ML17229A044
| ML17229A044 | |
| Person / Time | |
|---|---|
| Site: | Saint Lucie, Hope Creek  |
| Issue date: | 09/11/1996 |
| From: | Landis K NRC OFFICE OF INSPECTION & ENFORCEMENT (IE REGION III) |
| To: | Plunkett T FLORIDA POWER & LIGHT CO. |
| References | |
| NUDOCS 9609270012 | |
| Download: ML17229A044 (68) | |
Text
REGULATORY INFORMATION DISTRIBUTION SYSTEM (RIDS)
'ACCESSION NBR:9609270012 DOC.DATE 96/09/ll NOTARIZED:
NO
~ FACIL:50-'335 St. Lucie Plant, Unit 1, Florida Power
& Light Co.
50-389 St. Lucie Plant, Un'it 2, Florida Power
& Light Co.
AUTH.NAME AUTHOR AFFILIATION LANDIS,K.D.
Region 3 (Post 820201)
RECIP.NAME RECIPIENT AFFILIATION PLUNKETT,T.F.
Florida Power
& Light Co.
DOCKET 05000335'5000389
SUBJECT:
Summarizes 960829 meeting w/FPL in Juno Beach,FL re stated topics
& status of St Lucie plant. List of attendees FPL handouts encl.
DISTRIBUTION CODE:
ZE4SD COPIES RECEIVED:LTRI ENCL I
SIZE:
TITLE: Summary of Significant Meeting with Licensee (Part 50)
NOTES:
RECIPIENT ID CODE/NAME PD2-3 PD INTERNAL: DEDRO NRR/DISP/PIPB RES/DSIR/EIB EXTERNAL: NOAC COPIES LTTR ENCL 1
1 1
1 1
1 1
1 1
1 RECIPIENT ID CODE/NAME WIENSiL.
LE CENTE OGC ROED RGN2 FILE 01 NRC PDR COPIES LTTR ENCL 1
1 1
1 1
1 1
1 1
1 0
D NOTE TO ALL "RZDS" RECZPZENTS; PLEASE HELP US TO REDUCE-WASTE!
CONTACT THE DOCUMENT CONTROL DESY.,
ROOM OWFN SD-5(EXT. 415-2083)
TO ELZMZNATE YOUR NAME FROM DZSTRZBUTZON LZSTS FOR DOCUMENTS YOU DON'T N"ED!
TOTAL NUMBER OF COPIES REQUIRED:
LTTR 10 ENCL 10
September 11, 1996 Florida Power and Light Company ATTN:
Hr. T.
F. Plunkett President
- Nuclear Division P. 0.
Box 14000 Juno
- Beach, FL 33408-0420
SUBJECT:
'EETING
SUMMARY
STATUS MEETING SAINT LUCIE 1
AND 2 -
DOCKET NOS.
50-335 AND 50-389
Dear Hr. Plunkett:
This refers to the meeting on August 29, 1996, at your Training Building Room 123A.
The purpose of the meeting was to discuss the status of your plant.
It is our opinion, that this meeting was very beneficial.
Enclosed is a list of Attendees and Florida Power and Light Company Handouts.
The discussions included the following topics:
Plant Operating Report, Operations, Maintenance, Engineering, Corrective Action Program, and guality Assurance.
In addition, organizational accomplishments, challenges, lock and key switch tampering event, and the corrective actions were briefly discussed at the meeting.
Consequently, the Steam Generator Project and Services area were only briefly discussed.
We plan to more fully discuss the Steam Generator Project, Self Assessment, and Training at the next status meeting.
In accordance with Section 2.790 of NRC's "Rules of Practice, "Part 2, Title 10 Code of Federal Regulations, a copy of this letter and its enclosures will be placed in the NRC Public Document Room.
Should you have any questions concerning this letter, please contact us.
Sincerely, Docket Nos.
50-335, 50-389 License Nos.
Enclosures:
1.
List of Attendees 2.
FPSL Handouts cc w/encls:
J.
A. Stall, Site Vice President St.
Lucie Nuclear Plant P. 0.
Box 128 Ft. Pierce, FL 34954-0128 cc w/encls:
Continued see page 2
Orig signed by Kerry D. Landis Kerry D. Landis, Chief Reactor Projects Branch 3
Division of Reactor Projects 96092700i2 960911 PDR ADOCK 05000355 P
PDR OFFICIAL COPY
FP&L cc w/encls:
Continued H.
N.
- Paduano, Manager Licensing and Special Programs Florida Power and Light Company P. 0.
Box 14000 Juno
- Beach, FL 33408-0420 J. Scarola, Plant General Manager St.
Lucie Nuclear Plant P. 0.
Box 128 Ft. Pierce, FL 34954-0128 E. J.
Weinkam, Plant Licensing Manager St.
Lucie Nuclear Plant P. 0.
Box 128 Ft. Pierce, FL 34954-0218 J.
R.
- Newman, Esq.
- Morgan, Lewis
& Bockius 1800 M Street, NW Washington, D.
C.
20036 John T. Butler, Esq.
- Steel, Hector and Davis 4000 Southeast Financial Center
- Miami, FL 33131-2398 Bill Passetti Office of Radiation Control Dept. of Health and Rehab Serv.
1317 Winewood Boulevard Tallahassee, FL 32399-0700 Jack Shreve, Public Counsel Office of the Public Counsel c/o The Florida Legislature 111 West Madison Avenue, Room 812 Tallahassee, FL 32399-1400 Joe Myers, Director Division of Emergency Preparedness Department of Community Affairs 2740 Centerview Drive Tallahassee, FL 32399-2100 Thomas R. L. Kindred County Administrator St.
Lucie County 2300 Virginia Avenue Ft. Pierce, FL 34982 cc w/encls:
Continued see page 3
FPKL cc w//encls:
Continued Charles B. Brinkman Washington Nuclear Operations ABB Combustion Engineering, Inc.
12300 Twinbrook Parkway, Suite 3300 Rockville, MD 20852 Distribution w encls:
L. Wiens, NRR G. Hallstrom, RII PUBLIC NRC Resident Inspector U.S. Nuclear Regulatory Comm.
7585 South Highway A1A Jensen
- Beach, FL 34957-2010 SIGNATURE inh NAME
/ 09// //96 YES NO DATE 09/
/96 YES NO 09/
/96 YES NO 09/
/96 09/
/96 09 /
/96 YES NO COPY?
YES NO YES NO OFFICIAL RECORD COPY OOCUHENT NAHE:
G: iSTLUCIEiMEETINGiSLHTG829.SUH
ucie an a us ee in August 29, 1996
ST. LUCIE PLANT OPERATING REPORT
St. Lucie Status Meeting Agenda August 29, 1996 9:30 AM Training Building, Room 123A HR RSEEEIQQII Opening Remarks A. Stall Operating Report J. Scarola Operations C. Marple Maintenance J. Marchese Engineering D. Denver Steam Generator Project D. Sipos Services Corrective Action Program Quality Assurance C. Burton/
M. Allen B. Dawson
%. Bladow
Operating Report WWHHREIIIOll Unit One 100.0 75.0 a Taget =78.5 50.0 l5 gO Good 0.0 Dec Jan '96 May Date Nov Refueling outage ended 7/25/96 (88 days)
Turbine balance outage 8/23 - 8/24 Well planned evolution. Completed on schedule
Operating Report WWR HRERRIIHII Unit Two-10M mni P
+Q 0 Q+ R
'Q 0
Q Q
0 P
0 P >P Tarte =95 IIs a eT+
.-50.0 CI Cl oX 25.0 S~ctf kre fnmS95rdu5~
CxI+8 0.0 Jan'%eb Mar Apr May Jm Jul Aug Sep Oct Nov Dec Date 76 days on line Next outage - April 15, 1997
Operating Report
%% S ERSESIIjll 4
Automatic Reactor Trips Legend cn CL I-2 o
D'z Good Oct Dec Jan '96 Mar May Date Jul
\\
Sep Nov
~
No Automatic Trips Equipment Causes Operations to Ilrianeuver Plant 15
~
10 O
'D 0
5 0
1 QTR 2QTR 3QTR 4 QlR 1 QTR 2 QTR 3QTR But equipment failures cause Operations to respond
PSL Integrated Performance Assessment NRC IRs Since 1994 PSL IHE Reports QA Reports NPIND Division MonthlyIndicators PSL LERs Since 1994 PSL Condition Reports Independent Tecnnical Reviews Radiotogicai Detiaency Reports PSL Procedures NP-700 Probiem Reports
- PMArs Department Serf Assessments Skin 4 Personnel Ccntarrsroaons P
H A
S E
OPS Maintenance Engineering a
Plant Management Support Policies Assessment 0
OPS Maintenance Engineering S
g p
Plant Management Support Policies Underlying Causal Factors LimitingWeaknesses
OPERATIONS
Operations HHRSEESIHII Accom lishments
~
Error free Unit l shutdown/startup (8/24)
~
On shift communication improvements
~
Reduction in Operator Work Arounds Problem areas
~
Procedure Upgrade
~ Annunciator summary procedures
~ Off-normal procedures
~ Normal operating procedures
~
Centralize procedure writers group in 9/96
~
Improve watch standing techniques/ownership
~
Self-assessment meeting
~
Operator crew meetings (licensed K non licensed)
~ Nuclear plant supervisor meetings
~ Real Time Training Coach (RTTC)
~
Reduce out-of specification readings on operator logs
~ Eliminate operator complacency
~
Department Self-assessments
~
Operation crew self-assessments willbe performed by crew supervisors
~ Provide root cause training to Operations supervisors
OPERATOR WORK AROUNDS Updated and Submttted by: OST - Futrord MONTH Aug.95 Sep.95 Oct 95 Nov 95 Dec-95 Jan.98 Feb.98 Mar.98 Apr.98 May.98 Jun.98 Jul.98 Aug.98 Sep-98 Oct 98 Nov-98 Dec-98 OPEN TARGET 103 101 41 45 55 47 48 48 43 43 37 40 38 17 38 30 14 20 18 17 18 15 120 operator In performing duties within the approved procedures or In accordance with the fntended design.
100 Decrease due to separallon of OWAs from Operator tnconvenlences.
80 60.
~
~OPEN TARGET 40-
~
~ ~
Year End Target=15 20 Aug-95 Oct-95 Dec-95 Feb-96 APr-96 Jun.96 Aug-96 Oct-96 Dec-96 Time (Month)
~
~
OPERATOR WORK AROUNDS WORKING LIST Updated and Submiaed by: OST Fulford NPWO/
CR NO.
DESCRIPTION UNIT-CONIMON LvlCntrl Vlvs position indicators destroyed dunng maint.
UNIT 1 SCHD DEPT STATUS START WKG SCHD COMPLETION 1/31/97 9642-228 9642400 9643477 9643423 9643464 PCM 086-292 9603-702 PCM 251-295 96-1880 9642-287 9643413 9643459 UD pressure control vlvs are not able to control press CST kop seal gets pushed out w/ no fig in progmss. Alarms Root cause of gas surge tk moisture trap failure UNIT2 2A It28 D/G tachrxneter provide unreliable readings D/G pyrometers 8 thews have chronic loose conn, PC-11 loop 3 comm falure causes failure of audible alarms PCV48479 gland seal reg does control pressure SR-14350 lifted while testing CCW N hdr isolation vlvs V4111, iso fuel transfer tube, leaks by seat Restore PIA-1140 to original configuration when RCGVS Is frxd V4217 is leaking by the seat causing the 2A2 Sl hdr to press.
Extracdon stm trap bypass viva viillnot dose e 100% pwr TIC-2223, UDTCVis swinging causing LIDtemp to be unstable ENG SCE SCE IC IC JPN IC SCE SCE SCE WKG SCH WKG SCHD SCHD WKG SCHD SCHD SCHD SCHD SCHD SCHD SCHD 3/1/97 9/1/96 SL 2-10 SL-2-10 11/1/96 SL2-10 1/I5/97 SL2-10 SL-2-10 SL-2-10 SL-2-10 10/1 5/96 4/I/97 9/30/96 SL-2-10 SL-2-10 11/30/96 SL2-10 2i28/97 SL2-1 0 SL-2-10 SL-2-10 SL-2-10
Reactor Coolant System RCS Leakage Unusual Events WWHHHSEISOII 7/13/96 Unit 2
~
Based upon what appeared to be greater than 10 gpm leakage charging pump packing leak
~
Subsequent investigation:
~
Stuck open check valve on 2C charging pump recirculation line
~ Actions ofthe Nuclear Plant Supervisor (NPS) were conservative
~ The U.E. was retracted S/9/96 Unit I
~
InitialRCS leakrate indicates.56 gpm. The NPS orders a second leakrate calculation
~
Second leakrate indicated 1.5 gpm. Field operator notified control room 1A charging pump has a leak on center plunger The 1A charging pump was secured and isolated
~
NPS declares Unusual Event and orders a third leakrate to be performed
~
Third leakrate calculation indicated.423 gpm
~
NPS and crew perform a self-assessment ofthe event
Reactor Coolant System RCS Leakage Unusual Events W&R HRSIQIIjll Lessons Learned 0 erations:
~
Provide timely search for suspected RCS leakage
~
Keep all crew members informed ofrelevant information
~
Provide timely classification ofevent K ui ment:
~
Charging pump packing leak performance
~
Check valve performance
Man Rem 400 300 Unit 1Refuehn Out g
age
-. - Outage Budget= 310 aa eI I
c 389.042
~
~ gg g yg A l%
e X
325.497 without unplanned S/G work 200 K
100 Target
~Aclual 0
Jan Feb Mar Apr May Jun Jul Aug Sept Oct Nov Dec Time {Month)
Personnel Contarninatlons 100 Unit 1 Refueling Outage 93 80.
e 70 C
60 50 40 o
30
~
20
~
8, y
~
~
Target
~Aclual 10 0
Ja
~
~
~
~ ~ ~ r ice e
n Feb Mar Apr,'ay Jun Jul Aug Sept Oct Nov Dec Time {Month)
'T. LUCIE PLANTCONTAMINATEDFLOOR SPACE 4500 4000 -
3500 3000.
cr 2500 Post outage recovery of contaminated floor space.
~
~
~
~
~Actual
Target nt 2000 1500 1000 500 IneccessKe cree fottowintr Benctvnerktntr wkh Turkey Pohl end keettjrtt with tndustrkr rrrecttces.
Unit1Refuetin Outa e
Sep-Oct Nov 95 Dec Jan-Feb Mar Apr May June Jul Aug Sept Oct Nov Dec 95 Time (month)
Unit 1 CPI (Chemistry Performance Index)
Vn4 1 StathO F<<m Rch&nO Oval 1.30 CO I
CP 1.20 GOAL ~
1,25 I.IO
~
DAI' CPI OTR AVGCPI 15555>/i//<i<5i555555/(N55555i[
DATE Unit 2 CPI (Chemistry Performance Index) lO I
I7 CJ GOAL~
1.25 1.10
~ ~
~. ~ ~ DAILYCPI OTR AVGCPI sji5i<
(imim555i/555/iii5555N(
DATE
MAINTENANCE
Maintenance
%% R ERSEIIIHII
~
Accom lishments Pressurizer Code Safety Valve upgrade Steam Bypass Control Valve upgrade
~
Problem areas Charging Pump Packing Performance Maintenance Rule A(1) Equipment
Pressurizer Code Safe Valves W&%RHREIISI9II Problem Long standing repetitive equipment problem:
Leakage through valve caused plant shutdowns and extended refueling outages Operations work around (reduced RCS operating pressure)
Actions
~ Reduced nozzle tailpipe loading on valves (93-94)
~ Installed flexi-disc designed internals (93-94)
~ Upgraded pressurizer insulation for thermal stability (94-95)
~
Replaced valves with heavy body forged valves - Unit 1 replaced in 96, Unit 2 next outage (97)
Results
~ Zero RCS leakage through valves
~ Eliminated operator work around and returned to fullRCS operating pressure 15
Steam Bypass Control Upgrades HRS ESEENIIOI!
Problem Long standing equipment problem:
Repetitive maintenance Presented plant control problems to Operations Actions Replaced actuators (design change)
~
Replaced valve trim (design change)
~ Replaced valve operator
~ Installed test ports for flowscan testing Results
~ Control system proven reliable during shutdowns
~
Standardized equipment on both units
Charging Pump Packing Performance HR0 SESSIaIHI!
Problem Packing leaks led to:
Repetitive Maintenance Forced off-normal operations Actions e
Established repack criteria
~
Operations monitoring pump seal tank level
~ Formalizing repack criteria in Operations procedure
~
Develop root cause of short packing life - Unit 1
~ Monitor results
4000 Unit 1
Charging Pump Packing Performance 1994 1996 3000 2000 1000 0
CdID Gl 1994 o
CD C9 0)O T
1995 r r/
/ /
r r
/
/
~4i~i
/
r r/
r r
~8"%"%'
r/
////
r r 1996 r/r
/
PSL Target 2000 hrs 1A Chg PP I
1B Chg PP 9
1C Chg PP Industry Avg 1100 hrs
Unit 2 Charging Pump Packing Performance 1994 1996 6000 5000 thI Ul E D
~
m ~
p K 4000 1000 0
Q. U)
E.c 3000 CL O
Ul Q.
2000 OOO lA J
J/ /
/ /
r r
~ J r
/ J
/r r/
J J/ /
1994 1995 O
C4N J
Jr r
/ r
/
J r
/ /
/ /
/ //
r J J r
/ //
J /
~
~ r r
/ /
/ rI r J r r J /
/
1996 5
2AChg PP I
2B Chg PP 9
2C Chg PP PSL Target 2000 hrs Industry Avg 1100 hrs
F' r
ST. LUCIEPLANT MAINTENANCEPROCEDURE UPGRADE PROJECT TASK ff1: DEVEI.OP PROCEDURES/GUIDELINES FOR FREQUENTLY PERFORMED MAINTENANCEACTIVITIESWHICH CURRENTLY EMPLOY THE USE OF VENDOR TECHNICALMANUAI.S
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Orr,t&56LWROM IO/31/98 II/30/98 rdC V1 nrmetr Ckp 0 ra ll<<nProc Mon IO/31/90
'r&C Ul 6.2Ccnel ol Proc MorilRdny II/3008 MECH
<CECH We<<on Hydra<Ac
/kme5bvry Valves elves IO/3</90 It/30/90 MECH Vskor Eny Valves 10/31/96 MECII
~I<at/re Vs<res 11/30/90 r&C rd C Ul &02R<bvldn CEOMCabte fCV 12 I RcpN 10/31/90 II/30/98
'4C I<00065: Add tlevr E<S/pm<re 12/91/90 clddstt.t/I/t",9',:,,:
<2/31/90@<":: 0:i 4C lec 150<k<<<5 Cs'<bra'Ion Ir/31/90 1&0 U2 Saleyvkrdc Mclccs Caa 12/3168 MECH 0
4C Roc<moore Iran<cry<era I/3</90 MECH to/yet Roclr VsM<5 I/31/96 4C CP-2.1600023 r&CP/ocedvre I/3</91 rdC rlr 8 anon Hyd. A<bra<<<5 I/3</91 MECH R<<vy fran Valves 2/3</96 v<ECH 8<<y Wamrf Valve a 1/3'I/96 12/31/96 evetcp any remsbtny PSL 2 Place Spa<ac Aocedvret
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POWER BLOCK PWO BACKLOG Joe lmarchese - Maintenance PWO Backlo PWO backlog are non-outage trouble & breakdown work orders on components/equlpment ln the power block.
Total includes all other work orders (Non T/B WO's, Outage WO's, Projects).
900 600 700 600.
00 500 400 300 200 t00 TOTAL-"1697 g
W H
W W
Legend -Wta Good ix Tolsl
~ Terget Tslgel ~ 2lN Tetol Sep Oct Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct
'95
'96 Date Dele Sowce: peeepet
SUMMARY
STATUS Dlscfpllne Mechanical Electrical 1&C ProJects Total Unit 1 42 93 s
0 146 Unit 2 76 103 184 Common 18 0
33 Total 17 214 363 (8/23)
AGED PWOs > 'l2 MONTHS Joe Marchese - Maintenance
~Aed PWOe:
Non.outage corrective maintenance work type 5 PWOs older than 12 months.
80 70 Legend 60 0
N5o
>40 ds 30 0
20 to Tergal Target ".0 Sep Oct Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct
'95
'96 Date Dere Serrrcer pessrerr SUMINARYSTATUS Unit 1
,Unit 2 Common Total Mechanical Electrical I&C Construction Total 0
0 0
0 0
0 0
0 0
16 Oldest PWO
//
Discipline 7/25/94 0562 ROTATING 4/29/94 2990 ENGR
~eM
CONTROL ROOM DEFIGIENGIES G-TAGS
~C-Ta s:
- The number of Control Room/Board Green Tags.
It provides an Indication of the attentfon given to mafntalnfng controlroom fnstrurnents In an operable conditfon.
80 70 80
~ - ~ ---
- ~ - ~ ~ ~-
50 I-C3 40 O
>o 30 20 10 o
"OUTAGE-6" e
e e e e e e e e
e X
"'"""""Good"" ~uo ~~i X
Tols1 e NOn CMege tagtl Moo oAtee rabbet Sep Oct Hov Dec
'05 Jan Feb Mar Apr May Jun Jul Aug Sep Oct frov Dec
'es Date Data: M, Wilffs S UMIIARYSTATUS Ready to Work or Workln Englneerlng/RTA AWP Olher Holds Total Non Outage 16 Outage 0
0 Total 24 Oldest PWO ¹ Dlscfpllne 3/11/96 6436 I&C 5/5/94 3017 I&C(OUTAGE)
ENt INEERINt /TECHNICAL
Engineering/Technical
&%R USE>818ll Aceom lishments
~
Strengthened Temporary System Alteration process
~
Plant Change modifications resolved long standing equipment issues Steam Bypass Control System Pressurizer Code Safeties Problem areas
~
Control Element Assembly Drive System
~
Nuclear Instrumentation System Upgrade
~
FSAR Status 24
Control Rod Element Drive System W&%WESII55lIII
~
System Assessment
~
3 year performance reviewed
~ Rod drop events - too high 30 25 ROD DROPS G Unit 1 Q Unit 2 20 15 10 I
77 78 79 80 81 82 83 84 85 86 87 88 89 90 91 92 93 94 95 96 1993-1996 25
Control Rod Element Drive System WWR HREISEIQll 14 Rod Drops since 1993 0 Unit 1 D Unit 2 10 1993 1994 1995 1996
~
Post 1993 Analysis I6
~ Most drops have occurred on Unit 1
~ MajorityofUnit 1 drops in the 1996 refueling
~ Drops related to:
-Mechanical sluggish grippers (6)
-TimingModule failure (2) 26
Control Rod Element Drive System RE&R RRSSSRIOII
~
Corrective actions taken
~ Established Procedures and Preventive Maintenance Weekly I8'cC system inspections Increased refueling testing
~ Initiated refurbishment program for known aged electronic components
~
Corrective actions planned
~ Review needs for additional preventive activities Coil Trending Program (12/30/96)
Enhanced flushing procedures (9/30/96)
~ Review remaining electronics for additional refurbishment needs (4/15/97)
~ ACTM modification - Unit 1 (Refueling 1997)
Nuclear Instrumentation NI System Upgrade WHQREESml5lljll Replacement project initiated for Units 1 0 2 - Fall, 1994 Unit 2 installation - Fall, 1995 - No problems during installation and subsequent good performance
~
Unit 1 Installation - 1996 - numerous installation and design problems
~
Most significant problem discovered on July 30 with the Unit at 100% power - upper and lower detector signals on power range channels found to be reversed
~
Error traced to inadequate design preparation and verification, and testing weaknesses 28
Nuclear Instrumentation NI System Upgrade W&%%%$ESI0II Summa of roblems
~
Design Preparation Conflicting information on existing plant drawings not identified and resolved Similarity between Units 1 k. 2 ass'umed
~
Design Verification No point to point wiringverification Verification performed by several individuals
~
Post modification testing Detector inputs to axial shape index (ASI) not identified as a critical function
'I
~
Power ascension program Target or expected ASI not provided in test data or trended during program Inconsistent trends in ASI behavior observed by operating crew but not adequately pursued 29
Nuclear Instrumentation NI System Upgrade WWR WSRSQlIElll Immediaie Corrective Actions
~
Corrected wiring and documentation errors 4
Verified that operation in the as found condition was bounded by the safety analysis Lon erterm
~
Validate outstanding safety related PC/Ms involving wiring changes - 10/31/96
~
Procedure changes to require all critical functions to be tested during PMT - 9/30/96
~
Strengthen requirements forverification process-9/30/96 Require same level ofverification on duplicate packages
- 9/30/96 Provide target ASI for power ascension program-1/15/97
~
Place accountability with Reactor Engineering for performance ofinstruments used to monitor core-10/31/96 30
Updated Final Safe Analysis Report WWWRRRRSIOII Assessment Status Back ound Commitment to review FSAjRs and plant procedures for consistency - corrective action from boron dilution event identified in FPI. violation response Status
~
Procedure development process change to improve reference to FSAR and Technical Specifications 30% ofUnit 1 A 2 FSAR review complete Approximately 500 editorial findings Approximately 150 findings were not safety significant, but required operability assessment Schedule
~
Review willbe complete by 12/31/96
~
Changes willbe incorporated in the FSAR with the next routine update (U2 - 12/97; Ul - 6/98)
Procedure changes willbe completed based on their significance, but no later than the next required procedure review
Anchor-Darling Piston Check Valves WWR HRRSRRIQll Problem:
2C Charging Pump Discharge Check Valve (V2167) Stuck Open Evaluation:
~
Machining anomalies identified within installed valve
~
Valve replaced with spare and returned to service
~
Pulsating service, long periods ofoperation, constant flow and machining anomalies identified as causal factors
~
Operability review completed for Unit 1 A 2 applications (17 valves total, 6 in Unit 1, 11 in Unit 2)
Generic Actions:
~ All49 spare 2" ADVpiston check valves in Stores inspected, majority found with machining anomalies
~
Vendor reported under 10CFR21, FPL notified industry
~
Further review identified fretting wear as apparent cause
~
Anchor-Darling valve design review and industry application review requested and currently ongoing
~
Material changes/reduced port valve may be recommended
Inspection Results for InstaIled 2" ADVPiston Check VaIves (As of 8-26-96)
Ta 'jl Location installed Serial ¹ PWOICWO Schedule Results V02133 V02134 V3113 V09305 V18193 V18195 Ch PP 1B dlschar e
Ch PP1cdlschar e
HPSlfeedtoLoo 1A2 AFWPP 1A dischar e reclrc to CST IAsu I lo RGB IAsu I to RGB P-9 1998 RO 1993 Ro 1996 RO 1996 RO 1996 RO 1994 SNOW ET401-9-3 E-T401-9-13 E-T401-9.8 E-T401-8-1 E-Z600-2-2 E-T488-5-2 8101-96018488 8109-96018508 8100-96018487 8102-96018493 WR 96013145 WR 96013148 WR 96013147 WR 96013148 Com lete Com late RO RO RO RO MinorFretting, Use As Is Minor Fretting, Bonnet Galled, Valve Re laced Pendln Pendln Pendln Pendln
.I 0
Ta Location Installed Serial ¹ PWOICWO Schedule Results V2167 Ch PP2Cdlschar e
V2168 Ch PP2Bdlschar e
V2169 Ch PP2Adlschar e
V2462 Chg Common Header to Re enHX Inlet V07141 CS PP 2A Reclrc to RWT V3104 LPSI PP 2A reclrc to RWT V3102 HPSI PP 2A recirc to RWT V3103 HPSI PP 2B reclrc to RWT V15328 Prima makeu water to RCB P-7 V18193 IAsu I to RCB NNS V181270 SAsu I to RCB P.8 1994 RO 1994 Ro 1995 RO 1995 RO 1994 RO 1994 RO 1994 RO 1994 RO 1994 RO 1995 RO 1995 RO E-T401-9-19 E-T401-9-21 E-T401-9-38 E-T401-9-16 E-T401-9-20 E-T401-9-10 E-T401-9.9 E-T401-9-17 E-T401-9.24 E-T401-1-6 E-T488-5-1 7220-96018092 7221-96018198 7223.96018489 7226-96018522 7224.96018491 7225-96018521 WR 96013149 WR 96013150 WR 96013151 WR 96013152 WR 96013153 WR 96013154 WR 96013155 WR 96013156 Com tete gr7N6 Com lete RO RO RO RO RO RO RO RO Fretting, Valve Re laced Pendln Minor Fretting, Use As Is Pendln Pendln Pendln Pendln Pendln Pendin Pendin Pendin RO: Inspection Scheduled for Refueling Outage
TEMPORARY SYSTEM ALTERATIONS TSA 50 45-40
~
35
~
$ 30 v-25.
o20
'l5-10.
liOOd Legend X
Total Target data as ol 8/26 Target ~ 10 0
Oct Dec Feb Apr Jun Aug Date Oct Dec Data Source:
Kris Mohlndroo
SUMMARY
STATUS Disci line Mechanical Electrical I&C En Ineerin 0 eratlons Health Ph slee Unlt1 0
0 0
0 Unit 2 0
Total 0
Preventive Malnt SCE Total Oldest TSA Disci line 0
11/17/95 I&C 0
0 5/10/94 I&C 0
0
PLANT CHANGEIMODIFICATIONS 150 Gddd " """ t.
d 125 100
~
~75
~
0 0
50
~
data as of 8/28 Open PC/M Target ~ 80 25 0
Oct Dec Feb Apr Jun Date Aug Oct Dec Data Source:
Kris Mohtndroo
STEAM GENERATOR PROJECT
Steam Generator Project W&HHWSSSRIGII Re lacement schedule Im lementation: Now scheduled for October 1997
~
Milestones Completed:
~ Implementation engineering, June 1995
~ Engineering Package FRG approved, April 1996
~
Significant work to go
~
Complete rigging engineering, May 1997
~
Complete SGRP engineering document reconciliation, July 1997 36
Steam Generator Project WWKRREEHIIHII Re lacement enerator fabrication Scheduled to arrive on site Ma 1997
~
Milestones Completed
~ Lower assemblies, June 1996
~
Steam drum assemblies, June 1996 Significant work to go:
~ Fit-up and weld drums to lower assemblies, November 1996
~ Electro polish primary bowls, February 1997 o
Secondary hydro test, March 1997 37
Steam Generator Project
&%R RSEI@IRIEIII Pro ect Schedule ActivityDescription 1
2 3
4 1
2 3
4 1
2 3
4 1
2 3
4 1
2 3
4 1
2 3
4 1
2 3
4 Replacement Steam Generator Fabrication fabllca on Qgihs fII92 Tu mg ripiete 5t96
~
~
~
~
~I rrton plqte I96' geoei
- PSl
- 5I97 Phase l Engineering gi enpg
omplete 6I95'A3 RO
~
l
~
t Pkg0 8lg'5 crNn piete Phase ll Implementation hbbi 2'Ig?
~
~
Stogge '
Faci]ity '.
~
~
~
~
gp 9lns 1 lgl Scheduled
-...:>>,Adual 38
Steam Generator Project W&R RERESRIIjII Incor orate %on-S/G work
~
Identify and obtain management approval for all Projects
~ September, 1996
~
Identify Major Maintenance work September, 1996
~
Incorporate Approved work into Schedule October, 1996
~
Freeze Outage Scope f January, 1997 Staffin Plan
~
Establish "Core" group FPL supervision October, 1996
~
Execute SGRP Contractor XFPL approved Staffing plan February 1997 to Completion 39
Steam Generator Project.
Facili Plan W&R WISESSIQII
~
Revise site plan for Replacement Project Team UtilizeNorth Service Bldg (Occupy by 1/1/97)
Consolidate project organization to one location Control contractor personnel Trainin Plan Establish SGRP Indoctrination Program
~ Train FPL Project Team.....
Engineering Packages PWO Packages Observe A Evaluate Point Beach SGRP
~
Team Building - with station organization Better interdepartmental Coordination Establish X communicate functional accountabilities 40
SERVICES
PL.
Services mm a araa@Iu<
Accom lishments Reduced number ofoutstanding temporary changes to procedures
~
Established Configuration Control Group/mission/process Implemented improved PC/M closure process Initiated real time support list for minor modifications
~
Identified Unit 2 outage top 20 modifications Problem Areas
~
Improve quality ofprocedures
~
Centralize procedure upgrade effort
~
High volume ofmaterial reviewed by FRG
~
Implement self assessment program for Training
~
Back to basics in all training programs
~
Elevate training standards/reinforcement
Training Department WHWRREESIHII Problem areas
~
Expectations not clear
~
Behind industry standards
~
Lack ofproactiveness 42
Training Department WWWHRSSIIEII Accom 1ishments
~
Reorganized department to establish clear lines of responsibility
. ~
Established Assessment Group o
Self-assessment
~ Real time training coach
~ Configuration control
~
Gave clear expectations followed by several teamwork sessions
~
Met with customers (Operations &, Maintenance) to establish rapport
~
Commenced benchmarking with Turkey Point Site VP met with staff in small groups
~
Focus activities to meet real time plant needs
~
Rev arding innovation/excellent performance 43
Training Department W&R WEE ERIHII Current new initiatives
~
Continue to attack weak plant areas
~ Procedural adherence
~ Planning ahead
~ Attention to detail
~ Workingtogether
~
Increase proactive level
~ In-fieldmonitoring
~
Catch problems while they are still small
~
World-class performance every day
~ Enforce the highest standards - never let up
~
What's important now (WIN) - fundamentals
CO CTIVKACTION PROGRAM
Corrective Action Accom lisbments WWR HESSIIHII
~
Upgraded process to specify root cause effort expected
~ Linked Condition Report (CR) procedure to site root cause procedure e
Defined levels ofsignificance/root cause Problem Areas
~
Root cause knowledge across the plant is insufficient
~
Trending ability limited until history is accumulated
~
Overdue Condition Reports Overdue Condition Reports 0
0
$1/96 6'1/96 7/1/96
$1/96 2-Aug 9-Aug 16-Aug 23-Aug
Corrective Action
&HARREERilIOII CRs Generated b uarter 1200 1000 800 600 400 200 LO CP Q
th T
LO CA L
Cf U
lA L
Cf CQ CA U
th C
46
1 L"
Corrective Action mm a mere@I m CRs Stratified b Initiatin De artment 2nd uarter 200 160
'f53 120 SD 40 82 59 50 32 0
cC O
M UJ O
I-a.
~
Q cO n
Q
(9 U
O' V) '
0 LU 47
Corrective Action WWRRWSRSIH0 Event Initiator Anal sis 2nd uarter O
t=
Ctt at ~at atl-a CttN ~
o Ctt ~ +
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a
~
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48
UALITYASSURANCE
uali Assurance WWR HSSEH8ll
~
Overall Assessment Corrective Action is still considered a limitingweakness and requires continued management attention
~ Personnel error, attention to detail, and procedural adherence are focus areas ofconsideration
~
Less than adequate determination ofunderlying causal factors
~
14 findings responses were late to QA due to process change with site VP sign off. Rejected by site VP due to shallowness ofresponse
~
uali Assurance dail re orts to lant mana ement and staff Timely quality issues raised by QA/QC Condition reports (15) written immediately for resolution
~ Examples:
Bypassed QC hold point on bolting inspection Unit 1 containment purge valves inoperable Loose debris control for Unit 1 Containment in Mode 3 49
uali A.ssurance W&R RSSEWIHII
~
ualit Assurance audits Emergency Preparedness
( 3 Findings, corrective actions, training, administration)
Corrective Action (2 Findings,'overdue CRs, inadequate risk assessment)
Maintenance Rule Implementation (IFinding, revision control, vendor interface, drawing control)
Vendor Technical Manuals (6 Findings, revision control, vendor interface, drawing control)
Performance Monitoring.(3 Findings, FSAR requirements, overtime, procedure non-compliance)
Design Control (3 Findings, PCM interface control) 50
uali Assurance W&HHWERII55ll
~
Facilitation ofSelf-Assessment Phase I, problem areas, completed July 31, 1996 Phase II, causal factors, complete by August 30, 1996 Phase III,limitingweakness, complete by September 13, 1996 Phase IV, corrective actions, complete by October 11, 1996 Phase V, implementation and monitoring, start October 14, 1996
~
Conducted 2nd Workshop on Self-Assessment and Event Analysis
~ BillCorcoran, Ph.D.,P.E. (CNRB outside FPL member)
~ August 21, 1996, 140 participants (PSL,PTN,JB)
~
Stressed fundamentals of event evaluation. corrective action and self assessment
E I
rI