1994 - Manual trip of Unit 1 in response to a main feed pump trip due to a control circuit failure.
March 28, 1994 - Automatic trip of Unit I caused by a maintenance foreman opening the generator exciter field breaker (on the wrong unit).
2 April 3, 1994 - Automatic trip of Unit 1 due to procedural error in powering the A emergency bus from the A EDG for maintenance. .
April 23, 1994 - Automatic trip of Unit 2 during maintenance due to pre-existing RPS cabinet wiring error.
June 6,1994 - Automatic trip of Unit I caused by storm blowing aluminum flashing across two phases of main transformer output. .
4 July 8,1994 - Unit 2 was taken off line (Mode 2) because the 281 RCP lower oil level indication failed, incorrectly ' showing a leak.
July 14,1994 - Unit I was shut down to allow repair of a stuck-
- closed reactor trip circuit breaker.
The six reactor trips had no identified common causes. Operator performance on the trips was good.
4 D. Performance Indicators St. Lucie performance indicators indicate above average performance of both units, but with a recent increase in automatic scrams, f E. Enforcement History
. There have been no escalated enforcement actions in 1993 or 1994.
LAn enforcement panel was held on September 12, 1994, regarding operation of the 1A EDG in an electrical lineup for which the TS-required .
surveillance testing had not been performed (with the safety-related i swing bus powered from the 1A EDG bus). This issue is currently unresolved pending further NRC assessment of safety significance based ,
upon results of licensee completion of TS-required testing for this lineup in November, 1994, during the scheduled Unit 1 outage.
l l
F. SALP Period ended May 1992 Period ended January 1994 Operations 1 1 1
Maintenance 1 Engineering 1 1 Rad. Con. 1 Security 1 Emerg. Prep. 1 SA/QV 1 Plant Support 1 ,
1 i
i l
- 1. !
!. 3 i r
, G. JE0 A~ l INP0' assessment March 1992 - Category 1 !
INP0/WANO assessment April.1994 i
Next INPO_ assessment scheduled for August-0ctober ,1995 H '. 1994' Precursor Events On March 18, Unit 2 operators stopped shutdown cooling for six minutes, )'
- as a precautionary protection for pumps, until conditions were assessed
- - after a misanalyzed clearance resulted in automatic valve realignments that secured flow to one of two operating trains of shutdown cooling.
The NRC assessed the temporary cessation of-shutdown cooling as a conservative action by operators.
On July 8,1994, Unit 2 operators entered TS-3.0.3 (with both trains of -
l ECCS inoperable) due to improperly placing the 2A1 LPSI pump and the 2B -
charging pump 00S at.the same time. The NRC assessed this event as not ,
- constituting a violation of TS or a loss of ECCS capability since the 1
]
time-in 3.0.3 was less than one hour and all other ECCS' equipment in j both trains was operable. Also, the licensee took prompt action to .i b enhance the process'for placing equipment out of service to avoid any L future similar occurrence.
- . 1. -Alleaations and DOL Cases t
Five allegations are open: one drawing control; one area evacuation i
l F . ability (bridge maintenance); one negative performance appraisal;.one ;
- security guards -: insufficient number, drinking, etc.; and one licensed !
I operator overtime policy.
No 00L cases are open.
J. Attachments
- 1. Organization Charts '
- 2. Power Profiles
- 3. Plant Status Report 4.- Events Matrix i
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4
ST. LUCIE 1 Operational Period January 1,1994 through October 5,1994 23 4 5 1 -
100 -
On January 9. 1994 Unit I was meanually tripped trhen the la
- 1. Post trip response was p Main Feedwater Pump opuriously tripped.
=* r="2 *"* t"* "a i r - *"'"" * * * - ' aa 3 "" 'r 2 -
E a- 2. On m rch 28, 1994 Unit 1 experienced an autcasatic reactor trip when a maintenance foremen opened the generator exciter breaker R ton the wrong unit). We unit was restarted on April 2.
- 3. On April 3, 1994, daring unit restart, Unit 1 automatically tripped from 196 power due to an abnormal electrical lineup -
E _ with the A emergency bus (and its para 13eled CEA IIG eet) powered by the A EDG - which caused several Unit 1 returned reactor to trip power on N breakers to open on overcurrent.
April 4 1994.
- 4. On June E, 1994. Unit I automatically tripped during a severe thunderstorm as a result of aluminum flashing from an adjacent building being blown acrose two phases of the 1A sain transformer output. The reactor wee taken critical on June 8 f ==* ==== 4 =a tia ea a a 22 art - ia tr a car 9 ir-O were ieted.
o=
uait 2 We- atunit arr was <"od ai aa ^=s=== 28 ca r e ir lia- returned W 20 -
5-leak.
to power later on the same date.
l
{ 1 I
R 1 111111111llll1111:3111:331311ll'inilitillingitsllltigigggigigggggggggggggggggggggggggggg tilIliltlilililitillillittiillilillilllilI'l J A S O F M A M J J -
PERIOD OF OPERATION ,
Graph does not include power reductions for routine repairs, waterbox cleaning, or required repairs.
ST. LUCIE 2 Operational Period January 1,1994 ,
through October 5,1994 1 2 34 i
~-
100 -
P E 80 - 1. On February 13, 1994 Unit 2 woe shut down for the 1994 refueling outage. The outage lasted 65 days and the unit was R restarted on April 19.
C 2. On April 23, 1994 Unit 2 automatically tripped due to an RPS wirin. - - *ich -ire ted it-ir E si _
Fry c ai-t ==c et-during RPS troubleshooting. 1he wiring error had existed since oit=- ===4 i
=a orisia i =c c==r or ta c nia t-N to power on April 26, 1934.
T 3. On July S. 1994, Unit 2 was taken off line (teode 2) because the 251 RCP lower oil level indication f ailed, incorrectly showing l
i a leak. The unit was returned on line on July 10, 1994.
%- 4. On July 14, 1954, Unit 2 was shut down to allow repair of a stuck-closed trip circuit breaker. The unit was restarted and placed on line on July 15, 1994.
O. ,
W 20 -
't E
R O nmimmimnn mmunmmmumumi n immmimmumumumimii nmnmmmummmimmimm A M J J A S O J F M PERIOD OF OPERATION Graph does not include power reductions i
for routine repairs, waterbox cleaning, or required repairs.
c
4 L
i i
t .
! OPERATING REACTORS EVENTS BRIEFING 94-25 i
i LOCATION: 0-10B11, WHITE FLINT l WEDNESDAY, JULY 20, 1994 11:00 A.M.
1 4
i l
.00PER EMERGENCY DIESEL GENERATOR LOAD l
SHEDDING TEST DEFICIENCIES r
i i
SAINT LUCIE, UNIT 2 REACTOR TRIP BREAKER FAILURE '
DURING SURVEILLANCE TEST PRESENTED BY: EVENTS ASSESSMENT BRANCH DIVISION OF OPERATING REACTOR SUPPORT, NRR
f i
94-25
[ SAINT LUCIE, UNIT 2
- REACTOR TRIP BREAKER FAILURE DURING SURVEILLANCE TEST
! JULY 14, 1994 l PROBLEM:
L FAILURE OF A REACTOR TRIP BREAKER TO OPEN DURING A l SURVEILLANCE TEST.
l CAUSE:
! BREAKER OPENING PREVENTED BY FOREIGN MATERIAL LODGED IN j TRIP LATCH AREA.
l 'ETY SIGNIFICANCE:
' J PEARS TO BE A GENERIC PROBLEM WHICH MAY BE MORE SIGNIFICANT FOR BREAKERS USED IN OTHER APPLICATIONS OR i INSTALLED IN NSSS OF OTHER VENDORS.
L
- DISCUSSION
! e ON JULY 14, 1994, DURING MONTHLY REACTOR PROTECTION SYSTEM (RPS) LOGIC MATRIX TESTING, TRIP CIRCUIT BREAKER 5 (TCB5), GE MODEL AK 2-25, FAILED TO OPEN (FIGURE 1) .
e OPERATORS UNSUCCESSFULLY ATTEMPTED TO OPEN THE BREAKER FROM THE CONTROL ROOM. THE BREAKER ALSO COULD NOT BE OPENED LOCALLY BY EITHER ELECTRICAL OR MECHANICAL MEANS.
1 CONTACT: N. FIELDS, NRR/ DORS /EAB AIT: R0_
REFERENCES:
MORNING REPORTS 2-94-0058 SIGEVENT: IBD.
AND 2-94-0059
i
] SAINT LUCIE 94-25 i
l e TCB5 HAD SUCCESSFULLY OPENED ON THREE PREVIOUS i OCCASIONS IN RESPONSE TO PREVIOUS STEPS IN THE j SURVEILLANCE PROCEDURE.
i
! e TCB5 IS ONE OF EIGHT REACTOR TRIP BREAKERS IN THE ONE-l OUT-OF-DIO TAKEN TWICE REACTOR TRIP COINCIDENCE LOGIC.
l
) e THE LICENSEE ISOLATED TCB5 AS REQUIRED BY TECHNICAL j SPECIFICATIONS AND BEGAN A REACTOR SHUTDOWN.
L l e INSPECTION OF TCB5 FOUND THAT A SMALL PIECE OF PHENOLIC MATERIAL FROM THE CUT 0FF SWITCH BODY (PART OF THE ANTI-PUMP CIRCUIT) HAD BROKEN OFF AND BECOME LODGED IN THE
! TRIP LATCH MECHANISM, PREVENTING ITS MOTION -(SEE FIGURES 2 AND 3).
THE LICENSEE SPECULATES THAT A LOOSE MACHINE SCREW,
) e ATTACHING THE CUTOFF SWITCH TO ITS MOUNT, ALLOWED THE l
SWITCH TO MIGRATE SUCH THAT ITS BODY WAS DAMAGED AS A i RESULT OF COMPONENT MOVEMENT DURING PREVIOUS BREAKER l OPERATIONS.
i
! e GE SERVICE ADVISORY LETTER 303.0, ISSUED APRIL 6, 1989,
! INFORMED OWNERS OF AK 25-1 BREAKERS OF THE POTENTIAL FOR CUT 0FF SWITCH BODY CRACKING. THE LICENSEE STATED
! NO KNOWLEDGE OF SAL.
l l FOLLOWUP:
j e LICENSEE AND A VENDOR REPRESENTATIVE INSPECTED ALL i SIMILAR UNIT 2 BREAKERS. SWITCHES WERE FOUND WITH
! SCRATCHES OR " MOLD MARKS" BUT NONE OF THE CONDITIONS l WERE JHDGED SIGNIFICANT. NONE OF THE CUT 0FF SWITCHES WERE FOUND WITH LOOSE SCREWS.
{
4 1
SAINT LUCIE 94-25 e REGION II IS REVIEWING THE EVENT AND LICENSEE ACTIONS i
IN LIGHT OF THE TECHNICAL SPECIFICATION ACTION j STATEMENT.
j e THE REGION WILL DRAFT AN INFORMATION NOTICE DESCRIBING
- THIS EVENT. l i
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j ST. LUCIE PLANT
- MAINTENANCE PROCEDURE NO. 0920071, REVISION 2 l PERIOD!C MAINTENANCE OF MEACTDR TE1P SWITCHGEAM AND BREAKERS i
! RGURE 12 l AK 2 ENEAKER PRONTVWW i
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March 23, 1994 i
l ST LUCIE l Briefing Paper for April 7,1994, Senior Management Briefing i
A. Current Plant StatjLs.
, Unit I has been operating at power for 71 days, with the next refueling l outage scheduled to begin in October 1994.
i Unit 2 is in day 38 of a scheduled 45 day refueling outage.
B. Manaaement and Oraanizational Chances There have been no major management changes since the last Senior Management Meeting.
C. Plant Performance The units ran fairly well in 1993. There were five reactor trips and one TS required shutdown ir. 1993:
May 21, 1993 - Manual trip of Unit 2 in response to seven CEAs dropping into the core due to electrical faults.
May 30, 1993 - TS-required shutdown of Unit I due to unlatched CEA 1 discovered during post-refueling startup physics testing. l Septe m r 18, 20, and 22, 1993 - Three manual trips of Unit 1 in i response to jellyfish clogging intake screens. l November 2, 1993 - Manual trip of Unit 2 in response to increasing main generator hydrogen temperature.
There has also been one reactor trip in 1994:
January 9,1994 - Manual trip of Unit 1 in response to a main feed pump trip due to a control circuit failure.
On February 17, 1994, the St. Lucie SALP presentation was conducted at the site. St. Lucie received Category 1 ratings in all functional areas for the second consecutive time.
On March 16, 1994, during the Unit 2 refueling outage, the licensee discovered boron residue under one of the four pressurizer steam space instrument nozzles. Dye penetrant and eddy current testing revealed
- indications in three of the four nozzle-to-pressurizer welds inside the pressurizer. These are the same 3/4-inch pipe diameter instrument nozzles that were repaired one year ago. At that time, the Inconel 600 nozzle pipe was replaced with Inconel 690.
The licensee is planning to install a one-cycle Code repair to all four
, nozzles. That repair includes: analysis of the existing indications i
with fracture mechanics and leaving the existing nozzle-to-pressurizer
~
i i
l 2
l welds in place; cutting off all but a stub of the existing nozzles; and l rewelding the existing nozzles to the outside of the pressurizer. These repairs will extend the refueling outage by about two weeks. The licensee needs NRC approval to use Inconel 690 equivalent weld material and to leave the existing nozzle-to-prossurizer welds in place. .
j D. Performance Indicators 4 St. Lucie performance indicators indicate above average performance of both units.
E. Enforcement History I There have been no escalated enforcement actions in 1993 or 1994.
F. SALP Period ended May 1992 Period ended January 1994 Operations 1 1 Maintenance 1 1 Engineering 1 1 Rad. Con. 1 !
Security 1 1 Emerg. Prep. I l SA/QV 1
)
Plant Support 1 G. INPO l 1
INP0 assessment March 1992 - Category 1 !
Next INPO assessment scheduled for April 1994 q H. 1993 Precursor Events 1
None I. Allecations and 00L Cases Two allegations are open: one drawing control and one alleged drug.use by a contract employee.
One 00L case is open; discrimination - DOL action pending J. Attachments
- 1. Organization Charts
- 2. Power profiles
- 3. Plant Status Report
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Operational Period August 1,1993 through March 23,1994 !
i 1
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gump tripped due t. a control circuit fallere. The unit was returned on
+ eIne on Jeneary 10.
Q 20 -
E R !
h o ninnninunnnn unnnninininininninninunnunnnin inunninnninnonnnnnini -l' A S O N D J F M PERIOD OF OPERATION l
Graph does not include power reductions for routine repairs, waterbox cleaning, or required repairs.
i
. - . _ . -- _N
_.__ . . . . _ . _ _ . _ . . . . . . _ _ . . ~ - _ _ . _ . - _ _ _ _ _ _ _ . - - - - - - . _ . - . _ _. . . _ _ _ _ _ _ _ . _ _ _
t ST. LUCIE 2 Operational Period August 1,1993 through March 23,1994 1 2 3 ,
100 -
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E 80 - [
R ~
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- 1. m nose.6eri,im , nii:
- 'esti.e. ,r rorraien nessener a, e eret.re me.eiir trspeed the salt se e.reducedse m .
T response te lacreasies seis generator hydrogen inspareiere. hit a mes retareed to M poner se Rooseber 3 end was subsequestiy returned to 40 - sees , e se seceaner is, i m .
- 3. On February 13, 1994 Unit 2 was shut down to begin a scheduled 45-day refueling outage. .
Q W 20 -
E i R
0 n unmunmumunnumunnun nunnmunnmunununmmummum mumunnmni M O N D J F A S PERIOD OF OPERATION ;
Graph does not include power reductions for routine repairs, waterbox cleaning, or required repairs.
ST. LUCIE- I ,. .
Operational Period Marcli 13, 1993 through October 6,1993 2 3 1 -
1(H)
P E 80 -
R I.
Unit I shut down for . scheduled refueling outage on March 29 isis, and resterted on n.y 2s. ines. ,,
C E 2. on nay so, i m , unit i he an . torc.4 shutoo.n due to indications **"'r 60 - ' a ""' ' ' '**d '' d th' * ****rd d""'
"""' ' *"for N physics testing. The unit remained off line untti June 22 reeairs to tra 7 (aae at a ceatrai reds had =aiatched traa the T extension sh.ft) .n4 repairs to the RCp IA2 shart seal.
- 22. 1993.' Unit I
- 3. On September 18 and again on September 20 and September 40 - was .anuaiiy tripped <trom 7s. ss. 4 its power) due to jellyrish p clogging the intake travelling screens, which required immediately unit I operated at 7' stoppins the arrected circuiating ater pumps.
O various reduced power levels for about two weeks due to the unusual .
N 20 -
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PERIOD OF OPERATION Graph does not include power reductions for routine repairs, waterbox cleaning, or required repairs.
ST. LUCIE 2, ,
Operational Period March 13,1993 through October 6,1993 1 2 3
=
=
100 -
P, E 80 _
R -
- 1. On January 13, 1993,tinit 2 was manually shut down to repair the
- p. a cr.cied snart pius tor and pu.,
C 2ni roeier c.oia.: ,
rotating parts were replaced. The unit remained down for repairs E 60 - 'a 'aar 8"*'as Pr'55"r'r 'a5traa'*at aa225 'ad restarted on March 31, 1993.
"'5 'h'a
- 2. On May 21. 1993, Unit 2 was manually tripped from 72% power by T operators in response to seven CEAs dropping into the core. The cause was found to be electrical ground faults in five CEA control 40 - wires in t.. modules (tubes) in one shield building penetration.
P arter repairs. the = nit was resiarted on nar 2s. is93. !
O 3. Unit 2 was i den off H ne on August 9, 1993, for three days due to steam generator the lstry problems caused by a condenser tube i W 20 - 3**k-E R
0 nmn m u nu nu nu nunu 'n uinunununu ninimimn" un n uin nu u n u ninn A S O hl A hl J J PERIOD OF OPERATION Graph does not include power reductions for routine repairs, waterbox cleaning, ;
or required repairs.
I
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