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Results
Other: ML072400136, ML073520077, ML081640402, ML082140699, ML082190813, ML082380949, ML082490542, ML082490545, ML082490546, ML083120421, NL-07-1261, Applicant'S Environmental Report Operating License Renewal Stage, NL-07-2119, License Renewal Application - Environmental Site Audit Information Request - Follow Up Response
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MONTHYEARML0710202262007-04-0404 April 2007 Letter Transmitting Edwin I. Hatch, Joseph M. Farley, and Vogtle 2006 Annual Occupational Radiation Exposure Reports Project stage: Request ML0712204712007-04-30030 April 2007 Enclosure 3, Vogtle, Units 1 & 2 - Annual Radioactive Effluent Release Report for 2006 Project stage: Request ML0713600572007-05-14014 May 2007 Annual Radiological Environmental Operating Report for 2006 Project stage: Request NL-07-1261, Applicant'S Environmental Report Operating License Renewal Stage2007-06-30030 June 2007 Applicant'S Environmental Report Operating License Renewal Stage Project stage: Other ML0721300842007-08-15015 August 2007 Federal Register Notice: Vogtle Electric Generating Plant, Units 1 and 2 Project stage: Request ML0721403372007-08-21021 August 2007 FRN - Notice of Intent to Prepare an Environmental Impact Statement and Conduct Scoping Process Project stage: Request ML0724001362007-09-0505 September 2007 Environmental Site Audit Regarding Vogtle Electric Generating Plant, Units 1 and 2, License Renewal Application (TAC Nos. MD5905 and MD5906) Project stage: Other ML0728405302007-09-27027 September 2007 Environmental Scoping Meeting Transcripts for Vogtle, Units 1 and 2, License Renewal Application Project stage: Meeting ML0728405292007-09-27027 September 2007 Environmental Scoping Meeting Transcripts for Vogtle, Units 1 and 2, License Renewal Application Project stage: Meeting ML0727502612007-10-0101 October 2007 Scoping Fleeting Handouts; Presentation Project stage: Request ML0728409632007-10-12012 October 2007 Summary of Public Environmental Scoping Meetings Related to the Review of the Vogtle Electric Generating Plant, Units 1 and 2, License Renewal Application (TAC Nos. MD5905 and MD5906) Project stage: Meeting ML0728411072007-10-24024 October 2007 Request for Additional Information Regarding Severe Accident Mitigation Alternatives for Vogtle Electric Generating Plant, Units 1 and 2, License Renewal (TAC Nos. MD5905 and 5906) Project stage: RAI NL-07-2119, License Renewal Application - Environmental Site Audit Information Request - Follow Up Response2007-11-12012 November 2007 License Renewal Application - Environmental Site Audit Information Request - Follow Up Response Project stage: Other ML0731201192007-11-16016 November 2007 Summary of Conference Call with Southern Nuclear Operating Company, Inc., to Discuss the Severe Accident Mitigation Alternatives Requests for Additional Information for Vogtle Electric Generating Plant, Units 1 and 2 Project stage: RAI ML0731112132007-11-19019 November 2007 Summary of Site Audit Related to the Review of the License Renewal Application for Vogtle Electric Generating Plant, Units 1 and 2 (TAC Nos. MD5905 and MD5906) Project stage: Approval ML0735200772007-12-0505 December 2007 E-mail from Karen Kaniatobe of Absentee Shawnee Tribe License Renewal for Vogtle, Units 1 & 2 Project stage: Other NL-08-0109, License Renewal Application, Follow Up to Severe Accident Mitigation Alternatives Request for Additional Information Review Questions2008-02-0101 February 2008 License Renewal Application, Follow Up to Severe Accident Mitigation Alternatives Request for Additional Information Review Questions Project stage: Request ML0811202792008-04-21021 April 2008 FRN - Notice of Availability of the Draft Plant-Specific Supplement 34 to the Generic Environmental Impact Statement for License Renewal of Nuclear Plants (TAC MC5905 and TAC MD5906) Project stage: Draft Other ML0810802992008-04-30030 April 2008 NUREG-1437 Supp 34 Dfc, Generic Environmental Impact Statement for License Renewal of Nuclear Plants, Regarding Vogtle Electric Generating Plant, Units 1 & 2. Project stage: Acceptance Review ML0816201172008-06-0303 June 2008 Transcript of Vogtle License Renewal Draft SEIS Public Afternoon Meeting on June 3, 2008 in Waynesboro, Georgia Project stage: Draft Approval ML0816500462008-06-0303 June 2008 License Renewal Dseis Meeting Evening Transcript Project stage: Meeting ML0824905462008-06-10010 June 2008 Comment (9) of Karen Anderson-Cordova on Behalf of the Georgia Department of Natural Resources Approving the License Renewal Application Review of Vogtle Electric Generating Plant, Units 1 and 2 Project stage: Other ML0816404022008-06-10010 June 2008 Response in Regard to License Renewal Application Review on Impacts to Historic Properties Project stage: Other ML0819000162008-06-26026 June 2008 Comment (1) of Heinz J. Mueller, on Behalf of the United States Environmental Protection Agency, on Draft Generic Supplemental Environmental Impact Statement, Vogtle Electric Generating Plant Site, Supplement 34, NUREG-1437 Project stage: Request NL-08-1038, Comment (6) of T. E. Tynan on Behalf of Southern Nuclear Operating Company, Inc., on Draft Generic Environmental Impact Statement for License Renewal of Vogtle, Units 1 & 2, Supplement 342008-07-14014 July 2008 Comment (6) of T. E. Tynan on Behalf of Southern Nuclear Operating Company, Inc., on Draft Generic Environmental Impact Statement for License Renewal of Vogtle, Units 1 & 2, Supplement 34 ML0819902122008-07-14014 July 2008 License Renewal Application Comments on Draft Generic Environmental Impact Statement for License Renewal of Nuclear Plants, Supplement 34 ML0821000892008-07-18018 July 2008 Lr Dseis Comments from Dept. of Interior Project stage: Request ML0825200082008-07-18018 July 2008 Comment (7) of Gregory Hogue on Behalf of Us Dept of Interior, Draft Generic Environmental Impact Statement, NUREG-1437, Supplement 34 for License Renewal Nuclear Plants, Regarding Vogtle Electric Generating Plant, Units 1 and 2 ML0821908132008-07-22022 July 2008 Comment (3) of Sara Barczak on Behalf of Southern Alliance for Clean Energy (Sace) on the Dseis for Vogtle License Renewal (Revised Comments, in Place of 07/16/2008 Comments) Project stage: Other ML0821406992008-08-0101 August 2008 Scdnr Comments on Vogtle License Renewal Dseis Project stage: Other ML0824905452008-08-0101 August 2008 Comment (8) of Vivianne Vejdani on Behalf of the South Carolina Department of Natural Resources on the License Renewal Application Review of Vogtle Electric Generating Plant, Units 1 and 2 Project stage: Other ML0824905422008-08-0505 August 2008 Comment (4) of Roy E. Crabtree on Behalf of National Marine Fisheries Service on Generic Environmental Impact Statement, and Biological Assessment for Vogtle, Units 1 and 2, License Renewal Application Review Project stage: Other ML0823809492008-09-0303 September 2008 Project Manager Change for the License Renewal Environmental Review for Vogtle Electric Generating Plant, Units 1 and 2 Project stage: Other ML0831204212008-12-0808 December 2008 Notice of Availability of the Final Plant-Specific Supplement 34 to the Generic Environmental Impact Statement for License Renewal of Nuclear Plants Regarding Vogtle Electric Generating Plant, Units 1 and 2 Project stage: Other ML0833803252008-12-31031 December 2008 NUREG-1437 Supplement 34 Generic Environmental Impact Statement for the License Renewal of Nuclear Plants Regarding Vogtle Electric Generating Plant, Units 1 and 2, Final Report Project stage: Acceptance Review 2007-09-05
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Category:Letter
MONTHYEARML24032A0252024-02-0505 February 2024 NRC Initial Test Program and Operational Programs Integrated Inspection Report 05200026-2023009 ML24010A0712024-01-31031 January 2024 Exemption from Select Requirements of 10 CFR Part 73 (Security Notifications, Reports and Recordkeeping and Suspicious Activity Reporting) ML24031A6102024-01-31031 January 2024 Cyber Security Inspection Report 05200026/2024401 - Public ML24029A0592024-01-30030 January 2024 Request for Withholding Information from Public Disclosure Responses to NRC Request for Additional Information for Refueling Outage 1R24 Steam Generator Tube Inspection Report Enclosure 2, GAE-NRCD-RF-LR-000002 P-Attachment, Rev. 0 ML24016A1132024-01-30030 January 2024 Correction of Unit 1 Amendment Nos. 96 and 190 and Unit 2 Amendment Nos. 74 and 173 Adoption of Standard Technical Specifications Westinghouse Plants NL-24-0031, Inservice Inspection Program Owner'S Activity Report (OAR-1) for Outage 2R232024-01-29029 January 2024 Inservice Inspection Program Owner'S Activity Report (OAR-1) for Outage 2R23 IR 05000424/20244032024-01-26026 January 2024 Information Request for the Cyber-Security Baseline Inspection, Notification to Perform Inspection 05000424/2024403; 05000425/2024403 NL-24-0020, Plan, Unit 1 Responses to NRC Request for Additional Information for Refueling Outage 1R24 Steam Generator Tube Inspection Report2024-01-22022 January 2024 Plan, Unit 1 Responses to NRC Request for Additional Information for Refueling Outage 1R24 Steam Generator Tube Inspection Report ML23347A2092024-01-17017 January 2024 Voluntary Requests for Data, Information, And/Or Observation ML23279A0042024-01-17017 January 2024 Amendment No. 194 to Remove Combined License Appendix C NL-23-0926, Correction of Technical Specification Typographical Error2024-01-12012 January 2024 Correction of Technical Specification Typographical Error ML23341A2042024-01-12012 January 2024 Request for Additional Information Exemption Requests for Physical Barriers (EPID L-2023-LLE-0018 & L-2023-LLE-0021) ML23345A1312024-01-0303 January 2024 Withholding Letter - SNC Fleet - Physical Barriers Exemption (L-2023-LLE-0018 and L-2023-LLE-0021) ML23317A2072023-12-22022 December 2023 Issuance of Amendments 223 and 206 Regarding Revision to Technical Specifications to Adopt TSTF-339-A, Relocate Technical Specification Parameters to the COLR Consistent with WCAP-1448 ML23335A1222023-12-19019 December 2023 Safety Evaluation Regarding Implementation of Mitigating Strategies Related to Order EA-12-049 (EPID L-2023-LRQ-0002) - Letter ML23353A1702023-12-19019 December 2023 LAR-22-002, TS 3.8.3 Inverters Operating Completion Time Extension Letter ML23310A2922023-12-0707 December 2023 Issuance of Amendment for Exception to Regulatory Guide 1.163, LAR 23 007 ML23339A1812023-12-0707 December 2023 Correction Letter Regarding License Amendment Request: More Restrictive Action for Technical Specification 3.1.9 ML23338A2182023-12-0606 December 2023 Project Manager Reassignment NL-23-0878, Request for Exemption from Security Event Notification Implementation2023-11-29029 November 2023 Request for Exemption from Security Event Notification Implementation ML23289A1632023-11-28028 November 2023 Letter and Amendment 195 and 192 LAR-23-006R1 TS 3.1.9 More Restrictive Action NL-23-0827, Response to Requests for Additional Information for a License Amendment Request and a Proposed Alternative Related to TS 3.4.142023-11-17017 November 2023 Response to Requests for Additional Information for a License Amendment Request and a Proposed Alternative Related to TS 3.4.14 ML23318A4582023-11-14014 November 2023 Integrated Inspection Report 05200025/2023003 ML23312A3502023-11-14014 November 2023 Integrated Inspection Report 05200026/2023003 ML23306A3552023-11-0808 November 2023 NRC Initial Test Program and Operational Programs Integrated Inspection Report 052000/262023008 ML23268A0572023-11-0707 November 2023 Issuance of Amendments 194 & 191 Request for License Amendment Relocation of Technical Specification 3.7.9, Spent Fuel Pool Makeup Water Sources (LAR-23-003) IR 05000424/20234022023-11-0606 November 2023 Security Baseline Inspection Report 05000424/2023402 and 05000425/2023402 IR 05000424/20230032023-10-27027 October 2023 Integrated Inspection Report 05000424/2023003 and 05000425/2023003 ML23291A1512023-10-18018 October 2023 Information Request for the Cyber Security Baseline Inspection, Notification to Perform Inspection 0520026/2024401 ML23263A9852023-10-12012 October 2023 Issuance of Amendments Nos. 221 and 204, Regarding Technical Specification 5.5.11.C, Acceptance Criteria for Charcoal Filter Testing ML23283A0472023-10-0808 October 2023 Neop Letter Dated October 8, 2023 - Vogtle 3 & 4 - TS 3.7.6 License Amendment Request NL-23-0750, Response to Second Request for Additional Information Regarding License Amendment Request: Technical Specification Revision to Adopt TSTF-339-A, Relocate Technical Specification Parameters to the Colr2023-10-0404 October 2023 Response to Second Request for Additional Information Regarding License Amendment Request: Technical Specification Revision to Adopt TSTF-339-A, Relocate Technical Specification Parameters to the Colr NL-23-0745, Refueling Outage 1R24 Steam Generator Tube Inspection Report2023-09-22022 September 2023 Refueling Outage 1R24 Steam Generator Tube Inspection Report ML23254A2032023-09-13013 September 2023 Initial Test Program and Operational Programs Inspection Report 05200025/2023013 ML23241B0212023-09-12012 September 2023 Review of Quality Assurance Topical Report ML23234A2352023-09-0808 September 2023 Request for Withholding Information from Public Disclosure Notification of Full Compliance of Required Action for NRC Order EA-12-049 Mitigation Strategies for Beyond-Design-Basis External Events IR 05000424/20230912023-09-0505 September 2023 Plan Units 1 and 2 - NRC Investigation Report 2-2022-006 and Notice of Violation - NRC Inspection Report 05000424/2023091 and 05000425/2023091 ML23234A3002023-09-0101 September 2023 NRC Integrated Inspection Report 05200026/2023003 ML23243A0092023-08-31031 August 2023 Updated Inspection Plan for Vogtle Electric Generating Plant, Units 3 & 4 (Report 05200025 2023005 & 05200026 2023005) NL-23-0695, Response to Round 2 Request for Additional Information Regarding License Amendment Request for Technical Specification 3.8.3, Inverters Operating, Completion Time Extension (LAR-22-002S2)2023-08-31031 August 2023 Response to Round 2 Request for Additional Information Regarding License Amendment Request for Technical Specification 3.8.3, Inverters Operating, Completion Time Extension (LAR-22-002S2) ML23243B0252023-08-30030 August 2023 Exam Corporate Notification Letter (210 Day) IR 05000424/20230052023-08-29029 August 2023 Updated Inspection Plan for Vogtle Electric Generating Plant, Units 1 & 2 - Report 05000424/2023005 and 05000425/2023005 NL-23-0666, License Amendment Request: Remove Combined License Appendix C (LAR 23-008)2023-08-28028 August 2023 License Amendment Request: Remove Combined License Appendix C (LAR 23-008) 2024-02-05
[Table view] Category:Meeting Summary
MONTHYEARML24025A1372024-01-31031 January 2024 Summary of Observation Pre-Submittal Meeting Held with Snc., Regarding a Proposed Alternative Request - Explosively Actuated Valves for Vogtle Electric Generating Plant, Units 3 and 4 ML24019A1932024-01-30030 January 2024 Summary of January 8, 2024, Observation Pre-Submittal Meeting Held with Southern Nuclear Operating Company Regarding a Proposed LAR for Vogtle Electric Generating Plant, Units 1, 2, 3, & 4; Hatch, Units 1 & 2; Farley, Units 1 & 2 ML23356A0282023-12-27027 December 2023 December 11, 2023, Pre-Application Meeting with SNC Regarding a Proposed Fleet LAR to Revise TS 5.3.1 to Relocate Training Qualification Requirements from TS to Their Qatr/Ndqam ML23311A1302023-11-17017 November 2023 Summary of Nov. 6, 2023, - Closed Meeting Held with Southern Nuclear Operating Company, Inc., Regarding Physical Barriers Exemptions for Hatch Units 1 & 2, Farley Units 1 & 2 and Vogtle Units 1, 2, 3 & 4 (EPID L-2023-LLE-0018 & L-2023-LLE-0 ML23313A0952023-11-16016 November 2023 Summary of November 7, 2023, Observation Pre-Submittal Meeting Held with Southern Nuclear Operating Company, Inc., Regarding a Proposed License Amendment Request for Vogtle Electric Generating Plant, Units 1 and 2 ML23303A2032023-11-0101 November 2023 October 24, 2023, Summary of Comment Gathering Public Meeting on Lessons Learned from the ITAAC Hearing Process for Vogtle Units 3 and 4 ML23275A0882023-10-12012 October 2023 Summary of Meeting with Southern Nuclear Operating Company ML23272A1822023-10-11011 October 2023 Summary of September 28, 2023, Observation Pre Submittal Meeting Held with Southern Nuclear Operating Company, Inc., Regarding a Proposed License Amendment Request for Vogtle Electric Generating Plant, Units 3 and 4 ML23230A0212023-08-30030 August 2023 LAR-22-002 Technical Specification 3.8.3 Summary of 08-17-23 Public Meeting ML23187A5742023-08-22022 August 2023 Summary of June 29, 2023, Meeting with Southern Nuclear Operating Company ML23146A1542023-06-0505 June 2023 Summary of May 25, 2023, Meeting with Southern Nuclear Operating Company ML23132A0412023-05-18018 May 2023 Summary of May 11, 2023, Meeting with Southern Nuclear Operating Company ML23121A1692023-05-12012 May 2023 Summary of Meeting with Southern Nuclear Operating Company Vogtle LAR-23-006 U/3&4 More Restrictive Action for TS 3.1.9 Cvs Isolation Valves ML23115A3282023-05-10010 May 2023 Summary of Public Meeting with Southern Nuclear Operating Company to Have a Pre-Submittal Discussion of Draft License Amendment Request (LAR) for Vogtle Electric Generating Plant (VEGP) Unit 3 ML23115A0662023-05-0101 May 2023 Summary of Public Meeting with Southern Nuclear Operating Company to Have Presubmittal Meeting for Vogtle Electric Generating Plant, Unit 4 IR 05000424/20040252023-04-28028 April 2023 Public Meeting Summary - Vogtle Electric Generating Plant, Units 1, 2, 3, & 4 Docket No. 5000424, 5000425, 5200025, 5200026, Meeting Number 20230375 ML23090A1422023-04-0303 April 2023 Summary of Conference Call Regarding the Spring 2022 Steam Generator Tube Inspections ML23065A0732023-03-17017 March 2023 March 2, 2023, Summary of Meeting with Southern Nuclear Operating Company - Vogtle Electric Generating Plant, Unit 4 ML23055A0902023-03-14014 March 2023 February 16, 2023, Summary of Meeting with Southern Nuclear Operating Company ML23048A0682023-03-0101 March 2023 Summary of February 13, 2023, Observation Pre-Submittal Meeting Held with Southern Nuclear Operating Company, Inc. Regarding a Proposed License Amendment Request for Vogtle Electric Generating Plant, Units 1 and 2 ML23037A0032023-02-0606 February 2023 Summary of February 2, 2023, Public Meeting with Southern Nuclear Operating Company ML23012A0512023-01-17017 January 2023 January 11, 2023, Summary of Public Meeting with Southern Nuclear Operating Company (SNC) Regarding Vogtle Emergency Technical Specification Amendment ML22349A2142023-01-0303 January 2023 Summary of December 8, 2022, Public Meeting with Southern Nuclear Operating Company ML22336A0812022-12-0505 December 2022 Summary of December 1, 2022, Observation Pre-Submittal Meeting Held with Southern Nuclear Operating Company, Inc., Regarding a Proposed License Amendment Request for Vogtle Electric Generating Plant, Units 1 and 2 ML22335A4922022-12-0202 December 2022 Summary of Observation Pre-Submittal Meeting Held with Southern Nuclear Operating Company, Inc., Regarding a Proposed License Amendment Request for Vogtle Electric Generating Plant, Units 1 and 2 ML22319A0132022-11-30030 November 2022 Summary of a Public Meeting with Southern Nuclear Operating Company on November 10, 2022 ML22322A1672022-11-28028 November 2022 Summary of 11/15/2022 Public Meeting on Lessons Learned ML22271A0182022-10-0404 October 2022 Summary of Public Meeting with SNC on Lessons Learned Final ML22257A2362022-09-19019 September 2022 Summary of September 13, 2022, Partially Open and Partially Closed Pre-Submittal Meeting Held with SNC, Regarding a Proposed OLM License Amendment Request for Vogtle Electric Generating Plant, Units 1 and 2 ML22243A0302022-09-0909 September 2022 Summary of a Public Meeting with Southern Nuclear Operating Company on August 25, 2022 ML22145A6052022-06-0202 June 2022 Summary of May 24, 2022, Public Meeting with SNC, Regarding a Proposed Alternative Request for Performance-Based Leakage Test Frequencies for the Refueling Water Tank Suction Check Valves for Vogtle, Units 1 & 2 ML22145A4492022-05-27027 May 2022 Summary of May 23, 2022, Public Meeting with SNC, Regarding a Proposed License Amendment Request to Change Technical Specification 3.8.1 and Implement TSTF-163 for Vogtle Electric Generating Plant, Units 1 and 2 ML22131A3422022-05-18018 May 2022 Summary of Public Meeting with Southern Nuclear Operating Company, Inc., Regarding a Proposed License Amendment Requests to Implement Alternate Source Term, TSTF-51, TSTF-471, and TSTF-490 for Vogtle, Units 1 & 2 (EPID No. L-2022-LRM-0033 ML22132A0102022-05-17017 May 2022 Meeting of Public Meeting with Southern Nuclear Operating Company, Inc., Regarding Proposed Accident Tolerant Fuel License Amendment Request and Exceptions for Vogtle Electric Generating Plant, Units 1 and 2 ML22123A0652022-05-0202 May 2022 Public Meeting Summary Vogtle Electric Generating Plant, Units 1, 2, 3, & 4 Docket No. 50-424, 50-425, 52-025, 52-026, Meeting Number 20220330 ML22098A1292022-04-26026 April 2022 Summary of March 31, 2022 Public Meeting with Southern Nuclear Operating Company ML22095A2292022-04-11011 April 2022 Summary of Conference Call Regarding the Spring 2022 Steam Generator Tube Inspections ML22077A5432022-04-0404 April 2022 Summary of Meeting with Southern Nuclear Operating Co ML22028A0462022-02-0101 February 2022 MTS - Meeting Summary - Pre-Submittal Meeting on January 27, 2022 - Vogtle ATF LAR and Exemption ML21337A0032021-12-0707 December 2021 Summary of Vogtle Readiness Group Public Meeting on December 2, 2021 ML21322A1502021-12-0202 December 2021 Summary of November 10, 2021 Public Meeting with Southern Nuclear Operating Company ML21316A0692021-11-22022 November 2021 November 4, 2021 Summary of Public Meeting with Southern Nuclear Operating Company ML21313A1172021-11-18018 November 2021 Summary of Public Meeting with Southern Nuclear Operating Company, Inc., Regarding a Proposed License Amendment Request to Change the Technical Specification Related to Technical Specification 5.5.16 for Joseph M. Farley Nuclear Plant ML21238A1622021-09-10010 September 2021 Summary of Public Meeting with Southern Nuclear Operating Company, Inc., Regarding a Proposed License Amendment Request to Change the Technical Specification Related to Main Steam Isolation Valves for Vogtle Electric Generating Plant ML21225A5532021-08-31031 August 2021 August 13,2021, Public Meeting Summary with Southern Nuclear Operating Regarding Proposed LAR to Revise Technical Specifications Related to Reactor Trip System & Engineered Safety Feature Actuation System Instrumentation for Vogtle 1&2 (L-2 ML21230A0102021-08-24024 August 2021 Summary of Public Meeting with Southern Nuclear Operating Company on August 12, 2021 ML21154A2772021-07-20020 July 2021 Summary of a Public Meeting with Southern Nuclear Operating Company on May 27, 2021 ML21194A0402021-07-20020 July 2021 Summary of June 24, 2021 Public Meeting with SNC ML21190A0622021-07-16016 July 2021 Summary of July 8 2021 Public Meeting to Discuss Late-Filed Allegation Process for Vogtle Electric Generating Plant Units 3 and 4 2024-01-31
[Table view] Category:Request for Additional Information (RAI)
MONTHYEARIR 05000424/20244032024-01-26026 January 2024 Information Request for the Cyber-Security Baseline Inspection, Notification to Perform Inspection 05000424/2024403; 05000425/2024403 ML23341A2042024-01-12012 January 2024 Request for Additional Information Exemption Requests for Physical Barriers (EPID L-2023-LLE-0018 & L-2023-LLE-0021) ML23342A0802023-12-0808 December 2023 NRR E-mail Capture - Request for Additional Information (RAI) - Vogtle, Unit 1 - Review of SG Tube Inspection Report for Refueling Outage 24 (L-2023-LRO-0067) ML23279A2082023-10-0505 October 2023 Issuance of Formal RAIs - Vogtle, Units 1 and 2 - Proposed LAR and Proposed Alternative Request to Revise TS 3.4.14.1 and IST ALT-VR-02 (EPIDs L-2023-LLA-0061 and L-2023-LLR-0023) ML23257A2092023-09-14014 September 2023 NRR E-mail Capture - Formal Issuance of 2nd Round RAIs for Surry Units 1&2 and North Anna Units 1&2 Emergency Plans LAR ML23248A3482023-09-0505 September 2023 NRR E-mail Capture - for Your Action - Request for Additional Information (RAI) 6 - Vogtle - TSTF-339 LAR (L-2023-LLA-0053) ML23243A9862023-08-31031 August 2023 NRR E-mail Capture - Draft RAIs for EP Staff Augmentation Times LAR (L-2022-LLA-0166) ML23188A1512023-08-0909 August 2023 Round 2 RAIs for LAR 22-002 TS 3.8.3 Inverters-Operating, Completion Time Extension ML23200A0112023-07-18018 July 2023 Document Request for Vogtle Unit 3 RP Inspection ML23198A1552023-07-17017 July 2023 NRR E-mail Capture - for Your Action - Request for Additional Information (RAI) - Hatch, Farley, and Vogtle, Units 1 and 2 Quality Assurance Topical Report (QATR) Submittal Dated June 15, 2023 ML23193A7832023-07-12012 July 2023 NRR E-mail Capture - for Your Action - Request for Additional Information (RAI) - Vogtle - TSTF-339 LAR (L-2023-LLA-0053) ML23065A0612023-03-0303 March 2023 NRR E-mail Capture - for Your Action - Request for Additional Information (RAI) 14 - Vogtle - AST, TSTF-51, TSTF-471, and TSTF-490 LAR (L-2022-LLA-0096) ML23006A0882023-01-0606 January 2023 NRR E-mail Capture - for Your Action - Request for Additional Information (RAI) - Vogtle - Accident Source Term (Ast), TSTF-51, TSTF-471, and TSTF-490 LAR (L-2022-LLA-0096) ML22348A0332022-12-13013 December 2022 NRR E-mail Capture - for Your Action - RAI - Vogtle, Unit 2 - Steam Generator Tube Inspection Report (L-2022-LRO-0120) ML22192A1042022-08-0101 August 2022 Acceptance of Requested Licensing Action Amendment Request Application to Allow Use of Lead Test Assemblies for Accident Tolerant Fuel with Request for Additional Information ML22157A0902022-06-0606 June 2022 NRR E-mail Capture - RAIs - Vogtle, Unit 1 - Refueling Outage (RFO) 1R23 Steam Generator (SG) Tube Inspection Report ML22104A1312022-04-14014 April 2022 NRR E-mail Capture - Request for Additional Information - Farley and Vogtle - Relocate Piping Inspection License Amendment Request (L-2021-LLA-0235) ML22026A3942022-01-26026 January 2022 NRR E-mail Capture - Request for Additional Information - Vogtle, Units 1 and 2, TS 3.7.2 LAR ML21350A1032021-12-16016 December 2021 NRR E-mail Capture - Request for Additional Information - Vogtle, Units 1 and 2, TS 3.7.2 LAR ML21321A3762021-11-15015 November 2021 NRR E-mail Capture - Request for Additional Information - Vogtle, Units 1 and 2, TS 3.7.2 LAR ML21075A0032021-03-12012 March 2021 Emergency Preparedness Exercise Inspection Request for Information for - Brunswick, Catawba, North Anna, Oconee, Vogtle 1 & 2 ML21033B1072021-02-0202 February 2021 NRR E-mail Capture - RAI - Vogtle Unit 1 - SG Report (L-2020-LRO-0059) ML20338A1512020-12-0303 December 2020 NRR E-mail Capture - RAIs for Vogtle GSI-191 LAR (L-2020-LLA-0182) ML20325A0432020-11-20020 November 2020 NRR E-mail Capture - for Your Review - Draft RAIs for Vogtle GSI-191 LAR (L-2020-LLA-0182) ML20297A3052020-10-22022 October 2020 NRR E-mail Capture - RAIs for Vogtle Relief Request - EPRI Report (L-2020-LLR-0109) ML20293A0752020-10-14014 October 2020 NRR E-mail Capture - RAIs for SNC Fleet EP LAR (L-2020-LLA-0150 and L-2020-LLA-0151) ML20149K6252020-05-27027 May 2020 NRR E-mail Capture - RAIs for SNC Fleet Fire Protection Exemption Requests ML19263A6432019-09-19019 September 2019 NRR E-mail Capture - RAI - Vogtle End State License Amendment Request (LAR) to Revise the Technical Specifications (Tss) for Vogtle, Units 1 and 2 (L-2019-LLA-0148) ML19156A1872019-06-0505 June 2019 NRR E-mail Capture - Request for Additional Information (RAI) for Vogtle Unit 2 Core Operating Limits Report, Cycle 21 ML19105B1632019-04-15015 April 2019 NRR E-mail Capture - Request for Additional Information (RAI) for Voglte TSTF-412 Adoption LAR (L-2018-LLA-0731) ML18355A4772019-01-0404 January 2019 Request for Additional Information Revise TS 5.2.2.g and Update Emergency Plan Minimum On-Shift Staff Tables ML18337A4032018-12-0606 December 2018 Request for Additional Information Revise Technical Specification 5.2.2.G and Updating Emergency Plan Minimum On-Shift Staff Tables ML18236A4452018-08-30030 August 2018 Review of Response to RAI License Amendment Request for Approval to Utilize the Tornado Missile Risk Evaluator to Analyze Tornado Missile Protection Non-Conformances ML18227A0222018-08-15015 August 2018 Notification of Inspection and Request for Information ML18225A3362018-08-13013 August 2018 NRR E-mail Capture - Request for Additional Information Regarding Relief Request VEGP-ISI-RR-03 ML18197A0602018-07-13013 July 2018 Us NRC Final RAI No. 1 for Vogtle 3 and 4 LAR-18-015, Fire Protection System Non-Safety Cable Spray Removal ML18197A1882018-07-13013 July 2018 Us NRC Final Request for Additional Information (Final RAI) No. 4 on Vogtle LAR-17-024, Technical Specification Updates for Reactivity Controls and Other Miscellaneous Changes ML18197A1052018-07-13013 July 2018 Us NRC Final Request for Additional Information (Final RAI) No. 1 on Vogtle 3 and 4 LAR-17-043, Containment Pressure Analysis ML18192C0782018-07-11011 July 2018 RAI (LAR 18-009) - Vogtle Electric Generating Plant, Unit 3 and 4 ML18192B7692018-07-11011 July 2018 Us NRC Draft Request for Additional Information (Draft RAI) No. 4 on Vogtle LAR-17-024, Technical Specification Updates for Reactivity Controls and Other Miscellaneous Changes ML18136A4972018-06-0101 June 2018 Request for Additional Information, License Amendment Request to Incorporate Tornado Missile Risk Evaluator Methodology Into Licensing Basis ML18109A1152018-05-0101 May 2018 Request for Additional Information ML18079A9572018-03-28028 March 2018 Request for Additional Information Incorporate Seismic Probabilistic Risk Assessment Into the 10 CFR 50.69 Categorization Process (CAC Nos. MF9861 and MF9862; EPID L-2017-LLA-0248) ML18058A0812018-02-27027 February 2018 Enclosurequest for Additional Information(Rai for Review of Southern Nuclear Operating Company'S Decommissioning Funding Plan Updates for Joseph M. Farley,Unit 1 and 2;Edwin I. Hatch,Units 1 and 2; and Vogtle Electric Generating Plant, Unit ML18030B0622018-02-0808 February 2018 Request for Additional Information Reverse Technical Specification 5.5.17 for Permanent Extension of Type a and Type C Leak Rate Test Frequencies (CAC Nos. MG0240, MG0241; EPID L-2017-LLA-0295) ML17355A1012018-01-11011 January 2018 Request for Additional Information (CAC Nos. MF9685 and MF9686; EPID L-2017-TOP-0038) ML17354A7822018-01-0505 January 2018 Request for Additional Information Incorporate Seismic Probabilistic Risk Assessment Into the 10 CFR 50.69 Categorization Process (CAC Nos. MF9861 and MF9862; EPID L-2017-LLA-0248) ML17318A0352017-11-22022 November 2017 Request for Additional Information 2024-01-26
[Table view] |
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November 16, 2007 LICENSEE: Southern Nuclear Operating Company, Inc FACILITY: Vogtle Electric Generating Plant, Units 1 and 2
SUBJECT:
SUMMARY
OF CONFERENCE CALL WITH SOUTHERN NUCLEAR OPERATING COMPANY, INC., TO DISCUSS THE SEVERE ACCIDENT MITIGATION ALTERNATIVES REQUESTS FOR ADDITIONAL INFORMATION FOR VOGTLE ELECTRIC GENERATING PLANT, UNITS 1 AND 2 (TAC NOS.
MD5905, MD5906)
On October 29, 2007, the U.S. Nuclear Regulatory Commission (NRC) staff and its contractors from Pacific Northwest National Laboratory conducted a conference call (teleconference) with representatives from Southern Nuclear Operating Company, Inc. (SNC), and its contractors from Tetra Tech and ERIN Engineering and Research, Inc., to discuss the Vogtle Electric Generating Plant, Units 1 and 2 (VEGP) severe accident mitigation alternatives (SAMA) requests for additional information (RAIs) (ML072750508). The NRC staff formally sent the SAMA RAIs to SNC by letter dated October 24, 2007, in support of the environmental review of the VEGP application for license renewal (ML072841107).
SNC staff and contractors discussed SAMA RAIs with NRC staff and contractors and gained clarification as to specific line items. SNC agreed to provide the requested information within the 60 day period outlined in the formal RAI request letter. No staff decisions were made during the teleconference.
/RA/
J.P. Leous, Project Manager Projects Branch 1 Division of License Renewal Office of Nuclear Reactor Regulation Docket Nos. 50-424 and 50-425
Enclosures:
- 1. List of Participants
- 2. SAMA RAI List cc: See next page
ML073120119 OFFICE LA:DLR PM:DLR:RPB1 PM:DLR:RPB1 BC:DLR:RPB1 NAME IKing JPLeous DAshley LLund DATE 11/13/07 11/13/07 11/13/07 11/16/07 Letter to Southern Nuclear Operating Co. Inc., From JP Leous Dated, November 16, 2007
SUBJECT:
SUMMARY
OF CONFERENCE CALL WITH SOUTHERN NUCLEAR OPERATING COMPANY, INC., TO DISCUSS THE SEVERE ACCIDENT MITIGATION ALTERNATIVES REQUESTS FOR ADDITIONAL INFORMATION FOR VOGTLE ELECTRIC GENERATING PLANT, UNITS 1 AND 2 (TAC NOS.
MD5905, MD5906)
DISTRIBUTION:
E-Mail P.T. Kuo (RidsNrrDlr)
R. Franovich (RidsNrrDlrRebb)
E. Benner (RidsNrrDlrReba)
L. Lund J. Leous S. Hernandez Bobbie.hurley@earthtech.com D. Ashley B. Singal B. Anderson G. McCoy S. Shaeffer S. Uttal RidsOGCMailRoom DLR/REBB DLR/REBA
TELEPHONE CONFERENCE CALL WITH SOUTHERN NUCLEAR OPERATING COMPANY, INC.
LIST OF PARTICIPANTS October 29, 2007 PARTICIPANTS AFFILIATION Robert Palla U.S. Nuclear Regulatory Commission (NRC)
J.P. Leous NRC Steve Short Pacific Northwest National Laboratory (PNNL)
Bruce Schmitt PNNL Tom Moorer Southern Nuclear Operating Company, Inc (SNC)
Dale Fulton SNC Young Jo SNC Owen Scott SNC Bill Burns SNC Don Vanover ERIN Engineering and Research, Inc.
Al Toblin Tetra Tech Enclosure 1
REQUEST FOR ADDITIONAL INFORMATION REGARDING THE ANALYSIS OF SEVERE ACCIDENT MITIGATION ALTERNATIVES FOR THE VOGTLE ELECTRIC GENERATING PLANT, UNITS 1 AND 2 The Environmental Report (ER) failed to include key information in a number of areas related to the analysis of Severe Accident Mitigation Alternatives (SAMA) for Vogtle Electric Generating Station (VEGP), Units 1 and 2. The following information is considered both necessary in order for the NRC staff to complete its evaluation, and within the scope of Nuclear Energy Institute (NEI) 05-01, Severe Accident Mitigation Alternatives (SAMA) Analysis Guidance Document.
- 1. Provide the following information regarding the development of the VEGP probabilistic risk assessment (PRA) used for the SAMA analysis for VEGP, Units 1 and 2.
- a. Attachment F to the ER does not cite to which unit the internal events core damage frequency (CDF) applies. Provide the internal events CDF for the other unit if different, and a discussion of the reasons for any differences. Discuss the impact on the SAMA analysis and results if the analysis were based on the other unit.
- b. Section F.5.1.6.1 notes that the total internal events CDF has been reduced from 4.90E-05 per year (Individual Plant Evaluation (IPE)) to 1.55E-05 per year (current PRA) due to various improvements and enhancements to the model.
Table 2.1 lists the items updated in each PRA revision, but this table does not identify any plant changes, or include any information regarding the CDF or large early release frequency (LERF) for each revision.
- i. Provide a description of any plant changes (hardware or procedure) reflected within each PRA revision.
ii. Provide the total CDF and LERF estimates for each of the major PRA revisions (e.g., IPE, Rev 0, Rev 1, Rev 2, Rev 3, and VEGPL2UP).
iii. Identify the major reasons for the change in CDF and LERF in each of the major revisions.
iv. Identify any plant changes since the VEGPL2UP model and provide a qualitative assessment of their potential impact on the PRA and the results of the SAMA evaluation.
- c. The only mention of the breakdown of contributors to internal events CDF occurs in Section F.5.1.6.1 in the context of the fire events discussion. Provide a breakdown of the contributions to internal events CDF by initiating event for PRA version VEGPL2UP.
- d. Provide a list and description of the top 30 cutsets from the Level 1 model, and the plant damage states for each of the cutsets.
- e. Describe any credit taken for equipment in the opposite unit and the assumptions concerning this equipment=s availability as a result of conditions at the other unit.
Enclosure 2
- f. Provide additional information concerning the CDF sequences involving reactor coolant pump (RCP) seal loss-of-coolant accidents (LOCAs) due to either support system failure and station blackout (SBO) including the VEGP RCP seal design, associated seal injection and cooling systems, dependencies of these systems on other support systems, related emergency core cooling systems or makeup system dependencies and how the RCP seal failure is modeled in the VEGP PRA.
- g. Table F.2.2 provides Westinghouse Owners Group (WOG) peer review comment resolutions that were incorporated into Revision 3 to the VEGP PRA. Section F.2 indicates that all WOG peer review AB@ findings were addressed in PRA model Revision 3. However, PRA version VEGPL2UP was subsequently developed to support the SAMA analysis.
- i. Identify which version of the VEGP PRA was peer reviewed by the WOG.
ii. Discuss any subsequent internal or external peer reviews that have been performed of PRA version VEGPL2UP. Describe any significant review comments and their potential impact on the results of the SAMA analysis.
- h. Section F.2.2 indicates that the CDF event tree structure was re-constructed to incorporate additional success terms needed to support the refined Level 2 modeling in PRA version VEGPL2UP, and that the base model CDF with success branches accounted for is slightly lower than the base model CDF without success branches accounted for.
- i. Provide examples of the previous and the re-constructed versions of the Level 1 event trees to help illustrate the changes made in PRA version VEGPL2UP. Confirm the PRA version to which the Aprevious Vogtle Level 1 base model@ refers.
ii. Confirm that PRA version VEGPL2UP includes success criteria in the event tree quantification to support the Level 2 analysis. If so, explain why the CDF value of 1.55E-05 per year (based on model without success branches) is used as the base risk in the Section F.6 analyses rather than the CDF value of 1.529E-05 per year (based on model with success branches).
- 2. Provide the following information relative to the Level 2 analysis:
- a. Provide a description of the evolution of the Level 2 model prior to PRA version VEGPL2UP.
- b. Provide an expanded discussion of the changes to the Level 2 model implemented in PRA version VEGPL2UP (which are alluded to in Section F.2.1 and F.2.2.). Include a further description of the assumptions in the revised model that result in a zero frequency of LERF sequences with early containment failure due to severe accident phenomena (LERF-CFE) and small early release frequency sequences.
- c. Level 2 release categories are defined in Section F.2.1, and a representative sequence for each release category is identified in Table F.3.1. Describe the methodology for binning Level 1 sequences into the Level 2 release categories, and the approach used to identify the representative sequence for each release category. Address whether sequence selection was based on the frequencies, consequences, timing, or some other consideration of the various sequences assigned to each release category.
- 3. Provide the following information with regard to the treatment and inclusion of external events in the SAMA analysis:
- a. In Section F.5.1.6.1, Southern Nuclear Corporation (SNC) provides the CDF for the ten largest contributing fire scenarios, and identifies Phase II SAMAs (based on insights from the internal events PRA) that would help reduce the fire risk for each fire area. The top ten fire scenarios constitute less than 45 percent of the total fire PRA CDF. Provide a similar discussion for all fire areas contributing up to 95 percent of the fire CDF, or rationale as to why SAMAs to address these additional fire areas need not be considered.
- b. For each of the dominant fire areas, explain what measures have already been taken to reduce risk. Include in the response specific consideration of improvements to detection systems, enhancements to suppression capabilities, changes that would improve cable separation and drain separation, and monitoring and controlling the quantity of combustible materials in critical process areas. Explain why the fire CDF can not be further reduced in a cost effective manner through implementation of SAMAs specific to fire events.
- c. In Section F.5.1.6.1, a list of PRA topics that prevent the effective comparison of the CDF between the internal events PRA and the fire PRA is provided. These topics appeared to be derived from NEI 05-01, and are provided as general statements rather than specific arguments applicable to the VEGP fire PRA.
State how these assumptions apply to the VEGP fire PRA.
- d. The assumption that risks posed by external and internal events is approximately equal (page F-48) appears to be based on the fire PRA (individual plant examination of external events) only being 21 percent of the original IPE CDF value of 4.90E-05 per year. However, the fire PRA CDF represents over 66 percent of the internal events CDF from the VEGPL2UP model used in the SAMA analysis. Provide further justification that the factor of two multiplier is adequate to account for the additional risk from all external events (e.g., seismic, fire, high winds, etc.).
- 4. Provide the following information concerning the MACCS2 analyses:
- a. The discussion on pages F-17 and F-18 indicates that a factor of 1.84 was applied to evacuation, relocation, decontamination and property condemnation costs to account for cost escalation since the time these values were first specified in the MACCS2 Sample Problem A. Describe how the scaling factor of 1.84 was derived for cost escalation between 1986 and 2006. Also, identify and briefly discuss the key MACCS2 input assumptions or other factors that contribute to the offsite economic cost risk at VEGP (e.g., daily cost for relocated individuals, the costs to relocate an individual, daily cost for evacuated individuals, cost of farm and non-farm decontamination, the value of farm and non-farm wealth, cost of decontamination labor, property depreciation rate, investment rate of return).
- b. Three problems related to use of the SECPOP2000 code have recently been identified, and publicized throughout the industry. These deal with: (1) a formatting error in the regional economic data block text file generated by SECPOP2000 for input to MACCS2 which results in MACCS2 mis-reading the data, (2) an error associated with the formatting of the COUNTY97.DAT economic database file used by SECPOP2000 which results in SECPOP2000 processing incorrect economic and land use data (e.g., missing entries in the ANotes@ column result in data being output for the wrong county), and (3) gaps in the numbered entries in the COUNTY97.DAT economic database file which result in any county beyond county number 955 being handled incorrectly in SECPOP2000. Provide an assessment of the impact of correcting these errors on the VEGP SAMA analysis, including the screening of candidate SAMAs and the final dispositioning of the SAMAs. Provide revised estimates of the maximum averted cost risk (MACR) and the benefits for each SAMA, as appropriate.
- c. The population dose risk (PDR) values reported in the table on page F-23 sum to 1.23 person-rem rather than 1.54 person-rem as shown. Furthermore, the total PDR and offsite economic cost risk (OECR) values presented in this table are not consistent with the values used in the Phase II SAMA analysis (Section F.6).
Specifically, Section F.4.1 indicates that the baseline off-site population dose risk used was 2.04 person-rem per year, not 1.54 person-rem per year as reported in the table. Also, Section F.4.2 indicates the annual off-site economic risk used was $1,412, not $1,725 as reported in the table. Clarify these discrepancies. If appropriate, provide an updated MACR, modified MACR, and baseline evaluation of the Phase II SAMAs.
- d. Describe the method used to project the population within 50-miles of the site for the year 2040, and how the population within the surrounding 28 counties were mapped into the MACCS2 rosettes. Provide the resulting projected population distribution (by sector and radial ring) within the 10-mile radius and the 50-mile radius from VEGP.
- e. The 2040 evacuation speed was based on the 2010 evacuation speed and the ratio of the projected population within the Emergency Planning Zone (EPZ) for the years 2010 and 2040. Identify the year 2010 evacuation speed and the year 2010 and year 2040 EPZ populations used to calculate the year 2040 evacuation speed. Describe how the method used to develop the 2010 EPZ population estimate compares with the method used to project the population within 50-miles of the site for the year 2040.
- f. The MACCS2 analysis uses a reference pressurized water reactor (PWR) core inventory at end-of-cycle calculated using ORIGEN. The ORIGEN calculations were based on a 3-year fuel cycle (12 month reload), 3.3 percent enrichment, and three region burnup of 11,000, 22,000, and 33,000 megawatt days per metric ton of uranium (MWd/MTU). Current VEGP fuel management practices use higher enrichments (up to 4.95 percent) and significantly higher fuel burnup (up to 60,000 MWd/MTU discharge burnup). The use of a reference PWR core (scaled only for power) instead of a plant specific cycle could significantly underestimate the inventory of long-lived radionuclides important to population dose (such as Sr-90, Cs-134 and Cs-137), and thus impact the SAMA evaluation. Also, the fission product scaling was based on 3636 megawatt thermal; however, this does not appear to include the proposed VEGP power uprate of 1.7 percent. Provide an assessment of the impact on population dose and on the SAMA screening and dispositioning if the SAMA analysis were based on the fission product inventory for the highest burnup, higher fuel enrichment and higher power level.
- g. Tables F.3.1 and F.3.2 provide source term information for each release category.
- i. Table F.3.2 shows that the LERF-steam generator tube rupture (SGTR) plume release of CsI occurs over a ~45 hour period, from 2.7 to 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br />, with a calculation duration of 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br />. LATE-SGTR CsI release occurs over only a 4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> period, from 26 to 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />. Describe the phenomenology of CsI release for LERF- SGTR and LATE-SGTR, and the general approach for representing time varying fission product releases as input to the MACCS2 code.
ii. Table F.3.1 shows a CsI release fraction of 3.8E-01 for a calculation duration of 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> for LERF-SGTR (Case 8). Discuss whether the CsI release fraction in Case 8 is limited by the calculation duration and, if so, address the impact on the SAMA results if the calculation duration were extended (e.g., to 120 hours0.00139 days <br />0.0333 hours <br />1.984127e-4 weeks <br />4.566e-5 months <br /> as used in Cases 2a and 3a).
- 5. Provide the following with regard to the SAMA identification and screening process:
- a. Table A-1 in Attachment F provides a list of 266 SAMAs that had been identified by the nuclear industry in previous license renewal submittals. Section F.5.1 indicates that this list was used as an idea source that was reviewed to determine if a plant enhancement had already been conceived that would address VEGP=s needs.
- i. Identify the Phase I SAMAs that were derived from this generic industry list.
ii. RCP seal LOCAs are one of the largest VEGP risk contributors. SNC identified and evaluated several Phase I SAMAs (SAMAs 1, 2, 6, 7, and
- 8) to reduce this risk. Table A-1 identifies 24 SAMAs related to RCP seal LOCAs. Several of these SAMAs involve only procedure changes and so should have implementation costs significantly less than some of the Phase I SAMAs that were evaluated. Provide an evaluation of the costs and benefits of each of the RCP seal LOCA SAMAs in Table A-1 or, alternatively, provide an explanation for why these SAMAs are not applicable at VEGP. Specifically address SAMAs 2, 3, 4, 6, 7, 8, 16, 17, 18, 20, and 21.
iii. SGTR sequences are the dominant contributor to population dose risk and economic cost risk at VEGP. While a number of Phase I SAMAs (SAMAs 2, 4, 10, and 13) were identified and evaluated to reduce the frequency of SGTR sequences, no Phase I SAMAs were specifically identified to reduce the magnitude of releases from SGTR sequences.
Table A-1 SAMAs131, 132, 133, 135, and 136 all involve enhancements to reduce the consequences of an SGTR, of which SAMAs 135 and 136 are procedure changes only. Provide an evaluation of these SAMAs, or indicate if the particular SAMA has already been considered. If the latter, indicate whether the SAMA has been implemented or has been determined to not be cost-beneficial at VEGP.
- b. Section F.5.1.2.2 indicates that SNC reviewed the Phase II SAMAs from Palisades. Palisades SAMA 23, ADirect PCS cooldown on loss of RCP seal cooling,@ which involves a procedure change, was determined to be potentially cost-beneficial as Palisades. Provide an evaluation of the costs and benefits of enhancing RCP seal cooldown procedures at VEGP or, alternatively, provide an explanation for why this SAMA is not applicable at VEGP.
- c. Section F.5.1.2.2 indicates that SNC reviewed the Phase II SAMAs from Farley.
Farley SAMA 166, AProceduralize local manual operation of auxiliary feedwater when control power is lost@ (SAMA 166 in ER Attachment F Table A-1) which involves a procedure change, was determined to be potentially cost-beneficial at Farley. Provide an evaluation of the costs and benefits of implementation of this SAMA at VEGP or, alternatively, provide an explanation for why this SAMA is not applicable at VEGP.
- d. Section F.1 states that the Phase I SAMA analysis utilized the following screening criteria: (1) not applicable to the VEGP design or are of low benefit in PWRs, (2) already been implemented at VEGP or whose benefits have been achieved at VEGP using other means, and (3) estimated costs that exceed the possible MACR. All of the Phase I SAMAs in Table F.5-3 that were screened out (e.g., SAMAs 3, 5, and 8) were done so only based on criteria (3). Clarify the statement in the ER regarding the screening process/criteria.
- 6. Provide the following with regard to the Phase II cost-benefit evaluations:
- a. The description of how SAMA 2 was modeled (page F-55) is not sufficient to understand the reasons for the large reduction in CDF, population dose-risk, and OECR for this SAMA. Provide additional detail including assumptions in the base model for failure probability of both the black start diesel generators and the Wilson combustion turbines during SBO events.
- b. Describe the PRA model changes made to perform the Phase II evaluation of SAMA 5 for the sensitivity analysis.
- c. For a number of the Phase II SAMAs listed in Table F.5-4, the information provided does not sufficiently describe the associated modifications and what is included in the cost estimate. Provide a more detailed description of the modifications and a breakdown of the cost estimate for Phase II SAMAs 1, 6, 7, 9, 12, and 13.
- d. With regard to the Phase II evaluation of SAMA 11:
- i. Section F.6.8 says that the potential benefits from SAMA 11 were bounded by assuming that A90 percent of all Loss of [nuclear service cooling water (NSCW)] scenarios were avoided.@ It also further notes A10 percent likelihood of success is assumed to be representative of a best-case scenario.@ These statements appear to be contradictory.
Provide additional clarification on how SAMA 11 was modeled. Also, provide further justification for the use of the 90 percent and 10 percent assumption and how they impact the SAMA 11 evaluation.
ii. Section F.6.8 further states that the implementation cost of this SAMA at VEGP is closer to the Farley estimate of $580,000 (actually $520,000 per the Farley ER) than the V.C. Summer estimate of $150,000. Provide a more detailed description of the modifications, breakdown of the cost estimate, and description of the difference between the Farley and V.C.
Summer estimates.
iii. Section F.6.8 further states that the benefit of this SAMA is limited to Loss of NSCW scenarios and would not be effective at eliminating seal LOCAs in SBO scenarios since the power to the hydro pump would be unavailable in the SBO scenarios. Provide an evaluation of an enhancement to this SAMA that includes providing backup power to the hydrostatic test pump.
- e. Section F.6.12 provides an estimated implementation cost for SAMA 15 of
$900,000. The Wolf Creek Generating Station (Wolf Creek) ER estimated the cost for identical SAMA 1 to be $800,000. The difference is that Wolf Creek assumed the cost of the dedicated diesel generator to be 33 percent less than the $1.2 million estimate originally developed for the advanced boiling water reactor while the VEGP assumed the cost was only 25 percent less. Provide a justification for this change in assumption that resulted in a higher cost.
- f. ER page 3.1-1 indicates that the current power level for VEGP is 1232 megawatts electric. ER page F-28 indicates that a power level of 1215 MWe was used in calculating the replacement power cost for the Phase II cost-benefit evaluation. Clarify this discrepancy. Furthermore, ER page 3.1-1 indicates that SNC is submitting a request to NRC for a 1.7 percent power uprate in 2007.
Provide justification for the power level used in the Phase II cost-benefit evaluation and an assessment of any changes on the evaluation results.
- 7. Section F.7.1 identifies SAMA 6 and SAMA 16 as potentially cost-beneficial based on an analysis of the uncertainty of the calculated internal events CDF. Both Section F.7.1.3 and Section F.8 further conclude that these SAMAs are unlikely candidates for realistic consideration at VEGP because of optimistic cost estimates or PRA assumptions.
However, the staff does not consider the use of a multiplier of 2.0 to account for uncertainties to be overly conservative since this factor has been reported to be as high as 2.5 for other Westinghouse plants that have submitted license extension applications (e.g., Robinson Steam Electric Plant, Unit No. 2) and as high as 5.0 in NUREG-1560, AIndividual Plant Examination Program: Perspectives on Reactor Safety and Plant Performance.@ Provide additional justification, including engineering/deterministic (versus probabilistic) rationale for why these two SAMAs should not warrant implementation at VEGP. Describe SNC=s plans regarding further evaluation of these two SAMAs.
- 8. For certain SAMAs considered in the ER, there may be lower-cost alternatives that could achieve much of the risk reduction at a lower cost. In this regard, discuss whether any lower-cost alternatives to those Phase II SAMAs considered in the ER, would be viable and potentially cost-beneficial. Evaluate the following SAMAs (found to be potentially cost-beneficial at other plants, and also relevant to the dominant risk contributors at VEGP, or indicate if the particular SAMA has already been considered. If the latter, indicate whether the SAMA has been implemented or has been determined to not be cost-beneficial at VEGP.
- a. Use a portable generator to extend the coping time in loss of alternating current power events (to power selected instrumentation and direct current (DC) power to the turbine-driven auxiliary feedwater pump) (SAMA 167 in ER Attachment F Table A-1).
- b. Provide alternate DC feeds (using a portable generator) to panels supplied only by the DC bus.
- c. Modify emergency procedures to isolate a faulted SG due to a stuck open safety valve (SAMA 135 in ER Attachment F Table A-1). This RAI is related to RAI 5.a.iii.
- d. Provide hardware connections to allow service water to cool network control program seals (SAMA 5 in ER Attachment F Table A-1). This RAI is related to RAI 5.a.ii.
Vogtle Electric Generating Plant, Units 1 and 2 cc:
Mr. Tom E. Tynan Arthur H. Domby, Esquire Vice President - Vogtle Troutman Sanders Vogtle Electric Generating Plant Nations Bank Plaza 7821 River Road 600 Peachtree Street, NE Waynesboro, GA 30830 Suite 5200 Atlanta, GA 30308-2216 Mr. N. J. Stringfellow Manager, Licensing Resident Inspector Southern Nuclear Operating Company, Inc. Vogtle Plant P.O. Box 1295 8805 River Road Birmingham, AL 35201-1295 Waynesboro, GA 30830 Mr. Jeffrey T. Gasser Office of the County Commissioner Executive Vice President Burke County Commission Southern Nuclear Operating Company, Inc. Waynesboro, GA 30830 P.O. Box 1295 Birmingham, AL 35201-1295 Mr. Stanford M. Blanton, Esquire Balch & Bingham LLP Mr. Steven M. Jackson P.O. Box 306 Senior Engineer - Power Supply Birmingham, AL 35201 Municipal Electric Authority of Georgia 1470 Riveredge Parkway, NW Ms. Moanica M. Caston Atlanta, GA 30328-4684 Vice President and General Counsel Southern Nuclear Operating Company, Inc.
Mr. Reece McAlister 40 Inverness Center Parkway Executive Secretary P.O. Box 1295 Georgia Public Service Commission Birmingham, AL 35201-1295 244 Washington Street, SW Atlanta, GA 30334 Mr. Michael A. Macfarlane Southern Nuclear Operating Company, Inc.
Mr. Harold Reheis, Director 40 Inverness Center Parkway Department of Natural Resources P.O. Box 1295 205 Butler Street, SE, Suite 1252 Birmingham, AL 35201-1295 Atlanta, GA 30334 Mr. T. C. Moorer - Project Manager -
Attorney General Environmental Law Department Southern Nuclear Operating Company, Inc.
132 Judicial Building 40 Inverness Center Parkway Atlanta, GA 30334 P.O. Box 1295 Birmingham, AL 35201-1295 Mr. Laurence Bergen Oglethorpe Power Corporation 2100 East Exchange Place P.O. Box 1349 Tucker, GA 30085-1349