ML15112A102

2015/04/21 Indian Point Lr Hearing - FW: ACRS Presentation

ML15112A102
Person / Time
Site:	Indian Point
Issue date:	04/21/2015
From:	- No Known Affiliation
To:	Division of License Renewal
References
Download: ML15112A102 (26)

Text

1IPRenewal NPEmailsFrom:Louie, Richard [rlouie@entergy.com]Sent:Tuesday, April 21, 2015 12:42 PMTo:Green, KimberlyCc:Walpole, Robert W; Pickett, Douglas

Subject:

FW: ACRS PresentationAttachments:ACRS April 23-2015 F0R NRC 4-21.pdfKim, Attached for your information is Entergy's proposed presentation for the 4/23 ACRS subcommittee meeting. Richard Louie rlouie@entergy.com Regulatory Assurance Indian Point Energy Center (914) 254-6618 Hearing Identifier: IndianPointUnits2and3NonPublic_EX Email Number: 5086 Mail Envelope Properties (CB159DC717B797428E92782CE3B5F40B0F14E526)

Subject:

FW: ACRS Presentation Sent Date: 4/21/2015 12:42:17 PM Received Date: 4/21/2015 12:42:26 PM From: Louie, Richard Created By: rlouie@entergy.com Recipients: "Walpole, Robert W" <rwalpol@entergy.com>

Tracking Status: None "Pickett, Douglas" <Douglas.Pickett@nrc.gov>

Tracking Status: None "Green, Kimberly" <Kimberly.Green@nrc.gov> Tracking Status: None Post Office: JDCXMETSP003.etrsouth.corp.entergy.com Files Size Date & Time MESSAGE 277 4/21/2015 12:42:26 PM ACRS April 23-2015 F0R NRC 4-21.pdf 1019173

Options Priority: Standard Return Notification: No Reply Requested: No Sensitivity: Normal Expiration Date: Recipients Received:

Indian Point Energy CenterIndian Point Energy CenterACRS License Renewal SubcommitteeApril 23, 2015 AGENDAAGENDA*Introduction*Plant Status

• License Renewal Status

• Timely Renewal Activities

• Plant Modifications

• SER Supplement 2-Reactor Vessel Internals Program-Underground and Buried Piping

-Program Changes*Concluding Remarks2 Indian Point Energy CenterIndian Point Energy CenterIP2IP33 Indian Point Energy CenterPersonnel in AttendanceIndian Point Energy CenterPersonnel in Attendance*Larry CoyleVice President, Site-IP*Fred DacimoVice President, License Renewal-IP

• Bob WalpoleManager, Regulatory Assurance

• Garry YoungDirector, License Renewal

• Alan CoxManager, License Renewal Technical (ret.)

• Rich DrakeSupervisor, Civil/Structural Engineering

• Nelson AzevedoSupervisor, Code Programs

• Richard BurroniDirector, Engineering

• Don MayerDirector, IP1

• William Glew Jr.Associate General Counsel*Walter WittichEngineering Supervisor IPEC*Dave LachImplementation Project Manager*Robert DolanskySenior Lead Engineer4 IPEC Plant StatusIPEC Plant Status*IP2 -Status*IP3 -Status*Next refueling outages-Spring 2016 (IP2)-Spring 2017 (IP3)5 License Renewal StatusLicense Renewal Status*Entergy's license renewal application was docketed in 2007*Indian Point 2 entered the period of extended operation (PEO) onSeptember 28, 2013 and its license remains valid and in effect under the timely renewal provision of federal regulations*Indian Point 3 will enter the PEO on December 12, 2015, also under the timely renewal provision*The license renewal project, ongoing for more than 7 years, is very comprehensive. More than 33,000man-hours of engineering evaluations, procedure development, and inspections for commitment implementation*Ongoing Adjudicatory proceedings address two New York State issues:*Obtaining a 401 Water Quality Certificate*Obtaining consistency certification with Coastal Zone Management Act6 License Renewal Status (cont.)License Renewal Status (cont.)*NRC issued a supplement to the Final SupplementalEnvironmental Impact Statement (FSEIS) in June 2013. A second supplement is scheduled to be issued in March 2016, with a draft due in July 2015*The NRC issued a safety evaluation report (SER) in 2009 and supplements to the SER in 2011 and 2014, all supporting continued operation of both units*There are no SER open items*The ACRS License Renewal Subcommittee met in March of 2009 and the full Committee met in September of 2009 to review the IPEC license renewal application and SER*Hearings are ongoing before the Atomic Safety and License Board (ASLB). Thirteen of sixteen admitted contentions have been settled, resolved or appealed. Hearings for the remaining three contentions are planned for later this year7 Timely Renewal ActivitiesTimely Renewal ActivitiesIndian Point Unit 2*Commitments, which include inspections, due beforeentering the PEO were completed as required*Subsequent aging management activities are scheduled and completed as IP2 continues through the PEO*Aging management programs are described in theupdated FSAR which was updated prior to entering the PEO8 Planned Timely Renewal ActivitiesPlanned Timely Renewal ActivitiesIndian Point Unit 3*Commitments, which include inspections, due beforeentering the PEO are either completed or scheduled to be completed before December 12, 2015*Inspections requiring the plant to be shutdown are complete*Subsequent aging management activities will be scheduled and completed as IP3 continues into the PEO*Aging management program descriptions will be included in the Updated FSAR before entering the PEO9 Timely Renewal Activities (cont.)Timely Renewal Activities (cont.)LR Commitment 19 -One-Time Inspection (OTI) Program(Required prior toPEO)IP2 One-Time Inspection Program*Performed OTI for 437 samples*Inspections verified that unacceptable degradation is not occurring

• The inspections verified the effectiveness of the IP2 Water Chemistry Control, OilAnalysis and Diesel Fuel Monitoring programs to manage the effects of aging during the IP2 period of extended operation*IP3 One-Time Inspection Program*324 total OTI samples required*297 OTIs performed -one observation

• All 27 one-time inspections scheduled to be performed during the 2015 refuelingoutage were completed with one observation10 Timely Renewal ActivitiesTimely Renewal Activities*LR Commitment 23 -Selective Leaching (SL) ProgramIP2 Selective Leaching Program*Performed SL inspections for 46 samples -No evidence of SL for either gray cast ironor copper alloy materials*Destructive testing/analysis for 7 sample (2 copper alloy and 5 cast iron) -Results oflaboratory analysis revealed graphitization in four of the five cast iron samples*Developed new ongoing IPEC Selective Leaching Management Program -Established the program implementation requirements for the identification, monitoring, trending and repairing/replacing components susceptible to selective leachingIP3 Selective Leaching (SL) Program-22 total SL samples required-17 SL inspections performed -no findings11 Major Plant Modifications since 2009 ACRSSubcommittee MeetingMajor Plant Modifications since 2009 ACRSSubcommittee Meeting*Entergy has an ongoing robust capitalimprovement program*Since 2009 over 1000 modifications and otherplant improvements have been implemented costing nearly $ 600 million*Examples of modifications are included in thenext several slides12 Major Plant Modifications since 2009 ACRSSubcommittee Meeting (cont.)Major Plant Modifications since 2009 ACRSSubcommittee Meeting (cont.)Indian Point Unit 2*2010 -Installed vortex suppressors above internal recirculation andcontainment sump strainers*2010 -2013 Replaced 21 main transformer and rebuilt oilcontainment moats for 21 and 22 main transformers*2012 -Installed cathodicprotection system on Condensate StorageTank supply and return piping*2012 -Received license to transfer spent fuel from Unit3 to Unit 2*2015 -Work in progress to install Spent Fuel Pool wide-range levelindication*2015-Installed robust Flex Equipment Storage Building (also usedfor Unit 3)*2015 -Work in progress to install FLEX electrical andmechanical connectors13 Major Plant Modifications since 2009 ACRSSubcommittee Meeting (cont.)Major Plant Modifications since 2009 ACRSSubcommittee Meeting (cont.)Indian Point Unit 3*2009 -Replaced guide tube split pins*2011 -Installed vortex suppressors above internal recirculation andcontainment sump strainers*2011 -Installed cathodicprotection system on Condensate StorageTank supply and return piping*2012 -Fuel Storage Building and external roadway modifications to allowwet transfer of spent fuel from IP3 to IP2*2012 -Replaced Plant Process Computer with upgraded computer

• 2014 -Completed rebuilding 31 and 32 main transformer oil containmentmoats*2015 -Completed installation of FLEX electrical and mechanicalconnections*2015 -Completed installation of Spent Fuel Pool wide-range levelindication14 Major Plant Modifications since 2009 ACRSSubcommittee Meeting (cont.)Major Plant Modifications since 2009 ACRSSubcommittee Meeting (cont.)Site*New site security perimeter to include-2011 -Vehicle barrier system enhancement

-2012 -New Security Owner Controlled Area fence line*2012 -New Protected Area security access building

• 2014 -New Plant Access Authorization System

• 2014 -New security central monitoring and alarm system

• 2014 -Removal of most of the Unit 1 stack

• 2014 -Rebuilt the Unit 1 Screenwellhouse15 Reactor Vessel Internals ProgramReactor Vessel Internals Program*The NRC has reviewed and approved the IPEC Reactor Vessel Internals(RVI) Program (based on MRP-227-A) as documented in Supplement 2 to the Safety Evaluation Report. The NRC review included the detailed RVI inspection plan that implements the elements of the RVI Aging Management Plan and fulfills License Renewal Application Commitment 30*Inspections of all MRP-227-A primary components (including over 4700specific inspections) are scheduled for the Spring of 2016 (IP2) and Spring of 2019 (IP3)*Industry MRP-227-A inspections performed to date have found no issueswith RV internals, other than isolated cracking of baffle-to-former bolts*Based on the industry OE, IPEC will have a baffle bolt minimum patternanalysis to document that cracking of small numbers of bolts has no impact on the structural integrity of the baffle-former assembly*IP2 is planning on replacing the split pins during the 2016 refueling outagewith cold-worked 316 stainless steel which is degradation resistant. IP3 replaced their split pins with cold-worked 316 stainless steel in 200916 Underground PipingUnderground Piping*Underground piping is defined as below grade, in contact with airand with limited accessibility*The program was changed to reflect new regulatory guidance

• All underground piping inspections due prior to entering the PEOwere completed at IP2. No adverse conditions were identified. All underground piping at IP2 has been coated with a qualified coating*Approximately 50% of the pre-PEO underground piping inspectionshave been completed at IP3. The remainder of the inspections are scheduled for this upcoming Summer. No adverse conditions have been identified to date17 Buried PipingBuried Piping*Buried piping is defined as below grade and in contact with soil*All buried piping inspections due prior to entering the PEO have beencompleted at both IP2 and at IP3. The inspection results have demonstrated that the piping and the protective coating are generally in good condition.

Some minor coating degradation has been identified and corrected*There have been two exceptions where some moderate corrosion has beenidentified. One was a 2009 through-wall leak in the IP2 Condensate Storage Tank piping (discussed in the September 2009 ACRS) and the other was degradation in a Service Water line (two areas of degradation) in 2014 at IP3. Both locations have been repaired*In both instances, the affected piping remained structurally capable ofperforming its intended safety function18 Buried Piping (cont.)Buried Piping (cont.)*There is approximately 16,000 feet of buried piping within the scope oflicense renewal at IPEC (i.e. both units combined)*We have conservatively inspected in excess of 1,000 feet of buried piping ateach Unit (2,000 feet total)*IP2 committed to inspect (direct visual inspections) 20 carbon steellocations prior to the PEO (IP2 does not have any buried stainless steel piping)*IP3 committed to inspect 11 carbon steel and 3 stainless steel buried pipinglocations prior to the PEO*IP2 committed to inspect 14 carbon steel locations and IP3 committed toinspect 14 carbon steel and 2 stainless steel buried piping locations during each of the 10-year period during the PEO19 Buried piping -CathodicProtection (CP)Buried piping -CathodicProtection (CP)*As a result of the site geology, a site wide CP system is not feasibleat IPEC*Targeted CP systems have been installed to protect specific areaswhere vulnerabilities have been identified*These include some City Water piping and Condensate StorageTank piping at both IP2 and IP3*These CP systems provide some corrosion protection but not the fullprotection because of the non-conductive nature of the IPEC site geology*The main corrosion protection barrier for buried piping at IPEC is thebitumasticprotective coating*Since the full CP protection levels are not achievable at IPEC, theinstalled CP systems are not credited in establishing the inspection population which results in a larger direct visual inspection population20 Program ChangesProgram Changes*Examples of program changes*Buried Piping -Omission and corrections related to systems and componentscredited in AFW pump room fire (added IP1 river water, IP2 Circulating Waterand IP2 Instrument Air)*Metal-Enclosed Bus Inspection ProgramMetal-enclosed bus associated with Diesel Fire Pump is not required to startthe diesel since it only provides power to charge the batteries and was removed from program*Structures Monitoring Program-sump screens, strainers and flow barriers removed from program if they were changedto stainless steel in an air-indoor uncontrolled environment*External surface Monitoring program-some carbon steel piping and filter housing exposed externally to indoor air added tobe managed for loss of material by the program-carbon steel piping and filter housings and gray cast iron turbochargers exposedinternally to indoor air removed from program since they were associated with GT3 which is no longer credited21 Program Changes (cont.)Program Changes (cont.)*Oil Analysis Program-Added copper alloy greater than 15% zinc (inhibited) heatexchanger tubes which are exposed externally to lubricating oil*Tables in LRA revised to add or delete components based on annual updatesubmittals-programs looking for loss of material due to general, pitting and crevicecorrosion, microbiologically influenced corrosion, fouling and lining/coating degradation*Elastomer Degradation -materials added*Service Water System-Plastic piping exposed internally to raw water andexternally to indoor air added to a table in the LRA*Fuel Oil Systemadded copper alloy with greater than 15% zinc then removedbecause GT-3 no longer credited*Water treatment plant, City Water system, Lube Oil Systems -components added22 Concluding RemarksConcluding Remarks*Unit 3 is being prepared to enter the PEO aswas done for Unit 2*License renewal activities are being or will beconducted as if the plants had received a renewed license*Entergy continues to make investments into theplants to ensure safe and reliable operation*IPEC is consistently operating with capacityfactors above 90%23 QuestionsQuestions24