ML072690529

ACRS License Renewal Subcommittee Presentation September 5, 2007

ML072690529
Person / Time
Site:	FitzPatrick
Issue date:	09/05/2007
From:	Entergy Nuclear Operations
To:	Office of Nuclear Reactor Regulation
Le, Ngoc, NRR/DLR/RLRB, 415-1458
Shared Package
ML072690486	List: ML072690528 ML072690529 ML072690537
References
TAC MD2666
Download: ML072690529 (40)

Text

1 James A. James A. FitzPatrick FitzPatrick Nuclear Power Plant Nuclear Power Plant ACRS License Renewal Subcommittee PresentationSeptember 5, 2007 2Brian FinnSite NSA DirectorJohn McCannDirector of Licensing, White Plains Garry YoungManager, License RenewalSteve BonoDirector of EngineeringJoe PechacekManager, Programs & Components James CostedioLicensing Manager Alan CoxTechnical Manager Rick PlasseLicensing Lead Larry LeiterTechnical Lead Tom MoskalykStructural Lead Arturo SmithClass 1 Mechanical Lead Technical Support Personnel James A. James A. FitzPatrick FitzPatrick Personnel in Attendance Personnel in Attendance 3*James A. FitzPatrickSite Description*Current Status

• James A. FitzPatrickLicensing History & Highlights*License Renewal Project*Cost-Beneficial SAMAs*Presentation Topics -Drywell and Torus Monitoring

-Torus Repair*Questions Agenda Agenda 4 JAFNPP Site Description JAFNPP Site Description*General Electric (NSSS & TG), Stone &

Webster (AE and Constructor)*BWR-4, Mark I Containment*2536 MWtThermal Power; ~ 881 MWe*Once through cooling from Lake Ontario*Staff Complement: approximately 650 5 JAFNPP Plant Status JAFNPP Plant Status*Startup from RFO 17 -November 4, 2006*Current Plant Status*Next outage Sept 2008 6Construction Permit May 20, 1970Operating License October 17, 1974 Commercial OperationJuly 28, 1975 UpratedPower License (4%) December 6, 1996License Transfer to EntergyNovember 21, 2000 LR Application Submitted July 31, 2006

Operating License Expires October 17, 2014 Licensing History Licensing History 7 Major Improvements Major Improvements 1978-1983 Mark I Containment Modifications1988Hydrogen Water Chemistry1989Zinc Injection1990Power UprateEquipment Upgrades 1998ECCS Suction Strainers Replaced1999Noble Metals Application2004 LP Turbine Rotor Replacement2004 Noble Metals Application 22006HP Turbine Rotor Replacement2006 OffgasCondenser Replacement2006HPCI Discharge Exhaust SpargerAdded 8 Future Improvements Future Improvements2008Main Transformer Replacement2008Core Spray Motor Replacement2008345KV Breaker Replacement 9*LRA Prepared by experienced, multi-discipline Entergy team (utilized corporate and on-site resources)*Incorporated lessons learned from previous applications*Peer review conducted

• LRA internal reviews (Safety Review Committees and QA)*All comments resolved prior to submittal JAFNPP License Renewal Project JAFNPP License Renewal Project 10*License Renewal Commitments-Refined during audit/inspection process-Tracked by Entergy commitment tracking and engineering work tracking systems*36 Aging Management Programs -17 Programs in Place w/o Enhancements-9 Programs will be Enhanced-10 New Programs*GALL Consistancy-10 Consistent

-20 Consistent with exceptions / enhancements

-6 Plant Specific JAFNPP License Renewal Project JAFNPP License Renewal Project 11 Program Implementation Plan*Develop fleet approach for Entergy plants that have submitted an LRA*Develop schedule using industry experience JAFNPP License Renewal Project JAFNPP License Renewal Project 12 Scoping of Non safety-Related Systems, Structures, and Components (10 CFR 54.4a(2))*Utilized site component database, P&IDs, and isometric drawings*Reviewed safety related cable / piping locations*Performed walkdownsfor a(2) scope verification JAFNPP License Renewal Project JAFNPP License Renewal Project 13 Scoping of Non safety-Related Systems, Structures, and Components (10 CFR 54.4a(2))*Regional Inspection verified a(2) scoping for in-plant areas and systems*10 CFR 54.4a(2) scope changes made in LRA Amendment 11*Regional Inspection concluded that JAF had implemented an acceptable method of scoping and screening of non-safety related SSCsand that this method resulted in

accurate scoping determinations JAFNPP License Renewal Project JAFNPP License Renewal Project 14 Draft SER Summary*Open Items Reactor Vessel Fluence-Environmentally Assisted Fatigue*Confirmatory Items -None JAFNPP License Renewal Project JAFNPP License Renewal Project 15 Reactor Vessel Neutron Fluence

• Current P-T curves valid through 2014 (32EFPY)

• Submit RG 1.190 calculations by September 2007*Evaluated TLAAsto determine limiting fluence(RG 1.99)-Adjusted Reference Temperatures (<200F)

-Upper Shelf Energy (>50 ft-lb)-RPV welds-RPV nozzles near beltline*Axial Weld Failure Probability is limiting at 5x10

-6 per Reactor Year*ART and USE values will not be challenged at 54 EFPY JAFNPP License Renewal Project JAFNPP License Renewal Project 16 Environmentally Assisted Fatigue*JAF will demonstrate that cumulative usage factors (CUF) of the most fatigue

sensitive locations are less than 1.0 throughout the license renewal period by first using Option (1) of commitment #20*Analysis methods for determination of stresses and fatigue usage will be in accordance with NRC endorsed ASME

Boiler and Pressure Vessel Code*JAF will utilize design transient specifications and information from BWR-4 references to bound operational transients JAFNPP License Renewal Project JAFNPP License Renewal Project 17Environmentally Assisted Fatigue*Environmental effects on fatigue usage will be assessed consistent with the Generic Aging Lessons

Learned Report, NUREG-1801, Rev. 1.*If Option (2) becomes necessary, plant inspection program will be described in terms of the ten elements

specified in Branch Technical Position RLSB-1.*If Option (3) becomes necessary, repair or replacement will be in accordance with plant procedures that meet ASME Section XI requirements.*Above actions will be incorporated into the Fatigue Monitoring Program.*The Fatigue MontoringProgram will manage the effects of EAF in accordance with 10 CFR 54.21(c)(1)(iii).

JAFNPP License Renewal Project JAFNPP License Renewal Project 18*Six Potentially Cost-Beneficial SAMAs Identified *No Age-Related SAMAs *Implementation will be evaluated using the plant cost-benefit analysis process Cost Cost--Beneficial Beneficial SAMAs SAMAs 19 Presentation Topics Presentation Topics*Drywell and Torus Monitoring*Torus Repair 20 21 Drywell and Torus Monitoring James A. James A. FitzPatrick FitzPatrick 22 James A. James A. FitzPatrick FitzPatrick 23 James A. James A. FitzPatrick FitzPatrick 24 James A. James A. FitzPatrick FitzPatrick 25 Drywell Monitoring Drywell MonitoringSand Cushion Inspections. No Evidence of Moisture (Boroscopic Inspection).Visual Inspection of Interior Drywell Caulk Seal.Drywell Interior Coating System (Carbozinc11 and DupontCorlar Epoxy) Inspection IAW IWE Program during RFO.

26 Torus Monitoring Torus MonitoringTorus Interior Shell Inspection 1998 (Installation of ECCS Suction Strainers).Torus Interior Coating System (Carbozinc11) inspected.Torus Interior/Exterior Inspected IAW JAF IWE Program.

27 Drywell Shell Construction Photo Drywell Shell Construction Photo 28 Drywell Shell Construction Photo Drywell Shell Construction Photo 29 Drywell Shell Construction Photo Drywell Shell Construction Photo 30 Drywell Shell Construction Photo Drywell Shell Construction Photo 31 James A. James A. FitzPatrick FitzPatrick Torus Repair 32 Torus Repair Torus Repair Torus shell through-wall leak reported in June 2005Leak was located in same bay as HPCI Steam Discharge pipe near ring girder gusset plate weldASME Section XI code repair performed in July 2005 by removing the flaw and adding a circular repair plateRoot cause of flaw was vibration fatigue from HPCI steam condensation oscillation loading 33 34 Torus Leak 2005 Torus Indication 2006 HPCI Open End Discharge Ring Girder Gusset Plate 35 Torus Repair Torus RepairAHPCI Steam Exhaust Sparger assembly was added during refueling outage October 2006The spargerdirects steam flow away from the Torus shellThe spargersignificantly reduces loads on the Torus shell from HPCI Steam condensation oscillation 36 37 Torus Repair Torus RepairExtent of condition actions from Root Cause required additional shell exams during refueling

outage October 2006ASME visual exams of similar ring girder gusset welds performed at HPCI and RCIC steam

discharge locationsGeneral visual exams of similar ring girder gusset welds performed at several locations

throughout the TorusExam results reported shell base metal flaws at two additional locations in the HPCI discharge

bay 38 39 Torus Repair Torus RepairASME Section XI code repairs were performed by grinding to remove the flaws and welding to restore configurationReview was performed to confirm the HPCI steam discharge loading also caused these flaws 40 Comments and Questions Comments and Questions