ML103470631

Slides for December 2010 Public Meeting

ML103470631
Person / Time
Site:	Browns Ferry
Issue date:	12/13/2010
From:	Tennessee Valley Authority
To:	Division of Operating Reactor Licensing
Gratton C, NRR, DORL, 415-1055
References
Download: ML103470631 (17)

Text

TENNESSEE VALLEY AUTHORITY BROWNS FERRY NUCLEAR PLANTStatus of Extended Power Uprate (EPU)Rockville, MarylandDecember 15, 2010 Agenda*Introductions*Meeting Purpose

• Review BFN Extended Power Uprate Regulatory History 2*Future Plans

-Containment Accident Pressure Mitigation

-Steam Dryers

-Schedule Meeting Purpose*Revive Browns Ferry EPU project license submittal *Confirm outstanding project scope 3*Communicate planned Containment Accident Pressure (CAP) mitigation strategy relative to Draft NRC

guidelines*Communicate plans for Steam Dryers Browns Ferry EPU History

• June 2004: Initial EPU Submittals*Unit 1 -100% to 120% OLTP with pressure increase

• Units 2 and 3 -105% to 120% OLTP

• February 2007: ACRS reviewed Unit 1 analyses for 120% operation

• March 2007: Unit 1 a pproved for 105% o p eration 4 pp p*Included pressure increase*Units 1, 2, and 3 now at same licensed power level

• September 2009: EPU CAP review placed on hold pending development of CAP guidance

• March 2010: NRC Draft Guidelines on CAP provided EPU Modifications Modification StatusU1U2U3Reactor SystemsNew Main Steam IsolationValve Internals and ActuatorsCompleteCompleteCompleteUp-rated Reactor Recirculation Motors/ PumpsCompleteCompleteCompleteReplacementSteam DryersSecondary SystemsNew Condensate Pumps and MotorsCompleteCompletePlanned2012Additional CondensateDemineralizer VesselCompleteCompletePlanned2012 6New Condensate Booster Pumps and MotorsCompleteCompletePlanned2012Condensate Demineralizer Digital UpgradeCompleteCompletePlanned2012 New Reactor Feed PumpsCompleteCompletePlanned2012New Reactor Feed Pump TurbinesCompleteCompleteCompleteNew Feedwater Heater Nozzles, Relief Valves and #3 ShellCompleteCompletePlanned2012New HP TurbineNew Moisture Separator InternalsCompleteCompleteComplete New Generator Bus Duct Coolers and FansCompleteCompleteComplete EPU Open Issues *Containment Accident Pressure (CAP)*Replacement Steam Dryers (RSD) 7 CAP Mitigation Evaluation*Based on Draft Guidelinesprovided, comprehensive engineering analysis was performed to identify and evaluate strategies to address CAP for all events*Evaluation used Draft Guideline criteria to determine CAP need:*NPSHR 3% curve for LOCA plus uncertainty adderNPSHR3%fSilEt 8*NPSHR 3% curve f or S pec i a l E ven t s*Evaluation conservatively used 4 feet for uncertainty adder CAP Evaluation Results*Use of NRC Draft Guidelines eliminates CAP for Station Black Out (SBO) event *Use of NRC Draft Guidelines eliminates CAP for Anticipated Transient Without Scram (ATWS) eventIlttifNFPA805(ildihif 9*I mp l emen t a ti on o f NFPA-805 (i nc l u di ng compre h ens ive sa f e shutdown analysis upgrade, comprehensive improvements to safe shutdown procedures) is expected to eliminate Appendix R CAP requirement, to submit NFPA-805 LAR March 2012*Changes to credit improved RHR Heat Exchanger performance eliminates CAP for Long-Term LOCA Core Spray event*CAP credit needed for Short-Term LOCA event only CAP Evaluation Results cont'dLong-Term LOCA Core Spray Event:*RHR heat exchanger performance tests have measured fouling factors significantly better than vendor values used in current CAP analyses

• RevisionsrequiredtoGenericLetter89

-13HeatExchangerprogramto Revisions required to Generic Letter 89 13 Heat Exchanger program to reflect use of higher heat transfer coefficient value would credit improved Residual Heat Removal (RHR) Heat Exchanger performance *Improved RHR Heat Exchanger performance eliminates CAP forLong-Term LOCA Core Spray event 10 CAP Evaluation Results cont'dShort-Term LOCA Event:*CAP credit needed for Short-Term LOCA event*Short-Term LOCA CAP has low risk significance and PRA analysis will be performed

• CAPisrequiredforonlyshorttimeperiodoftenminutes 11*CAP is required for only short time period of ten minutes *Low probability of a large break LOCA and simultaneous gross containment failure*Operation at EPU power levels do not significantly worsen existing CLTP CAP for the short term LOCA event EPU CAP Summary Existing EPU Submittal ValuesPlanned EPU Submittal ValuesShort-Term LOCA (< 10 minutes)Current CLTP valuesRevised values using draft CAP guidelines Core Spray1.47 psi < 10 minutes2.0 psi / 8.9 minutes2.0 psi / 9.7 minutesRHR Intact LoopNone Required0.2 psi / 3.2 minutes2.7 psi / 9.7 minutesRHRBrokenLoop1.57psi<10minutes2.1psi/9.3minutes5.0psi/10minutes 12 RHR Broken Loop 1.57 psi 10 minutes 2.1 psi / 9.3 minutes 5.0 psi / 10 minutesLong-Term LOCA (> 10 minutes)Core Spray3.0 psi / 22.5 hours5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br /> None RequiredRHR-Containment CoolingNone RequiredNone RequiredSpecial EventsAppendix R(NPSH 3%)6.1 psi / 27.8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />sNone RequiredStation Black Out1.4 psi / 1.4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />sNone RequiredATWS1.9 psi / 1.2 hour2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />sNone Required Replacement Steam Dryers *To improve required stress margins, TVA will replace the existing steam dryers *RSDs will be designed and analyzed by General Electric Hitachi (contract scheduled to be finalized in early 2011)*RSD analyses will use GEH Plant Based Load Evaluation (PBLE) 13 methodology*Analyses will use Main Steam Line (MSL) strain gage data taken at CLTP conditions*Data for Units 1 and 3 already taken

• Additional data for Unit 2 to be taken Spring 2011 Replacement Steam Dryers *Goal to submit RSD analyses by January 2012*Lessons learned from ongoing Grand Gulf reviews will be incorporated as required*Submittal will address all open BFN applicable steam dryer related RAIs from previous reviewsPltittdlditltfdi 14*Pl an t o i ns t rumen t dryer on l ea d un it on l y to measure per f ormance d ur i ng power ascension to EPU conditions*Will initiate dryer construction following approval of EPU submittal

• Dryer replacement is predicated by successful resolution of EPU CAP Draft Schedule for EPUSubmittals*Steam Dryer analysis and designFebruary 2012

• NFPA-805 LAR (Appendix R Cap elimination)March 2012

• Remaining plans to mitigate CAP March 2012

• Unit 1 Areva fuel analysis for EPUMarch 2012NRCActivity NRC Activity *18 months for NRC review, ACRS meetings, etc.

• Issue SER for EPU September 2014EPU Implementation Activities*Unit 2 EPU Spring 2015

• Unit 3 EPU Spring 2016

• Unit 1 EPU Fall 2016 15 Closing Remarks*We will design and install new steam dryers*We plan to eliminate requirement for CAP for all accident scenarios except Short Term LOCAWillflldiktilttiJ

• W e w ill f o llow up an d i ssue a key assump ti ons l e tt er i n J anuary based on discussions today regarding our planned strategy to mitigate/ eliminate Containment Accident Pressure*We will maintain an open dialogue of communication in the form of a bi-weekly telecon with project manager 16 Quest i o n s/Co mm e n ts?17Questos/Coets