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{{#Wiki_filter:TENNESSEE VALLEY AUTHORITY BROWNS FERRY NUCLEAR PLANTStatus of Extended Power Uprate (EPU)Rockville, MarylandDecember 15, 2010 Agenda*Introductions*Meeting Purpose
{{#Wiki_filter:TENNESSEE VALLEY AUTHORITY BROWNS FERRY NUCLEAR PLANT Status of Extended Power Uprate (EPU)
*Review BFN Extended Power Uprate Regulatory History 2*Future Plans
Rockville, Maryland December 15, 2010
-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
Agenda
*June 2004: Initial EPU Submittals*Unit 1 -100% to 120% OLTP with pressure increase
* Introductions
*Units 2 and 3 -105% to 120% OLTP
* Meeting Purpose
*February 2007: ACRS reviewed Unit 1 analyses for 120% operation  
* Review BFN Extended Power Uprate Regulatory History
*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
* Future Plans
*September 2009: EPU CAP review placed on hold pending development of CAP guidance
  - Containment Accident Pressure Mitigation
*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
  - Steam Dryers
*RevisionsrequiredtoGenericLetter89
  - Schedule 2
-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 hours None RequiredRHR-Containment CoolingNone RequiredNone RequiredSpecial EventsAppendix R(NPSH 3%)6.1 psi / 27.8 hoursNone RequiredStation Black Out1.4 psi / 1.4 hoursNone RequiredATWS1.9 psi / 1.2 hoursNone 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
Meeting Purpose
*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
* Revive Browns Ferry EPU project license submittal
*Dryer replacement is predicated by successful resolution of EPU CAP Draft Schedule for EPUSubmittals*Steam Dryer analysis and designFebruary 2012
* Confirm outstanding project scope
*NFPA-805 LAR (Appendix R Cap elimination)March 2012
* Communicate planned Containment Accident Pressure (CAP) mitigation strategy relative to Draft NRC guidelines
*Remaining plans to mitigate CAP March 2012
* Communicate plans for Steam Dryers 3
*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  
Browns Ferry EPU History
*Unit 3 EPU Spring 2016
* June 2004: Initial EPU Submittals
*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
* Unit 1 - 100% to 120% OLTP with pressure increase
*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}}
* Units 2 and 3 - 105% to 120% OLTP
* February 2007: ACRS reviewed Unit 1 analyses for 120% operation
* pp March 2007: Unit 1 approved  for 105% operation 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 4
 
EPU Modifications Modification Status U1      U2          U3 Reactor  New Main Steam Isolation Valve Internals and Actuators  Complete Complete  Complete Systems Up-rated Reactor Recirculation Motors / Pumps            Complete Complete  Complete Replacement Steam Dryers Secondary New Condensate Pumps and Motors                          Complete Complete Planned 2012 Systems Additional Condensate Demineralizer Vessel              Complete Complete Planned 2012 New Condensate Booster Pumps and Motors                  Complete Complete Planned 2012 Condensate Demineralizer Digital Upgrade                Complete Complete Planned 2012 New Reactor Feed Pumps                                  Complete Complete Planned 2012 New Reactor Feed Pump Turbines                          Complete Complete  Complete New Feedwater Heater Nozzles, Relief Valves and #3 Shell Complete Complete Planned 2012 New HP Turbine New Moisture Separator Internals                        Complete Complete  Complete New Generator Bus Duct Coolers and Fans                  Complete Complete  Complete 6
 
EPU Open Issues
* Containment Accident Pressure (CAP)
* Replacement Steam Dryers (RSD) 7
 
CAP Mitigation Evaluation
* Based on Draft Guidelines provided, 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 adder
* NPSHR 3% curve ffor S Special i lEEventst
* Evaluation conservatively used 4 feet for uncertainty adder 8
 
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) event
* IImplementation l     t ti off NFPA-805 NFPA 805 (including (i l di comprehensive h   i safef 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 9
 
CAP Evaluation Results contd Long-Term LOCA Core Spray Event:
* RHR heat exchanger performance tests have measured fouling factors significantly better than vendor values used in current CAP analyses
* Revisions required to Generic Letter 89-13 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 for Long-Term LOCA Core Spray event 10
 
CAP Evaluation Results contd Short-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
* 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 11
 
EPU CAP Summary Existing EPU        Planned EPU Submittal Submittal Values              Values Short-Term LOCA                                                     Revised values using draft Current CLTP values
(< 10 minutes)                                                     CAP guidelines Core Spray            1.47 psi < 10 minutes  2.0 psi / 8.9 minutes    2.0 psi / 9.7 minutes RHR Intact Loop          None Required      0.2 psi / 3.2 minutes    2.7 psi / 9.7 minutes RHR Broken Loop       1.57 psi < 10 minutes 2.1 psi / 9.3 minutes     5.0 psi / 10 minutes Long-Term LOCA (> 10 minutes)
Core Spray                                  3.0 psi / 22.5 hours         None Required RHR - Containment None Required              None Required Cooling Special Events Appendix R (NPSH 3%)                         6.1 psi / 27.8 hours        None Required Station Black Out                            1.4 psi / 1.4 hours          None Required ATWS                                        1.9 psi / 1.2 hours          None Required 12
 
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) 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 13
 
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 reviews
* Plan tto instrument Pl       i t       t dryer d    on llead d unitit only l tto measure performance f       d during i
power ascension to EPU conditions
* Will initiate dryer construction following approval of EPU submittal
* Dryer replacement is predicated by successful resolution of EPU CAP 14
 
Draft Schedule for EPU Submittals
* Steam Dryer analysis and design              February 2012
* NFPA-805 LAR (Appendix R Cap elimination)     March 2012
* Remaining plans to mitigate CAP               March 2012
* Unit 1 Areva fuel analysis for EPU            March 2012 NRC Activity
* 18 months for NRC review, ACRS meetings, etc.
* Issue SER for EPU September 2014 EPU 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 LOCA
* W We will ill ffollow ll  up and d iissue a kkey assumptions ti   lletter tt iin JJanuary 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
 
Questions/Comments?
Quest o s/Co e ts 17}}

Latest revision as of 05:28, 13 November 2019

Slides for December 2010 Public Meeting
ML103470631
Person / Time
Site: Browns Ferry  Tennessee Valley Authority icon.png
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)
v • d • e


Text

TENNESSEE VALLEY AUTHORITY BROWNS FERRY NUCLEAR PLANT Status of Extended Power Uprate (EPU)

Rockville, Maryland December 15, 2010

Agenda

  • Introductions
  • Meeting Purpose
  • Future Plans

- Containment Accident Pressure Mitigation

- Steam Dryers

- Schedule 2

Meeting Purpose

  • Revive Browns Ferry EPU project license submittal
  • Confirm outstanding project scope
  • Communicate planned Containment Accident Pressure (CAP) mitigation strategy relative to Draft NRC guidelines
  • Communicate plans for Steam Dryers 3

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
  • pp March 2007: Unit 1 approved for 105% operation 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 4

EPU Modifications Modification Status U1 U2 U3 Reactor New Main Steam Isolation Valve Internals and Actuators Complete Complete Complete Systems Up-rated Reactor Recirculation Motors / Pumps Complete Complete Complete Replacement Steam Dryers Secondary New Condensate Pumps and Motors Complete Complete Planned 2012 Systems Additional Condensate Demineralizer Vessel Complete Complete Planned 2012 New Condensate Booster Pumps and Motors Complete Complete Planned 2012 Condensate Demineralizer Digital Upgrade Complete Complete Planned 2012 New Reactor Feed Pumps Complete Complete Planned 2012 New Reactor Feed Pump Turbines Complete Complete Complete New Feedwater Heater Nozzles, Relief Valves and #3 Shell Complete Complete Planned 2012 New HP Turbine New Moisture Separator Internals Complete Complete Complete New Generator Bus Duct Coolers and Fans Complete Complete Complete 6

EPU Open Issues

  • Containment Accident Pressure (CAP)
  • Replacement Steam Dryers (RSD) 7

CAP Mitigation Evaluation

  • Based on Draft Guidelines provided, 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 adder
  • NPSHR 3% curve ffor S Special i lEEventst
  • Evaluation conservatively used 4 feet for uncertainty adder 8

CAP Evaluation Results

  • Use of NRC Draft Guidelines eliminates CAP for Station Black Out (SBO) event
  • IImplementation l t ti off NFPA-805 NFPA 805 (including (i l di comprehensive h i safef 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 9

CAP Evaluation Results contd Long-Term LOCA Core Spray Event:

  • RHR heat exchanger performance tests have measured fouling factors significantly better than vendor values used in current CAP analyses

CAP Evaluation Results contd Short-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
  • 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 11

EPU CAP Summary Existing EPU Planned EPU Submittal Submittal Values Values Short-Term LOCA Revised values using draft Current CLTP values

(< 10 minutes) CAP guidelines Core Spray 1.47 psi < 10 minutes 2.0 psi / 8.9 minutes 2.0 psi / 9.7 minutes RHR Intact Loop None Required 0.2 psi / 3.2 minutes 2.7 psi / 9.7 minutes RHR Broken Loop 1.57 psi < 10 minutes 2.1 psi / 9.3 minutes 5.0 psi / 10 minutes Long-Term LOCA (> 10 minutes)

Core Spray 3.0 psi / 22.5 hours5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br /> None Required RHR - Containment None Required None Required Cooling Special Events Appendix R (NPSH 3%) 6.1 psi / 27.8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> None Required Station Black Out 1.4 psi / 1.4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> None Required ATWS 1.9 psi / 1.2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> None Required 12

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) methodology
  • Data for Units 1 and 3 already taken
  • Additional data for Unit 2 to be taken Spring 2011 13

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 reviews
  • Plan tto instrument Pl i t t dryer d on llead d unitit only l tto measure performance f d during i

power ascension to EPU conditions

  • Will initiate dryer construction following approval of EPU submittal
  • Dryer replacement is predicated by successful resolution of EPU CAP 14

Draft Schedule for EPU Submittals

  • Steam Dryer analysis and design February 2012
  • Remaining plans to mitigate CAP March 2012
  • Unit 1 Areva fuel analysis for EPU March 2012 NRC Activity
  • 18 months for NRC review, ACRS meetings, etc.
  • Issue SER for EPU September 2014 EPU 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 LOCA
  • W We will ill ffollow ll up and d iissue a kkey assumptions ti lletter tt iin JJanuary 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

Questions/Comments?

Quest o s/Co e ts 17

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