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MONTHYEARML0515305472005-05-27027 May 2005 RAI Related to GL 2004-02, Potential Impact of Debris Blockage on Emergency Sump Recirculation at pressurized-water Reactors Project stage: RAI ML0516605012005-06-0202 June 2005 Waterford - RAI Related to Generic Letter 2004-02, Potential Impact of Debris Blockage on Emergency Sump Recirculation at Pressurized-Water Reactors. Project stage: RAI ML0603903862006-02-0909 February 2006 Request for Additional Information Response to Generic Letter 2004-02, Potential Impact of Debris Blockage on Emergency Recirculation During Design-Basis Accident at Pressurized-Water Reactors. Project stage: RAI W3F1-2007-0051, Request for Extension of Completion Date for Corrective Actions Required by Generic Letter 2004-022007-11-14014 November 2007 Request for Extension of Completion Date for Corrective Actions Required by Generic Letter 2004-02 Project stage: Request ML0733900652007-12-10010 December 2007 Approval of Extension Request, Corrective Actions Due Date, GL 2004-02 Potential Impact of Debris Blockage on Emergency Recirculation During Design-Basis Accidents at Pressurized Water Reactors Project stage: Other ML0801400072008-01-28028 January 2008 Report on Results of Staff Audit of Corrective Actions to Address GL 2004-02, Potential Impact of Debris Blockage on Emergency Recirculation During Design-Basis Accidents at PWRs Project stage: Other ML0801403182008-01-28028 January 2008 Staff Audit Report on Results of Corrective Actions to Address GSI-191 GL 2004-02, Potential Impact of Debris Blockage on Emergency Recirculation During Design-Basis Accidents at PWRs Project stage: Other ML0917302852009-06-11011 June 2009 Draft Request for Additional Information Generic Letter 2004-02, Potential Impact of Debris Blockage on Emergency Recirculation During Design-Basis Accidents at Pressurized Water Reactors Project stage: Draft RAI ML0917302832009-06-11011 June 2009 Email, Draft Request for Additional Information Generic Letter 2004-02, Potential Impact of Debris Blockage on Emergency Recirculation During Design-Basis Accidents at Pressurized Water Reactors Project stage: Draft RAI ML0920901072009-08-0606 August 2009 Notice of Conference Call with Entergy Operations, Inc. to Discuss Draft Request for Additional Information on Generic Letter 2004-02 for Waterford, Unit 3 Project stage: Draft RAI ML0925101242009-09-22022 September 2009 RAI, Regarding Supplemental Response to Generic Letter 2004-02, Potential Impact of Debris Blockage on Emergency Recirculation During Design Basis Accidents. Project stage: RAI ML0927200322009-10-0101 October 2009 Notice of Forthcoming Conference Call with Entergy Operations, Inc. to Discuss Waterford Steam Electric Station, Unit 3, Planned Response to Request for Additional Information on Generic Letter 2004-02 Project stage: RAI ML1005400832010-02-24024 February 2010 Forthcoming Conference Call with Entergy Operations, Inc. to Licensee'S Responses to NRC Generic Letter 2004-02 for Waterford Steam Electric Station, Unit 3 Project stage: Request ML1006903722010-03-0808 March 2010 Licensee Slides from 3/8/2010 Meeting Generic Letter 2004-02 Response to RAIs Project stage: Response to RAI ML1007003012010-04-0707 April 2010 Summary Follow-Up Conference Call with Entergy Operations, Inc. to Discuss Draft Response for Waterford, Unit 3, to the Request for Additional Information for Generic Letter 2004-02 Project stage: Draft RAI ML1013400612010-05-18018 May 2010 Notice of Forthcoming Conference Call with Entergy Operations, Inc. to Discuss Draft Response on GL-2004-02 for Waterford Steam Electric Station, Unit 3 Project stage: Draft Other ML1015204762010-06-0101 June 2010 Email, Request for Additional Information Regarding Supplemental Response to Generic Letter 2004-02, Potential Impact of Debris Blockage on Emergency Recirculation During Design Basis Accidents at Pressurized-Water Reactors Project stage: RAI ML1015302322010-06-0909 June 2010 Summary of Conference Call Meeting with Entergy Operations, Inc. to Discuss Draft Response on GL-2004-02 for Waterford Steam Electric Station, Unit 3 ML1017301902010-06-17017 June 2010 Revised Responses to the Request for Additional Information Related to GL-2004-02 Project stage: Request ML1017301952010-06-17017 June 2010 Revised Responses to the Nrc'S Request for Additional Information Related to GL-2004-02 Project stage: Request ML1017302002010-06-17017 June 2010 Chemical Effects Summary Related to RAI Response to GL-2004-02 Project stage: Other W3F1-2010-0032, Response to Request for Additional Information Regarding Final Supplemental Response to Generic Letter 2004-02, Potential Impact of Debris Blockage on Emergency Recirculation During Design Basis Accidents at Pressurized-Water Reactors2010-11-23023 November 2010 Response to Request for Additional Information Regarding Final Supplemental Response to Generic Letter 2004-02, Potential Impact of Debris Blockage on Emergency Recirculation During Design Basis Accidents at Pressurized-Water Reactors Project stage: Supplement 2009-08-06
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MONTHYEARML22034A3952022-02-16016 February 2022 Enclosure 3 - IP 96001 CY2021 - IR 8 Baseline Inspection Completion ML22034A3972022-02-16016 February 2022 Enclosure 2 - IP 92707 CY2021 - IR 8 Baseline Inspection Completion ML22034A3992022-02-16016 February 2022 Enclosure 1 - IP 71130.03 Cy 2021 - IR 8 Baseline Inspection Completion ML21354A7602021-12-20020 December 2021 Recertification of Foreign Ownership Control or Influence and Request for FOCI Redetermination - Part 15 of 18 ML21354A7462021-12-20020 December 2021 Recertification of Foreign Ownership Control or Influence and Request for FOCI Redetermination - Part 1 of 18 ML21354A7492021-12-20020 December 2021 Recertification of Foreign Ownership Control or Influence and Request for FOCI Redetermination - Part 4 of 18 ML21354A7562021-12-20020 December 2021 Recertification of Foreign Ownership Control or Influence and Request for FOCI Redetermination - Part 11 of 18 ML21354A7572021-12-20020 December 2021 Recertification of Foreign Ownership Control or Influence and Request for FOCI Redetermination - Part 12 of 18 ML21354A7592021-12-20020 December 2021 Recertification of Foreign Ownership Control or Influence and Request for FOCI Redetermination - Part 14 of 18 ML21354A7612021-12-20020 December 2021 Recertification of Foreign Ownership Control or Influence and Request for FOCI Redetermination - Part 16 of 18 ML21354A7632021-12-20020 December 2021 Recertification of Foreign Ownership Control or Influence and Request for FOCI Redetermination - Part 18 of 18 ML20329A1452020-11-20020 November 2020 Terrapower'S QAPD Preliminary Questions ML17290A0492017-10-17017 October 2017 Discussion Topics for October 19, 2017 Category 1 Public Meeting Regarding Fluence Methodology ML17041A1732017-02-10010 February 2017 Further Discussion Topics for Public Meeting to Discuss License Amendment Request Regarding the Revision of TS Table 4.3-2 for Waterford Steam Electric Station, Unit 3 CNRO-2016-00024, Entergy - Form 10-K for Fiscal Year Ended December 31, 20152016-12-20020 December 2016 Entergy - Form 10-K for Fiscal Year Ended December 31, 2015 ML15363A3742015-10-0606 October 2015 Internal Events and Internal Flooding PRA and Fire PRA NFPA 805 Record of Review ML14217A4972014-08-0404 August 2014 Attachment 5 - W3F1-2014-0005 - Waterford Steam Electric Station, Unit 3, List of Regulatory Commitments ML12181A3462012-06-28028 June 2012 Attachment 5 to W3F1-2012-0049, List of Regulatory Commitments ML12056A0522012-03-12012 March 2012 Enclosure 6 - List of Power Reactor Licensees and Holders of Construction Permits in Active or Deferred Status ML1206800622012-02-22022 February 2012 Attachment to Email, Issues Related to 10 CFR 50.59 Evaluation - License Amendment Request, Revise Technical Specification Applicability and Action Language for Revised Fuel Handling Accident Analysis ML1203705362012-01-23023 January 2012 Correction to NRC Safety Evaluation for Scv Hatch Repair ML1110807292011-04-18018 April 2011 SG Batwing Inspections Notes RFO-17 (Part 2) ML1109501252011-04-0404 April 2011 Attachment 5 to W3F1-2011-0021, List of Regulatory Commitments ML1104701842011-02-15015 February 2011 Attachment 2 to W3F1-2011-0016, Waterford, Unit 3, List of Regulatory Commitments ML1030001222010-10-27027 October 2010 Markup of Corrections for NRC LLRT Relief SER ML1017301952010-06-17017 June 2010 Revised Responses to the Nrc'S Request for Additional Information Related to GL-2004-02 ML1019304602010-03-25025 March 2010 List of Historical Leaks and Spills at Us Commercial Nuclear Power Plants ML0932105192009-11-12012 November 2009 NRC Mid-RF16 Outage Call Discussion Points ML1002215022009-03-30030 March 2009 Data Sheet for Waterford 3 Steam Electric Station, Checklist for Step 1 Review ML0821804192008-07-11011 July 2008 2008-03, Revised SRO Answer Key ML0808000362008-03-13013 March 2008 List of Attendees, 03/13/2008 Summary of Meeting with Eight Operating Nuclear Power Plant Licensees to Discuss Emerging Metallurgical Issues Certain Welds in Reactor Coolant System for Pressurized-Water Reactors ML0806704192008-03-0707 March 2008 CDBI Findings ML0805105192008-02-0606 February 2008 Modification of LPDES Permit - LA0007374 Waterford Steam Electric Station - Unit 3 (Waterford 3) ML0732400242007-10-25025 October 2007 Examples of Max Thermal Power License Conditions CNRO-2007-00038, Entergy Operations, Inc. - Proof of Financial Protection (10 CFR 140.15)2007-09-24024 September 2007 Entergy Operations, Inc. - Proof of Financial Protection (10 CFR 140.15) ML0726301142007-09-14014 September 2007 / P. Paquin Ltr Amendment to Certificate of Compliance No. 9208 for the Model No. 10-142B Package (TAC L24117)/S121170 ML0726303192007-09-14014 September 2007 P. Paquin Ltr Amendment to Certificate of Compliance No. 6574 for the Model No. 3-82B Package (TAC L24116)/ Register User List ML0721104302007-07-25025 July 2007 SDP Phase 2 Exercise ML0721104332007-07-25025 July 2007 Questions from 1 Through 8 ML0634705992006-12-14014 December 2006 Plant Service List ML0607301852006-03-31031 March 2006 Mid-Inspection Questions with the NRC for Waterford 3 Steam Generators During RF13 ML0536302482005-12-31031 December 2005 Indemnity Agreement No. B-92, Amd. 7 (New Name: Entergy Louisiana, LLC) ML0525002622005-09-0606 September 2005 Recap of NRC Emergency Planning Roundtable to Be Included in Transcript and Record ML0512401522005-05-0909 May 2005 Event Description: Attachment 7 ML0326909822005-02-14014 February 2005 August 2003 - Init Exam - Es 401-4 Rejected K/A ML0404104922004-02-20020 February 2004 Order EA-03-009 Service List ML0505404692004-02-10010 February 2004 Dynamic Web Page Printout Dated 02/10/2004, ROP PIM Report - All Sites - Event Dates: 01/01/2003 - 02/10/2004 ML0505404642004-02-0909 February 2004 Dynamic Web Page Printout Dated 02/09/2004 Regarding Applied Violations for Nuclear Power Plants 2022-02-16
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NRC RAI 18:
The October 23, 2008, supplemental response identified on page 59 that the assumptions made about the settling of particulate down to 100 microns in size were benchmarked against NRC-sponsored settling tests. Please identify the NRC-sponsored tests being referenced in this discussion.
WF3 Response 18:
The "NRC-sponsored settling tests" is referring to NUREG/CR-6916, titled "Hydraulic Transport of Coating Debris", Naval Surface Warfare Center, Carderock Division. The particulate settling size for the various materials is based on a force balance that accounts for hydraulic drag, gravity, and hydrostatic forces as prescribed in WCAP-16406-P. The developed relationship is compared (benchmarked) to the data in NUREG/CR-6916 Table 3-2 to demonstrate that the relationship produces conservative results. The data from NUREG/CR-6916 was not used as a basis for any materials settling size or depletion determination. Particulate settling is only analyzed to occur in the reactor lower plenum.
NRC RAI 33:
The supplemental response dated October 23, 2008, stated that flashing at the strainer would not occur because the strainer submergence is 8 inches and the maximum head loss is about 6 inches. This is true for a large-break LOCA, but does not address a small-break LOCA, which has a bounding submergence of about 2 inches. Please provide an evaluation for flashing during a small-break LOCA at the most limiting condition. This may require an evaluation of head loss versus submergence over time or credit for accident-generated pressure.
WF3 Response 33:
Credit for 1 psi of containment overpressure will provide > 2 ft flashing margin when submergence is less than the bounding head loss. Sump temperature will exceed 210 degrees Fahrenheit for only ~11 hrs during the event and the time to reach 210 degrees post Recirculation Actuation Signal is ~2.2 hrs. The maximum temperature profile is based on; (1) 1 of 2 Containment Spray Trains operating, (2) 1 of 4 Containment Fan Coolers operating, and (3) minimum Safety Injection flow. Waterford 3 Technical Specifications require containment pressure to be maintained between 14.275 psia and about 1 psig (27 inches water).
When expected containment pressure is compared to the saturation pressure of the sump fluid throughout the duration of an event it can be seen that adequate margin exists to support the 1 psi overpressure credit. Two cases are presented below. The first graph shows the comparison for the maximum sump temperature evaluation. The second shows the comparison for the minimum sump temperature evaluation.
Maximum Containment Profile 0 10 20 30 40 50 60 1 10 100 1000Time (hrs)Pressure (psia0 0 50 100 150 200 250Temperature (°F)Atm PressureMax Sat PressLiquid Temp Minimum Containment Profile 0 5 10 15 20 25 30 1 10 1001000Time (hrs)Pressure (psia) 0 20 40 60 80 100 120 140 160 180 200Temperature (°F)Atm PressureMin Sat PressLiquid Temp
NRC RAI 33a:
Please provide an evaluation of gas evolution downstream of the strainer that could reach the pump suction. Please provide the percentage of evolved gas estimated at the pump inlet. Evaluate the effects of any potential gas ingestion to the pumps taking suction from the sump as described in RG 1.82, Appendix A. The staff is concerned that any gasses that are stripped from the fluid as it passes through the strainer could collect within the strainer and eventually transport to the pump suction as larger air pockets. In addition, the staff has not received information that would characterize the redissolution of air or gas as the static head on the fluid increases as it flows to the pumps suction. If re-dissolution of air is credited, please provide an evaluation of the variables that could affect the redissolution.
WF3 Response 33a:
The solubility of air in water is a maximum at the lowest temperature of interest. The table of dissolved air in water at 25 °C clearly shows that the solubility is proportional to absolute pressure. The difference of solubility is 0.023 g Air / kg Water per one atm. A conservatively bounding pressure difference across the strainer of 2.5 ft (0.07 atm) is used in this analysis.
Assuming conservatively that the water entering the strainer is fully saturated with air, the bounding difference of solubility of air in water is:
0.07
- 0.023 = 0.00169 g Air / kg Water or 1.69E-6 kg Air / kg Water Dissolved Air in Water (25 °C)(77 °F) Gauge Pressure (atm) 0 1 2 3 4 5 Dissolved Air (g/kg) 0.023 0.045 0.068 0.091 0.114 0.136 The densities are:
Air - 1.169 kg/m3 at 25 °C and one atm Water - 997 kg/m3 at 25 °C The volume ratio therefore becomes; (1.69E-6 kg Air / kg Water) * (997 kg/m3) / (1.169 kg/m3) = 0.0014 or 0.14%
As the flow stream leaves the sump it travels downward where it experiences an increase in pressure due to the elevation difference (~30 ft). This increase in pressure would promote some of the air re-dissolving back into the water and void size reduction due to compression. Conservatively neglecting the re-dissolution of air and using the ideal gas law to evaluate the void compression, the 0.14% void fraction equates to a 0.07% void fraction at the pump suction.
P 1 V 1 = P 2 V 2; therefore V 2 = P 1 V 1/P 2 P 1 = 14.7 psia
- 2.31 ft/psi = 34 ft P 2 = P 1 + 30 ft = 64 ft V 2 = 0.14%
Using the relationship from Regulatory Guide 1.82, it can be seen that the 0.07% void fraction will have a negligible effect (<1 ft) on pump required net positive suction head.
NPSHrequired' = NPSHrequired * (1+0.5*) where is the air ingestion rate in percent by volume Highest NPSHrequired for any ECCS pump operating at runout conditions is 21.765 ft 21.765 ft * (1 + 0.5
- 0.07%) = 22.527 ft or an increase of 0.762 ft