ML11083A025

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2009/03/03 Indian Point Lr Hearing - Latest Slides
ML11083A025
Person / Time
Site: Indian Point  Entergy icon.png
Issue date: 03/03/2009
From: Green K J
Division of License Renewal
To: Stroud M D
Entergy Nuclear Operations
References
Download: ML11083A025 (49)
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Text

1 Stuyvenberg, Andrew From: Kimberly Green Sent: Tuesday, March 03, 2009 1:36 PM To: STROUD, MICHAEL D

Subject:

latest slides Attachments:

ACRS-Indian Point-Presentation 03-03-09.pptHere are the latest. I don't expect too many changes at this point.

Kim

Advisory Committee on Reactor Safeguards License Renewal SubcommitteeIndianPointNuclearGeneratingUnit Indian Point Nuclear Generating Unit Nos. 2 and 3Safety Evaluation Report with Open Items March 4, 2009Kimberly Green, Project Manager Office of Nuclear Reactor Regulation Introduction*Overview*Section 2: Scoping and Screening Review*License Renewal Ins p ections p*Section 3: Aging Management Program and ReviewResults Review Results*Section 4: Time-Limited Aging Analyses (TLAAs) 2*Open Items Overview*LRA Submitted by letter dated April 23, 2007

  • Westinghouse4 Loop*Westinghouse 4-Loop*3216 MWth, 1080 MWe
  • OperatinglicenseDPR

-26(IP2)expires Operating license DPR 26 (IP2) expires September 28, 2013*Operating license DPR-64 (IP3) expires December122015 December 12 , 2015*Located approximately 25 miles north of NYC limits 3 Overview*Safety Evaluation Report with Open Items was idJ152009 i ssue d J anuary 15 , 2009*20 Open items*121 RAI's Issued*272 Audit Questions*38 Commitments 4

Overview*Scoping and Screening Methodology Audit-October 8, 2007 -October 12, 2007

  • AgingManagementPrograms(AMP)Audit Aging Management Programs (AMP) Audit-August 27, 2007 -August 31, 2007*Aging Management Review (AMR) & Time-Limited Aging Analysis (TLAA) AuditOtb222007Otb262007-O c t o b er 22 , 2007 -O c t o b er 26 , 2007-November 27, 2007 -November 29, 2007-February 19, 2008 -February 21, 2008
  • R eg i o n a l Li ce n se R e n e w a l In spect i o n segoaceseeeaspectos-January 28, 2008 -February 1, 2008

-February 11, 2008 -February 14, 2008

-March 31, 2008 -April 2, 2008J22008J62008dJ182008 5-J une 2 , 2008 -J une 6 , 2008 , an d J une 18 , 2008 Open Items*SER issued with 20 open items

-14 with requests for additional information-6 are still under review by staff*Applicant submitted additional information dated January 27, 2009*Staff can close out 13 Open Items 6

Section 2: Structures and Components SubjecttoAgingManagementReviewSection 2.1 -Scoping and Screening Methodology Subject to Aging Management Review*Based on audit and review staff concluded that the applicant's methodology is consistent with the requirementsof10CFR54.4and54.21(a)(1) requirements of 10 CFR 54.4 and 54.21(a)(1)Section 2.2 -Plant-Level Scoping Results*IP2 chlorination and IP3 H 2systems initially omitted f f rom scope*Staff concluded applicant identified mechanical systems and structures within the scope of license renewal per 7 10 CFR 54.4(a).

Section 2.3 -Scoping and Screening Results: MechanicalSystems Mechanical Systems*Mechanical Systems: 59 (IP2 ) and 87 (IP3)

  • TwoTierReviewofBalanceofPlantsystems:

Two Tier Review of Balance of Plant systems: -Tier 1 Review: Review LRA and UFSAR-Tier 2 Review: Detailed review of LRA, UFSAR, and lildi li cense renewa l d raw i ngs*100% of mechanical systems identified by applicantaswithinthescopeoflicenserenewal applicant as within the scope of license renewal were reviewed 8

Section 2.3 -Scoping and Screening Results: MechanicalSystems Mechanical Systems*Staff identified omission of nonsafety-related componentsfromscopeforIP2containment components from scope for IP2 containment spray*Applicantre

-evaluatedandidentified3other Applicant re evaluated and identified 3 other systems (IP2 CCW, IP3 CCW, and IP3 BVS)

  • AmendedLRAandaddedcomponentstoscope Amended LRA and added components to scope 9 Section 2.3 -Scoping and Screening Results MechanicalSystems Mechanical Systems*Three Open ItemsOI23A311 1yardhosehousesandchamber

-OI 2.3A.3.11-1 -yard hose houses and chamber housings-OI 2.3.4.2-1

-feedwater isolation valves-OI 2.3A.4.5-1 -auxiliary feedwater pump room fire event systems*These OIs can be closed 10 Section 2.4 -Scoping and Screening Results: Stt St ruc t ures*Staff concluded that there were no omissions of ttttltf s t ruc tures or s t ruc t ura l componen t s f rom scope of license renewal in accordance with 10 CFR 544(a)andnoomissionsfromAMRin 54.4(a), and no omissions from AMR in accordance with 10 CFR 54.21(a)(1).

11 Section 2.5 -Scoping and Screening Results: ElectricalandInstrumentationandControl Electrical and Instrumentation and Control Systems*OI 2.5-1 -Station blackout scoping*Issue is under staff evaluation

  • With exception of SBO OI scoping, staff concludednoomissionsofelectricaland concluded no omissions of electrical and instrumentation and control system components from the scope of license renewal in accordance with10CFR544(a)andnoomissionsfrom with 10 CFR 54.4(a), and no omissions from AMR in accordance with 10 CFR 54.21(a)(1) 12 Section 2.6 -Conclusion for Scoping and Screening Screening*The applicant's scoping and screening methodologyisconsistentwiththerequirements methodology is consistent with the requirements of 10 CFR 54.4 and 10 CFR 54.21(a)(1)*With exception of open items, the applicant adequately identified those SSCs within the scope of license renewal in accordance with 10 CFR544(a)andthoseSCssubjecttoanAMR CFR 54.4(a), and those SCs subject to an AMR in accordance with 10 CFR 54.21(a)(1).

13 LicenseRenewalInspections License Renewal InspectionsGlennMeyer Glenn MeyerRegionIInspectionTeamLeader Region I Inspection Team Leader Ins p ection Ob j ectives pj*Scoping of Non-safety SSCs *28 Aging Management Programs (AMPs)*2 Systems: Auxiliary Feedwater; IP2 SBO diesel generator (DG)

  • F o ll o w up: IP2 S B O D G, e l ect ri ca l cab l e ooupSOG,eectcacabe vault, and containment liner 15 Scoping Scoping*Scopingofnon

-safetySSCs

-generally*Scoping of non-safety SSCs -generally accurate and acceptable

  • Structuralandspatialinteractions
  • Structural and spatial interactions reviewedAMPifd2ti*AMP rev i ews f oun d 2 componen t scop i ng errors 16 A g in g Mana g ement Pro g ram Reviewgggg Resolved by LRA Amendment 3:*Structural Monitoring
  • OilAnalysis Oil Analysis*Diesel Fuel MonitoringWtChit*W a t er Ch em i s t ry*Metal-Enclosed Bus Inspection 17 A g in g Mana g ement Pro g ram ReviewggggResolvedbyLRAAmendment3:

Resolved by LRA Amendment 3:*Selective Leaching NEQBldCblCi

  • N on-EQ B o l te d C a bl e C onnect i ons Resolved by LRA Commitment 37:
  • Exposedrebaroncontainmentexterior 18 Exposed rebar on containment exterior A g in g Mana g ement Pro g ram Reviewgggg Resolved Onsite:*Metal-Enclosed Bus Operating Experience *Instrument air heat exchan g ers g*AMR for transite material
  • ConditionReportsonisolateddegradation
  • Condition Reports on isolated degradation 19 Follow U p Ins p ections pp*IP2SBOdiesel

-scopingandsystem

  • IP2 SBO diesel -scoping and system review when operational
  • Electricalcablevaultwhenaccessible
  • Electrical cable vault -when accessible*Unit 2 containment liner -when accessible 20 Ins p ection Conclusions p*Non-safetySSCscopingandaging
  • Non-safety SSC scoping and aging management programs are acceptable.*Inspection results support a conclusion of blthtifft reasona bl e assurance th a t ag i ng e ff ec t s will be managed and intended functions illbitid 21 w ill b e ma i n t a i ne d Current Performance*Both units -Licensee Response Column
  • AllFindings

-Green All Findings Green*All Performance Indicators (PIs) -Green 22 Section 3: Aging Management Review Rlt R esu lt s*Section 3.0 -Aging Management Programs*Section 3.1 -Reactor Vessel & Internals*Section 3.2 -Engineered Safety Features*Section 3.3 -Auxiliary Systems

  • Section 3.4 -Steam and Power Conversion System*Section 3.5 -Containments, Structures and Component Supports*Section36ElectricalandInstrumentationandControls 23*Section 3.6 -Electrical and Instrumentation and Controls System Section 3.0.3 -Aging Management Programs (AMP)(AMP s)*41 AMPs10NewPrograms

-10 New Programs-31 Existing Programs

  • 15consistentwithGALLReport
  • 15 consistent with GALL Report*10 consistent with GALL Report with enhancements
  • 8hadexceptions
  • 8 had exceptions*8 plant-specific 24 Section 3.0.3 -AMPs8OIt*8 O pen It ems*The following 5 OIs can be closed-OI 3.0.3.2.7-1 -fire penetration seals-OI 3.0.3.3.3-1 -acceptance criteria for visual examinations-OI 3.0.3.3.4-1 -inspection methods, etc. for lubrite sliding supports-OI 3.0.3.3.4-2 -corrective actions for ISI-OI 3.0.3.3.7-1 -Periodic Surveillance and Preventive Maintenance Program 25 Section 3.0.3 -AMPs*The following 3 OIs are still under review-OI 3.0.3.2.15-1 -IP2 reactor refueling cavity leakage

-OI 3.0.3.2.15-2

-IP2 spent fuel pool leak-OI 3.0.3.3.2-1 -Exterior containment concrete degradation degradation 26 Section 3.1 -Aging Management of Reactor Vessel, Internals, and RCS*2 O p en Items p-OI 3.1.2-1 -Nickel alloy components

-OI31227-1-InspectionofCASS OI 3.1.2.2.7 1 Inspection of CASS These 2 OIs can be closed 27 Section 3.3 -Aging Management of Auxiliary Systems

  • OI33-1-Clarificationof OI 3.3 1 Clarification of material/environment/aging effect for titaniumcomponents titanium components This OI can be closed 28 Section 3.4 -Aging Management of StdPCi St eam an d P ower C onvers i on Systems*One Open Item-OI 3.4-1 -AMR results for a fire in IP2 ilifdt aux ili ary f ee d wa t er pump room This OI is still under staff review 29 Section 3.5 -Aging Management of CtitSttd C on t a i nmen t s, St ruc t ures an d Component Supports*3 Open Items*These 2 OIs are still under staff reviewOI35 1 WtttifIPt-OI 3.5-1 -W a t e r-cemen t ra ti o f or IP concre t e-OI 3.5-2 -Reduction of strength and modulus of concrete due to elevated temperatures 30 Section 3.5

-A g in g Mana g ement of ggg Containments, Structures and ComponentSupports Component Supports*This OI can be closed-OI 3.5-3 -Aging management of concrete surrounding B1 supports 31 Section 3.6 -Aging Management of Electrical and I&C Systems*LRA identified no aging effects for IP2 138-kV hihltbl hi g h-vo lt age ca bl e*Staff issued RAIAlitddLRAtddblt

  • A pp li can t amen d e d LRA t o a dd ca bl e t o Periodic Surveillance and Preventive

Maintenance Pro g ram g 32 Section37Conclusion Section 3.7 Conclusion With the exception of the Open Items, the lithdttdthti app li can t h as d emons t ra t e d th a t ag i ng effects will be adequately managed during theperiodofextendedoperationin the period of extended operation in accordance with 10 CFR 54.21(a)(3) 33 Section 4: Time-Limited A g in g Anal y ses*4.1 Identification of Time Limited Aging Analyses (TLAAs)ggy (TLAAs)*4.2 Reactor Vessel Neutron Embrittlement

  • 4.3MetalFatigue 4.3 Metal Fatigue*4.4 Environmental Qualification of Electrical Equipment
  • 4.5 Concrete Containment Tendon Prestress*4.6 Containment Liner Plate and Penetration Fatigue
  • 4.7 Other Plant-Specific TLAAs 34 Section 4.2: Reactor Vessel Neutron Embrittlement

-UpperShelfEnergy Embrittlement Upper Shelf EnergyLimiting Beltline Material-Lower Shell Plate (B2002-3)Unit2% CU48 EFPY Fluence (E>1 MeV) at Initial Charpy V notch USE Value Irradiated Charpy V Acceptance Criterion per Unit 2 ()1/4T 10 19 (n/cm 2)(ft-lb)notch USE Value at48 EFPY (ft-lb) 10 CFR 50, App. G (ft-lb)0.251.1367448.3>

50 35*Equivalent margins analysis submitted which meets Appendix G of ASME Section XI and 10 CFR Part 50, Appendix G Section 4.2: Reactor Vessel Neutron Embrittlement

-UpperShelfEnergy Embrittlement Upper Shelf EnergyLimiting Beltline Material-Lower Shell Plate (B2803-3)Unit3% CU48 EFPY Fluence (E>1 MeV) at Initial Charpy V notch USE Value Irradiated Charpy V Acceptance Criterion per Unit 3 ()1/4T 10 19 (n/cm 2)(ft-lb)notch USE Value at48 EFPY (ft-lb) 10 CFR 50, App. G (ft-lb)0.240.92986849.8>

50 36*Equivalent margins analysis submitted which meets Appendix G of ASME Section XI and 10 CFR Part 50, Appendix G Section 4.2: Reference Temperature for PressurizedThermalShock(PTS)Values Pressurized Thermal Shock (PTS) ValuesLimiting Beltline Material-Lower Shell Plate(B2803-3)

Unit 3%CU%Ni48 EFPY Fluence (E>1 MeV)(@clad/steelinterface)

Initial Charpy RT NDT 0 F RT PTS 0 F Acceptance Criterion per 10 CFR 50.61

(@clad/steel interface) 10 19 (n/cm 2)F 0 F 0.24 0.521.5674279.5<

270 o F 0.52 Commitment 32: As required by 10 CFR 50.61(b)(4), IP3 will submit a plant-specific safetyanalysisforplateB2803

-3totheNRCthreeyearspriortoreachingtheRT PTS 37 safety analysis for plate B2803 3 to the NRC three years prior to reaching the RT PTS screening criterion. Alternatively, the site may choose to implement the revised PTS rule when approved.

Section 4.3: Metal Fati gue Anal y ses*60-year fatigue analyses were performed gy for all NUREG/CR-6260 locations, except 2 locations (IP2) and 3 locations (IP3)*Entergy will manage aging for NUREG/CR-6260 locations in accordance with 10 CFR 54.21(c)(1)(iii) (Commitment

33)38)

Section 4.3: Metal Fati gue Anal y ses Section 4.3

-Class 1 Fati g ue gy g*One Open Item

-OI43-1-NumberofIP3plantheatupsand

-OI 4.3-1 -Number of IP3 plant heatups and cooldownsThisOIcanbeclosed This OI can be closed 39 Open Items Still Under Staff Review*OI 2.5-1 -SBO scoping*OI 3.0.3.2.15-1 -IP2 reactor refueling cavity leakage*OI 3.0.3.2.15-2 -IP2 spent fuel pool leak

  • OI 3.0.3.3.2-1 -Exterior containment concrete ddti d egra d a ti on*OI 3.4-1 -AMR results for the auxiliary feedwater pump room event*OI 3.5-1 -Water-cement ratio for IP concrete*OI 3.5-2 -Reduction of strength and modulus of 40concrete due to elevated temperatures
  • OI 2.5-1

-SBO sco p in g pg-Applicant revised LRA Figures 2.5-2 and 2.5-3, the "Offsite Power Scoping Diagram(s)" for IP2 and IP3 forprimarandsecondaroffsitepoerpaths for primar y and secondar y offsite po w er paths -By letters dated March 24, 2008 and August 14, 2008 , the a pplicant revised and clarified its res p onse ,ppp-The staff is completing its review of the applicant's information on the SBO scoping boundary and will dtitliithfilSER d ocumen t it s conc l us i on i n th e fi na l SER 41

  • OI 3.0.3.2.15-1 -IP2 reactor refueling cavity leakageIP2refelingcaitleaksattheppereleationsofthestainless

-IP2 ref u eling ca v it y leaks at the u pper ele v ations of the stainless steel cavity liner when flooded during refueling outages-Attempts have been made to mitigate this condition

-An action plan is being developed for permanent fix-Applicant has committed to perform one-time inspection prior to entering period of extended operation to confirm absence of degradation (Commitment 36)-Applicant has not identified augmented inspections for period of extended operation-Staff sent draft RAI to request how the AMP will monitor condition during period of extended operation 42

  • OI 3.0.3.2.15-2 -IP2 spent fuel pool leak

-IP2 spent fuel pool (SFP) has experienced leakage-IP2 SFP does not have leak chase channelsApplicantcommittedtotestthegroundwateroutside

-Applicant committed to test the groundwater outside IP2 SFP every 3 months (Commitment 25)

-Applicant does not p lan to p erform au g mented ppppginspections of SFP during the period of extended

operation.StfftdftRAItththAMPill

-St a ff sen t d ra ft RAI t o reques t h ow th e AMP w ill monitor this condition during period of extended

operation 43

  • OI 3.0.3.3.2-1 -Exterior containment concrete degradation degradation-External surfaces of IP2 and IP3 containments have locations of concrete spalling

-Applicant explained that areas of spalling occur at cadweld sleeves and scaffolding anchor locations-Applicant concluded there is sufficient design margin for exposed reba r-Applicant committed to perform enhanced inspections of containment (Commitment 37)-Staff sent draft RAI requesting information on how the applicant will use the above within its Containment Inservice Inspection

Program 44

  • OI 3.4-1 -AMR results for the IP2 auxiliary feedwater fit pump room fi re even t-Applicant stated that systems are continuously in operation and monitored-Applicant stated aging related degradation that occurs during 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> is negligible

-A pplicant concluded that there are no a g in g effects; therefore no ppgg AMPs are necessary-Applicant provided additional information on January 27, 2009

-Staffisstillevaluatingapplicant

'sresponseStaff is still evaluating applicants response 45

  • OI 3.5-1 -Water-cement ratio for IP concrete-LRA identified the water-cement ratios for IP concrete -Staff identified a discrepancy and asked for clarification

-ApplicantstateditusedMethod2inACI318

-63standardto Applicant stated it used Method 2 in ACI 318 63 standard to determine concrete strength-Staff sent draft RAI to define water-cement ratios and provide resultsoforiginalconcretestrengthtestsAlternativelythe results of original concrete strength tests. Alternatively , the applicant may identify applicable aging effects and how they will

be managed 46

  • OI 3.5-2 -Reduction of strength and modulus of concrete due to elevated tem p eratures p-LRA stated concrete surrounding IP2 penetrations can reach 250 °F-GALL Report recommends further evaluation to manage reduction of strength and modulus of concrete structures due to elevated temperature (>200 °F)-Applicant concluded that reduction of strength and modulus is not an aging effect requiring management

-Applicant determined a reduction in strength of 15% from elevated temperatures which is acceptable-Staff sent draft RAI about how strength margin was determined and if reductioninmodulusofelasticitywasconsideredAlternativelythe reduction in modulus of elasticity was considered. Alternatively , the applicant may explain how the aging effect will be managed 47 Questions?

Questions?

48

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