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| {{#Wiki_filter:August 3, 2006Mr. J. A. StallSenior Vice President, Nuclear and Chief Nuclear Officer Florida Power and Light Company P.O. Box 14000 Juno Beach, Florida 33408-0420 | | {{#Wiki_filter:August 3, 2006 Mr. J. A. Stall Senior Vice President, Nuclear and Chief Nuclear Officer Florida Power and Light Company P.O. Box 14000 Juno Beach, Florida 33408-0420 |
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| ==SUBJECT:== | | ==SUBJECT:== |
| ST. LUCIE NUCLEAR PLANT, UNIT 2 - | | ST. LUCIE NUCLEAR PLANT, UNIT 2 |
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| ==SUMMARY== | | ==SUMMARY== |
| OF CONFERENCE CALLWITH FLORIDA POWER AND LIGHT COMPANY REGARDING THE 2006 STEAM GENERATOR INSPECTION (TAC NO. MD1084) | | OF CONFERENCE CALL WITH FLORIDA POWER AND LIGHT COMPANY REGARDING THE 2006 STEAM GENERATOR INSPECTION (TAC NO. MD1084) |
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| ==Dear Mr. Stall:== | | ==Dear Mr. Stall:== |
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| On May 5, 2006, the U.S. Nuclear Regulatory Commission (NRC) staff participated in aconference call with Florida Power and Light Company (FPL) representatives regarding the steam generator inspection activities at St. Lucie Unit 2 during the SL2-16 refueling outage. | | On May 5, 2006, the U.S. Nuclear Regulatory Commission (NRC) staff participated in a conference call with Florida Power and Light Company (FPL) representatives regarding the steam generator inspection activities at St. Lucie Unit 2 during the SL2-16 refueling outage. |
| Enclosed is a brief summary of the conference call prepared by the NRC staff. The materialsprovided by FPL in support of the calls are attached to this summary. If you have any questions regarding this material, please contact me at (301) 415-3974.Sincerely,/RA/Brendan T. Moroney, Project ManagerPlant Licensing Branch II-2 Division of Operating Reactor Licensing Office of Nuclear Reactor RegulationDocket No. 50-389 | | Enclosed is a brief summary of the conference call prepared by the NRC staff. The materials provided by FPL in support of the calls are attached to this summary. |
| | If you have any questions regarding this material, please contact me at (301) 415-3974. |
| | Sincerely, |
| | /RA/ |
| | Brendan T. Moroney, Project Manager Plant Licensing Branch II-2 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation Docket No. 50-389 |
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| ==Enclosure:== | | ==Enclosure:== |
| Conference Call Summary cc w/enclosure: See next page | | Conference Call Summary cc w/enclosure: See next page |
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| ML062060255 | | ML062060255 |
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| ==Attachment:== | | ==Attachment:== |
| ML062060285 NRR-106OFFICELPL2-2/PMLPL2-2/LACSGB/BC(A)LPL2-2/BCNAMEBMoroneyBClaytonTBloomer by memo dated LRaghavanDATE 08/ 02/06 08/ 02 /06 06/01/06 08/ 03/06 Mr. J. A. StallST. LUCIE PLANTFlorida Power and Light Company cc:Mr. William E. Webster Vice President, Nuclear Operations Florida Power & Light Company P.O. Box 14000 Juno Beach, FL 33408-0420 Senior Resident Inspector St. Lucie Plant U.S. Nuclear Regulatory Commission P.O. Box 6090 Jensen Beach, Florida 34957 Craig Fugate, Director Division of Emergency Preparedness Department of Community Affairs 2740 Centerview Drive Tallahassee, Florida 32399-2100 M. S. Ross, Managing Attorney Florida Power & Light Company P.O. Box 14000 Juno Beach, FL 33408-0420 | | ML062060285 NRR-106 OFFICE LPL2-2/PM LPL2-2/LA CSGB/BC(A) LPL2-2/BC NAME BMoroney BClayton TBloomer LRaghavan by memo dated DATE 08/ 02/06 08/ 02 /06 06/01/06 08/ 03/06 Mr. J. A. Stall ST. LUCIE PLANT Florida Power and Light Company cc: |
| | Mr. William E. Webster Mr. Christopher R. Costanzo Vice President, Nuclear Operations Plant General Manager Florida Power & Light Company St. Lucie Nuclear Plant P.O. Box 14000 6351 South Ocean Drive Juno Beach, FL 33408-0420 Jensen Beach, Florida 34957 Senior Resident Inspector Mr. Terry Patterson St. Lucie Plant Licensing Manager U.S. Nuclear Regulatory Commission St. Lucie Nuclear Plant P.O. Box 6090 6351 South Ocean Drive Jensen Beach, Florida 34957 Jensen Beach, Florida 34957 Craig Fugate, Director Mark Warner, Vice President Division of Emergency Preparedness Nuclear Operations Support Department of Community Affairs Florida Power & Light Company 2740 Centerview Drive P.O. Box 14000 Tallahassee, Florida 32399-2100 Juno Beach, FL 33408-0420 M. S. Ross, Managing Attorney Mr. Rajiv S. Kundalkar Florida Power & Light Company Vice President - Nuclear Engineering P.O. Box 14000 Florida Power & Light Company Juno Beach, FL 33408-0420 P.O. Box 14000 Juno Beach, FL 33408-0420 Marjan Mashhadi, Senior Attorney Florida Power & Light Company Mr. J. Kammel 801 Pennsylvania Avenue, NW. Radiological Emergency Suite 220 Planning Administrator Washington, DC 20004 Department of Public Safety 6000 Southeast Tower Drive Mr. Douglas Anderson Stuart, Florida 34997 County Administrator St. Lucie County Mr. Bill Parks 2300 Virginia Avenue Operations Manager Fort Pierce, Florida 34982 St. Lucie Nuclear Plant 6351 South Ocean Drive Mr. William A. Passetti, Chief Jensen Beach, Florida 34957-2000 Department of Health Bureau of Radiation Control 2020 Capital Circle, SE, Bin #C21 Tallahassee, Florida 32399-1741 Mr. Gordon L. Johnston Vice President St. Lucie Nuclear Plant 6351 South Ocean Drive Jensen Beach, Florida 34957-2000 |
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| Marjan Mashhadi, Senior Attorney Florida Power & Light Company 801 Pennsylvania Avenue, NW.
| | CONFERENCE CALL |
| Suite 220 Washington, DC 20004Mr. Douglas Anderson County Administrator St. Lucie County 2300 Virginia Avenue Fort Pierce, Florida 34982
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| Mr. William A. Passetti, Chief Department of Health Bureau of Radiation Control 2020 Capital Circle, SE, Bin #C21 Tallahassee, Florida 32399-1741Mr. Gordon L. Johnston Vice President St. Lucie Nuclear Plant 6351 South Ocean Drive Jensen Beach, Florida 34957-2000Mr. Christopher R. CostanzoPlant General Manager St. Lucie Nuclear Plant 6351 South Ocean Drive Jensen Beach, Florida 34957Mr. Terry PattersonLicensing Manager St. Lucie Nuclear Plant 6351 South Ocean Drive Jensen Beach, Florida 34957Mark Warner, Vice PresidentNuclear Operations Support Florida Power & Light Company P.O. Box 14000 Juno Beach, FL 33408-0420Mr. Rajiv S. KundalkarVice President - Nuclear Engineering Florida Power & Light Company P.O. Box 14000 Juno Beach, FL 33408-0420Mr. J. KammelRadiological Emergency Planning Administrator Department of Public Safety 6000 Southeast Tower Drive Stuart, Florida 34997Mr. Bill ParksOperations Manager St. Lucie Nuclear Plant 6351 South Ocean Drive Jensen Beach, Florida 34957-2000 EnclosureCONFERENCE CALL
| | ==SUMMARY== |
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| ==SUMMARY==
| | 2006 STEAM GENERATOR TUBE INSPECTION ACTIVITIES ST. LUCIE NUCLEAR PLANT, UNIT NO. 2 DOCKET NO. 50-389 On May 5, 2006, the Nuclear Regulatory Commission (NRC) staff conducted a conference call with representatives from St. Lucie Nuclear Plant, Unit 2 to discuss their ongoing steam generator (SG) tube inspections during the SL2-16 refueling outage. St. Lucie Unit 2 has two Combustion Engineering Model 3410 SGs with mill annealed Alloy 600 tube material. The tubes have an outside diameter of 0.75 inch and a nominal wall thickness of 0.048 inch. The tubes are explosively expanded for the full depth of the tubesheet and are supported by carbon steel lattice grids (eggcrates). The last inspection of the SG tubes was performed during the SL2-15 refueling outage in January 2005. The SGs are scheduled to be replaced at the next refueling outage in 2007. The licensee (Florida Power and Light Company) met with the NRC staff on April 20, 2006, to discuss the scope of the 2006 SG inspections. That meeting was summarized in an NRC letter dated May 11, 2006 (NRC Agencywide Documents Access and Management System No. ML061250269). |
| 2006 STEAM GENERATOR TUBE INSPECTION ACTIVITIESST. LUCIE NUCLEAR PLANT, UNIT NO. 2DOCKET NO. 50-389On May 5, 2006, the Nuclear Regulatory Commission (NRC) staff conducted a conference callwith representatives from St. Lucie Nuclear Plant, Unit 2 to discuss their ongoing steam generator (SG) tube inspections during the SL2-16 refueling outage. St. Lucie Unit 2 has two Combustion Engineering Model 3410 SGs with m ill annealed Alloy 600 tube material. Thetubes have an outside diameter of 0.75 inch and a nominal wall thickness of 0.048 inch. The tubes are explosively expanded for the full depth of the tubesheet and are supported by carbonsteel lattice grids (eggcrates). The last inspection of the SG tubes was performed during the SL2-15 refueling outage in January 2005. The SGs are scheduled to be replaced at the next refueling outage in 2007. The licensee (Florida Power and Light Company) met with the NRC staff on April 20, 2006, to discuss the scope of the 2006 SG inspections. That meeting wassummarized in an NRC letter dated May 11, 2006 (NRC Agencywide Documents Access andManagement System No. ML061250269).Prior to the May 5, 2006, call, the licensee provided a written response to a set of questionsfrom the NRC staff. The questions are documented in a letter to the licensee datedApril 17, 2006 (ML060960106) and the response is attached to this call summary. | | Prior to the May 5, 2006, call, the licensee provided a written response to a set of questions from the NRC staff. The questions are documented in a letter to the licensee dated April 17, 2006 (ML060960106) and the response is attached to this call summary. |
| Additional clarifying information and information not included in the attached document is summarized below.The licensee reported that primary-to-secondary leakage was below the detection limit ofapproximately 1 gallon per day during t he cycle immediately preceding the outage.No circumferential indications, degradation due to loose parts, or crack indications within wearscars had been detected. No new forms of degradation had been detected during thisinspection.The licensee identified 0.73 inch below the top of the tubesheet as the location of the deepestexpansion transition. One indication had been found in the examined region below the top of the tubesheet. This was an axial indication attributed to primary water stress corrosion cracking in SG-A. The licensee believed this indication was in the fully-expanded region of the tube.Axial outside diameter stress corrosion cracking identified at the top of the tubesheet wasassociated with either the sludge pile region or the expansion transition.The bobbin probe was being used to inspect dings less than 5 volts in the straight tubesections. No cracking had been detected in dings at the time of the call. A new retest technique was being used in this inspection to disposition RCL (retest forclarification) bobbin probe indications, as discussed in the attachment. The rotating probe was being operated at a slower speed this outage (when compared to the previous outage).The number of eddy current flaw indications was significantly lower than expected based onpast inspections at St. Lucie Unit 2. This was the one unexpected result noted by the licensee. | | Additional clarifying information and information not included in the attached document is summarized below. |
| In response to these findings, the licensee reviewed their eddy current data quality to ensure the quality of their 2006 inspection was as good as their previous inspections. With respect to data quality, the licensee concluded it was at least as high as in previous inspections based on the following factors: (1) eddy current analysts reported the data was "clean" (e.g., minimal noise from deposits), (2) the calibration standards were the same ones used in the previous inspection, (3) some of the data analysts had worked on the previous inspection, and (4) similar probes were used during the inspections.The licensee offered the following possible explanations for the reduction in the number ofindications: (1) the latest operating cycle (Cycle 15) was shorter than the previous cycle,(2) the hot-leg temperature was reduced approximately 3 degrees Fahrenheit after about 2 months into Cycle 15, (3) there were fewer significant operational transients in Cycle 15 (three transients) than in other recent cycles (e.g., seven transients during Cycle 14, includinghurricanes that resulted in chemistry excursions), and (4) crack initiation rates may be significantly lower at the locations where cracking has not already been detected.Detailed profiling to determine all in situ testing requirements had not been completed at thetime of the call. The licensee explained that the final list of tubes for in situ testing would include all tubes with indications meeting the predefined screening criteria, as well as additional tubes. The additional tubes would be selected according to the significance of the indications, based on eddy current voltage and apparent dimensions. The licensee also noted that no leakage had been detected in the 29 in situ tests conducted during previous outages, and thatthese tests were performed at indications larger than those being detected during the 2006 outage.Sludge lancing and foreign object search and retrieval were being performed in both SGs andwere complete in SG-B at the time of the call. The licensee's attached written summary includes a list of five foreign objects discovered during prior outages and remaining in the SGs. | | The licensee reported that primary-to-secondary leakage was below the detection limit of approximately 1 gallon per day during the cycle immediately preceding the outage. |
| In response to a question from the staff, the licensee stated that the oldest of these objectsdates back to Cycle 2. For these parts, the licensee inspects and evaluates the need for plugging and stabilizing the surrounding tubes.With respect to the attached Figure 1, the data plotted in the graph is for outside diameter flawsdetected at the eggcrate supports, and "KSU" and "KSL" are the upper and lower Kolmogorov-Smirnov limits, respectively. The licensee indicated that there is no statistical difference between the Cycle 14 and Cycle 15 data sets. With respect to Figures 2 and 3, "OPCON-CY 15" refers to the SG tube integrity projections made following the previous SG tube inspections.At the end of the call, the licensee was asked to inform the staff if they did not install sleeves, orif they found other unexpected results such as new degradation mechanisms or leakage or burst during an in situ pressure test. The licensee subsequently informed the staff that no sleeves were installed.}} | | No circumferential indications, degradation due to loose parts, or crack indications within wear scars had been detected. No new forms of degradation had been detected during this inspection. |
| | The licensee identified 0.73 inch below the top of the tubesheet as the location of the deepest expansion transition. One indication had been found in the examined region below the top of the tubesheet. This was an axial indication attributed to primary water stress corrosion cracking in SG-A. The licensee believed this indication was in the fully-expanded region of the tube. |
| | Axial outside diameter stress corrosion cracking identified at the top of the tubesheet was associated with either the sludge pile region or the expansion transition. |
| | The bobbin probe was being used to inspect dings less than 5 volts in the straight tube sections. No cracking had been detected in dings at the time of the call. |
| | Enclosure |
| | |
| | A new retest technique was being used in this inspection to disposition RCL (retest for clarification) bobbin probe indications, as discussed in the attachment. The rotating probe was being operated at a slower speed this outage (when compared to the previous outage). |
| | The number of eddy current flaw indications was significantly lower than expected based on past inspections at St. Lucie Unit 2. This was the one unexpected result noted by the licensee. |
| | In response to these findings, the licensee reviewed their eddy current data quality to ensure the quality of their 2006 inspection was as good as their previous inspections. With respect to data quality, the licensee concluded it was at least as high as in previous inspections based on the following factors: (1) eddy current analysts reported the data was clean (e.g., minimal noise from deposits), (2) the calibration standards were the same ones used in the previous inspection, (3) some of the data analysts had worked on the previous inspection, and (4) similar probes were used during the inspections. |
| | The licensee offered the following possible explanations for the reduction in the number of indications: (1) the latest operating cycle (Cycle 15) was shorter than the previous cycle, (2) the hot-leg temperature was reduced approximately 3 degrees Fahrenheit after about 2 months into Cycle 15, (3) there were fewer significant operational transients in Cycle 15 (three transients) than in other recent cycles (e.g., seven transients during Cycle 14, including hurricanes that resulted in chemistry excursions), and (4) crack initiation rates may be significantly lower at the locations where cracking has not already been detected. |
| | Detailed profiling to determine all in situ testing requirements had not been completed at the time of the call. The licensee explained that the final list of tubes for in situ testing would include all tubes with indications meeting the predefined screening criteria, as well as additional tubes. The additional tubes would be selected according to the significance of the indications, based on eddy current voltage and apparent dimensions. The licensee also noted that no leakage had been detected in the 29 in situ tests conducted during previous outages, and that these tests were performed at indications larger than those being detected during the 2006 outage. |
| | Sludge lancing and foreign object search and retrieval were being performed in both SGs and were complete in SG-B at the time of the call. The licensees attached written summary includes a list of five foreign objects discovered during prior outages and remaining in the SGs. |
| | In response to a question from the staff, the licensee stated that the oldest of these objects dates back to Cycle 2. For these parts, the licensee inspects and evaluates the need for plugging and stabilizing the surrounding tubes. |
| | With respect to the attached Figure 1, the data plotted in the graph is for outside diameter flaws detected at the eggcrate supports, and KSU and KSL are the upper and lower Kolmogorov-Smirnov limits, respectively. The licensee indicated that there is no statistical difference between the Cycle 14 and Cycle 15 data sets. With respect to Figures 2 and 3, OPCON-CY 15 refers to the SG tube integrity projections made following the previous SG tube inspections. |
| | At the end of the call, the licensee was asked to inform the staff if they did not install sleeves, or if they found other unexpected results such as new degradation mechanisms or leakage or burst during an in situ pressure test. The licensee subsequently informed the staff that no sleeves were installed.}} |
Letter Sequence Other |
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MONTHYEARML0609602052006-04-0606 April 2006
Meeting Notice, Florida Power & Light, St. Lucie Unit 2, Steam Generator Tube Inspection During Refueling
Project stage: Request
ML0609601062006-04-17017 April 2006
Upcoming Steam Generator Tube Inservice Inspection
Project stage: Other
ML0612804882006-04-20020 April 2006
Meeting Summary Handouts for Public Meeting with Florida Power and Light St Lucie, Unit 2 Steam Generator Tube Inspection for the Cycle 16 Refueling Outage
Project stage: Meeting
ML0612502602006-05-11011 May 2006
Summary of Public Meeting with Florida Power and Light St Lucie, Unit 2 Steam Generator Tube Inspection for the Cycle 16 Refueling Outage
Project stage: Meeting
ML0620602552006-08-0303 August 2006
Letter SG Inspection Conference Call
Project stage: Other
ML0620602852006-08-0303 August 2006
Letter Summary of SG Inspection Conference Call
Project stage: Other
2006-04-06
[Table View] |
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Category:Letter
MONTHYEARIR 05000335/20240032024-11-0707 November 2024
Integrated Inspection Report 05000335/2024003 and 05000389/2024003
ML24291A2862024-11-0101 November 2024
– Relief Request: Proposed Alternative in Accordance with 10 CFR 50.55a(Z)(1), Extension of Inspection Interval for Reactor Pressure Vessel Welds from 10 to 20 Years
L-2024-176, Annual 10 CFR 140.21 Licensee Guarantees of Payment of Deferred Premiums2024-10-30030 October 2024
Annual 10 CFR 140.21 Licensee Guarantees of Payment of Deferred Premiums
L-2024-167, Correction to St. Lucie L-2024-132, 2024 Population Update Analysis2024-10-22022 October 2024
Correction to St. Lucie L-2024-132, 2024 Population Update Analysis
IR 05000335/20250102024-10-21021 October 2024
Notification of St. Lucie Plant Units 1 & 2 Comprehensive Engineering Team Inspection - U.S. Nuclear Regulatory Commission Inspection Report 05000335/2025010 and 05000389/2025010
ML24227A9702024-10-18018 October 2024
Letter to Kenneth Mack Dir, License and Reg Compliance, NextEra Energy, Inc Response to Request Re Engagement Re Sub License Renewal Environmental Review - St Lucie Nuclear Plant 1 and 2
L-2024-085, Refueling Outage SL1-32 Low Pressure Turbine Rotor Inspection Results2024-10-15015 October 2024
Refueling Outage SL1-32 Low Pressure Turbine Rotor Inspection Results
L-2024-169, Supplement to License Amendment Request to Adopt Common Emergency Plan with Site- Specific Annexes2024-10-15015 October 2024
Supplement to License Amendment Request to Adopt Common Emergency Plan with Site- Specific Annexes
L-2024-165, Report of 10 CFR 50.59 Plant Changes, Tests and Experiments Made2024-10-14014 October 2024
Report of 10 CFR 50.59 Plant Changes, Tests and Experiments Made
L-2024-118, Fleet License Amendment Request to Relocate Staff Qualifications from Technical Specifications to the Quality Assurance Topical Report (FPL-1)2024-10-0808 October 2024
Fleet License Amendment Request to Relocate Staff Qualifications from Technical Specifications to the Quality Assurance Topical Report (FPL-1)
ML24255A3092024-09-30030 September 2024
SLRA - Revised SE Letter
L-2024-155, Subsequent License Renewal Application, Third Annual Update2024-09-27027 September 2024
Subsequent License Renewal Application, Third Annual Update
L-2024-158, Supplemental Information to License Amendment Request to Adopt Common Emergency Plan with Site-Specific Annexes2024-09-25025 September 2024
Supplemental Information to License Amendment Request to Adopt Common Emergency Plan with Site-Specific Annexes
05000335/LER-2024-001, Unplanned Reactor Scram2024-09-25025 September 2024
Unplanned Reactor Scram
IR 05000335/20240112024-09-18018 September 2024
Biennial Problem Identification and Resolution Inspection Report 05000335/2024011 and 05000389/2024011
L-2024-136, Supplement to License Amendment Request to Adopt Common Emergency Plan with Site-Specific Annexes2024-09-16016 September 2024
Supplement to License Amendment Request to Adopt Common Emergency Plan with Site-Specific Annexes
L-2024-138, License Amendment Request L-2024-138, Fuel Methodology Changes in Support of St. Lucie, Unit 2 Transition to 24-Month Fuel Cycles2024-09-11011 September 2024
License Amendment Request L-2024-138, Fuel Methodology Changes in Support of St. Lucie, Unit 2 Transition to 24-Month Fuel Cycles
L-2024-148, Submittal of Offsite Dose Calculation Manual (Odcm), Revision 552024-09-0909 September 2024
Submittal of Offsite Dose Calculation Manual (Odcm), Revision 55
ML24228A2962024-09-0606 September 2024
NRC to NMFS, Designation of FPL as the Non-Federal Representative for St. Lucie
IR 05000335/20240052024-08-22022 August 2024
Updated Inspection Plan for St. Lucie, Units 1 & 2 - Report 05000335/2024005 and 05000389/2024005
L-2024-133, Snubber Program Plan Submittal2024-08-14014 August 2024
Snubber Program Plan Submittal
L-2024-140, Cycle 28 Core Operating Limits Report2024-08-14014 August 2024
Cycle 28 Core Operating Limits Report
L-2024-132, 2024 Population Update Analysis2024-08-13013 August 2024
2024 Population Update Analysis
IR 05000335/20240022024-08-13013 August 2024
Integrated Inspection Report 05000335-2024002 and 05000389-2024002
L-2024-129, Relief Request (RR) 14. Limited Coverage Exams Due to Impractical Inservice Inspection Requirements - Fourth Ten-Year Inservice Inspection Program Interval2024-08-0707 August 2024
Relief Request (RR) 14. Limited Coverage Exams Due to Impractical Inservice Inspection Requirements - Fourth Ten-Year Inservice Inspection Program Interval
05000389/LER-2024-003, Unplanned Reactor Scram2024-08-0505 August 2024
Unplanned Reactor Scram
ML24163A0012024-08-0505 August 2024
LTR-24-0119-1-1 Response to Nh Letter Regarding Review of NextEras Emergency Preparedness Amendment Review
L-2024-121, Subsequent License Renewal Commitment 30 Revision2024-07-30030 July 2024
Subsequent License Renewal Commitment 30 Revision
L-2024-123, Submittal of In-Service Inspection Program Owners Activity Report (OAR-1)2024-07-29029 July 2024
Submittal of In-Service Inspection Program Owners Activity Report (OAR-1)
L-2024-125, Notice of Intent to Provide Supplemental Information to License Amendment Request to Adopt Common Emergency Plan with Site-Specific Annexes2024-07-24024 July 2024
Notice of Intent to Provide Supplemental Information to License Amendment Request to Adopt Common Emergency Plan with Site-Specific Annexes
ML24184B2822024-07-16016 July 2024
– Request to Use a Later Code Edition and Addenda of the American Society of Mechanical Engineers Boiler and Pressure Vessel Code, Section XI
ML24193A2432024-07-12012 July 2024
– Interim Audit Summary Report in Support of Review of License Amendment Requests Regarding Fleet Emergency Plan
05000389/LER-2024-002-01, Safety Injection Tank Vent Through Wall Leakage2024-07-11011 July 2024
Safety Injection Tank Vent Through Wall Leakage
L-2024-110, Environmental Protection Plan Report, Unusual or Important Environmental Event - Manatee in Intake2024-07-10010 July 2024
Environmental Protection Plan Report, Unusual or Important Environmental Event - Manatee in Intake
L-2024-114, Quality Assurance Topical Report (FPL-1 Revision 31 Annual Submittal2024-07-10010 July 2024
Quality Assurance Topical Report (FPL-1 Revision 31 Annual Submittal
L-2024-109, Schedule for Subsequent License Renewal Environmental Review2024-07-0303 July 2024
Schedule for Subsequent License Renewal Environmental Review
ML24172A1562024-06-27027 June 2024
Relief Request - PSL2-I5-RR-01 Proposed Alternative to Amse Code XI Code Examination Requirements - System Leakage Test of Reactor Pressure Vessel Bottom Head and Class 1 and 2 Piping in Covered Trenches
L-2024-104, Response to Request for Additional Information, St. Luce Relief Request (RR) 7, Proposed Alternative in Accordance with 10 CFR 50.55a(z)(1 Extension of Inspection Interval for Reactor Pressure Vessel Welds from 102024-06-26026 June 2024
Response to Request for Additional Information, St. Luce Relief Request (RR) 7, Proposed Alternative in Accordance with 10 CFR 50.55a(z)(1 Extension of Inspection Interval for Reactor Pressure Vessel Welds from 10
L-2024-097, Technical Specification Special Report2024-06-20020 June 2024
Technical Specification Special Report
L-2024-102, Official Service List Update2024-06-19019 June 2024
Official Service List Update
ML24149A2862024-06-12012 June 2024
NextEra Fleet - Proposed Alternative Frr 23-01 to Use ASME Code Case N-752-1, Risk-Informed Categorization and Treatment for Repair/Replacement Activities in Class 2 and 3 Systems Section X1, Division 1 (EPID L-2023-LLR-0009) - Letter
L-2024-090, Revised Steam Generator Tube Inspection Reports2024-06-0404 June 2024
Revised Steam Generator Tube Inspection Reports
IR 05000335/20244012024-06-0303 June 2024
Security Baseline Inspection Report 05000335/2024401 and 05000389/2024401
ML24135A0642024-05-17017 May 2024
Correction Letter - Amendment Nos. 253 and 208 Regarding Conversion to Improved Standard Technical Specifications
L-2024-075, Notification of Improved Standard Technical Specifications (ITS) Implementation2024-05-13013 May 2024
Notification of Improved Standard Technical Specifications (ITS) Implementation
IR 05000335/20240012024-05-10010 May 2024
Integrated Inspection Report 05000335/2024001 and 05000389/2024001
ML24127A0632024-05-0606 May 2024
Supplemental Information to License Amendment Request to Adopt Common Emergency Plan with Site-Specific Annexes
L-2024-053, License Amendment Request L-2024-053, Updated Spent Fuel Pool Criticality Analysis2024-04-30030 April 2024
License Amendment Request L-2024-053, Updated Spent Fuel Pool Criticality Analysis
L-2024-070, Cycle 32 Core Operating Limits Report2024-04-29029 April 2024
Cycle 32 Core Operating Limits Report
L-2024-071, Cycle 27 Core Operating Limits Report2024-04-29029 April 2024
Cycle 27 Core Operating Limits Report
2024-09-09
[Table view]
Category:Meeting Summary
MONTHYEARML24185A1262024-07-10010 July 2024
Summary of Meeting with Florida Power and Light on License Amendment Requests Regarding the Spent Fuel Criticality Analysis in Support of Planned Transition to 24-Month Fuel Cycles for St. Lucie, Unit 2
ML24128A2102024-05-0707 May 2024
Public Meeting Summary - 2023 Annual Assessment Meeting Regarding Saint Lucie
ML23166A0042023-06-15015 June 2023
Summary of Meeting Concerning 2023 Annual Assessment of the Saint Lucie and the Turkey Point Nuclear Plants
ML23107A2312023-04-18018 April 2023
Summary Meeting with Florida Power and Light/Nextera on Improved Technical Specification Conversion License Amendment Requests
ML23097A1642023-04-17017 April 2023
Summary of March 23, 2023, Meeting with Florida Power and Light on St. Lucie and Turkey Point Improved Technical Specifications Conversion License Amendment Requests
ML23069A0282023-03-15015 March 2023
Summary of January 31, 2023, Meeting with Florida Power and Light on St. Lucie and Turkey Point Improved Technical Specifications Conversion License Amendment Requests
ML23066A0872023-03-15015 March 2023
Summary of Meeting with Florida Power and Light on St. Lucie and Turkey Point Improved Technical Specifications Conversion License Amendment Requests
ML23044A4172023-03-0606 March 2023
Summary of January 17, 2023, Meeting with Florida Power and Light on St. Lucie and Turkey Point Improved Technical Specifications Conversion License Amendment Requests
ML22357A0742023-01-19019 January 2023
Summary of December 1, 2022, Meeting with Florida Power and Light on St. Lucie and Turkey Point Improved Technical Specification Conversion License Amendment Requests
ML22350A7082023-01-17017 January 2023
Summary of November 21, 2022, Presubmittal Meeting with Florida Power and Light on St. Lucie License Amendment Request to Adopt 10 CFR 50.69, Risk-Informed Categorization and Treatment of Structures, Systems, and Components
ML22327A2402022-12-0808 December 2022
Summary of October 27, 2022, Meeting with Florida Power and Light on St. Lucie and Turkey Point Improved Technical Specification Conversion License Amendment Requests
ML22263A0122022-09-27027 September 2022
Summary of August 29, 2022, Meeting with Florida Power and Light on St. Lucie and Turkey Point Improved Technical Specification Conversion License Amendment Requests (EPID Nos. L-2021-LLI-0000 and L 2021 Lli 0002)
ML22144A0022022-09-14014 September 2022
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2024-07-10
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Text
August 3, 2006 Mr. J. A. Stall Senior Vice President, Nuclear and Chief Nuclear Officer Florida Power and Light Company P.O. Box 14000 Juno Beach, Florida 33408-0420
SUBJECT:
ST. LUCIE NUCLEAR PLANT, UNIT 2
SUMMARY
OF CONFERENCE CALL WITH FLORIDA POWER AND LIGHT COMPANY REGARDING THE 2006 STEAM GENERATOR INSPECTION (TAC NO. MD1084)
Dear Mr. Stall:
On May 5, 2006, the U.S. Nuclear Regulatory Commission (NRC) staff participated in a conference call with Florida Power and Light Company (FPL) representatives regarding the steam generator inspection activities at St. Lucie Unit 2 during the SL2-16 refueling outage.
Enclosed is a brief summary of the conference call prepared by the NRC staff. The materials provided by FPL in support of the calls are attached to this summary.
If you have any questions regarding this material, please contact me at (301) 415-3974.
Sincerely,
/RA/
Brendan T. Moroney, Project Manager Plant Licensing Branch II-2 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation Docket No. 50-389
Enclosure:
Conference Call Summary cc w/enclosure: See next page
ML062060255
Attachment:
ML062060285 NRR-106 OFFICE LPL2-2/PM LPL2-2/LA CSGB/BC(A) LPL2-2/BC NAME BMoroney BClayton TBloomer LRaghavan by memo dated DATE 08/ 02/06 08/ 02 /06 06/01/06 08/ 03/06 Mr. J. A. Stall ST. LUCIE PLANT Florida Power and Light Company cc:
Mr. William E. Webster Mr. Christopher R. Costanzo Vice President, Nuclear Operations Plant General Manager Florida Power & Light Company St. Lucie Nuclear Plant P.O. Box 14000 6351 South Ocean Drive Juno Beach, FL 33408-0420 Jensen Beach, Florida 34957 Senior Resident Inspector Mr. Terry Patterson St. Lucie Plant Licensing Manager U.S. Nuclear Regulatory Commission St. Lucie Nuclear Plant P.O. Box 6090 6351 South Ocean Drive Jensen Beach, Florida 34957 Jensen Beach, Florida 34957 Craig Fugate, Director Mark Warner, Vice President Division of Emergency Preparedness Nuclear Operations Support Department of Community Affairs Florida Power & Light Company 2740 Centerview Drive P.O. Box 14000 Tallahassee, Florida 32399-2100 Juno Beach, FL 33408-0420 M. S. Ross, Managing Attorney Mr. Rajiv S. Kundalkar Florida Power & Light Company Vice President - Nuclear Engineering P.O. Box 14000 Florida Power & Light Company Juno Beach, FL 33408-0420 P.O. Box 14000 Juno Beach, FL 33408-0420 Marjan Mashhadi, Senior Attorney Florida Power & Light Company Mr. J. Kammel 801 Pennsylvania Avenue, NW. Radiological Emergency Suite 220 Planning Administrator Washington, DC 20004 Department of Public Safety 6000 Southeast Tower Drive Mr. Douglas Anderson Stuart, Florida 34997 County Administrator St. Lucie County Mr. Bill Parks 2300 Virginia Avenue Operations Manager Fort Pierce, Florida 34982 St. Lucie Nuclear Plant 6351 South Ocean Drive Mr. William A. Passetti, Chief Jensen Beach, Florida 34957-2000 Department of Health Bureau of Radiation Control 2020 Capital Circle, SE, Bin #C21 Tallahassee, Florida 32399-1741 Mr. Gordon L. Johnston Vice President St. Lucie Nuclear Plant 6351 South Ocean Drive Jensen Beach, Florida 34957-2000
CONFERENCE CALL
SUMMARY
2006 STEAM GENERATOR TUBE INSPECTION ACTIVITIES ST. LUCIE NUCLEAR PLANT, UNIT NO. 2 DOCKET NO. 50-389 On May 5, 2006, the Nuclear Regulatory Commission (NRC) staff conducted a conference call with representatives from St. Lucie Nuclear Plant, Unit 2 to discuss their ongoing steam generator (SG) tube inspections during the SL2-16 refueling outage. St. Lucie Unit 2 has two Combustion Engineering Model 3410 SGs with mill annealed Alloy 600 tube material. The tubes have an outside diameter of 0.75 inch and a nominal wall thickness of 0.048 inch. The tubes are explosively expanded for the full depth of the tubesheet and are supported by carbon steel lattice grids (eggcrates). The last inspection of the SG tubes was performed during the SL2-15 refueling outage in January 2005. The SGs are scheduled to be replaced at the next refueling outage in 2007. The licensee (Florida Power and Light Company) met with the NRC staff on April 20, 2006, to discuss the scope of the 2006 SG inspections. That meeting was summarized in an NRC letter dated May 11, 2006 (NRC Agencywide Documents Access and Management System No. ML061250269).
Prior to the May 5, 2006, call, the licensee provided a written response to a set of questions from the NRC staff. The questions are documented in a letter to the licensee dated April 17, 2006 (ML060960106) and the response is attached to this call summary.
Additional clarifying information and information not included in the attached document is summarized below.
The licensee reported that primary-to-secondary leakage was below the detection limit of approximately 1 gallon per day during the cycle immediately preceding the outage.
No circumferential indications, degradation due to loose parts, or crack indications within wear scars had been detected. No new forms of degradation had been detected during this inspection.
The licensee identified 0.73 inch below the top of the tubesheet as the location of the deepest expansion transition. One indication had been found in the examined region below the top of the tubesheet. This was an axial indication attributed to primary water stress corrosion cracking in SG-A. The licensee believed this indication was in the fully-expanded region of the tube.
Axial outside diameter stress corrosion cracking identified at the top of the tubesheet was associated with either the sludge pile region or the expansion transition.
The bobbin probe was being used to inspect dings less than 5 volts in the straight tube sections. No cracking had been detected in dings at the time of the call.
Enclosure
A new retest technique was being used in this inspection to disposition RCL (retest for clarification) bobbin probe indications, as discussed in the attachment. The rotating probe was being operated at a slower speed this outage (when compared to the previous outage).
The number of eddy current flaw indications was significantly lower than expected based on past inspections at St. Lucie Unit 2. This was the one unexpected result noted by the licensee.
In response to these findings, the licensee reviewed their eddy current data quality to ensure the quality of their 2006 inspection was as good as their previous inspections. With respect to data quality, the licensee concluded it was at least as high as in previous inspections based on the following factors: (1) eddy current analysts reported the data was clean (e.g., minimal noise from deposits), (2) the calibration standards were the same ones used in the previous inspection, (3) some of the data analysts had worked on the previous inspection, and (4) similar probes were used during the inspections.
The licensee offered the following possible explanations for the reduction in the number of indications: (1) the latest operating cycle (Cycle 15) was shorter than the previous cycle, (2) the hot-leg temperature was reduced approximately 3 degrees Fahrenheit after about 2 months into Cycle 15, (3) there were fewer significant operational transients in Cycle 15 (three transients) than in other recent cycles (e.g., seven transients during Cycle 14, including hurricanes that resulted in chemistry excursions), and (4) crack initiation rates may be significantly lower at the locations where cracking has not already been detected.
Detailed profiling to determine all in situ testing requirements had not been completed at the time of the call. The licensee explained that the final list of tubes for in situ testing would include all tubes with indications meeting the predefined screening criteria, as well as additional tubes. The additional tubes would be selected according to the significance of the indications, based on eddy current voltage and apparent dimensions. The licensee also noted that no leakage had been detected in the 29 in situ tests conducted during previous outages, and that these tests were performed at indications larger than those being detected during the 2006 outage.
Sludge lancing and foreign object search and retrieval were being performed in both SGs and were complete in SG-B at the time of the call. The licensees attached written summary includes a list of five foreign objects discovered during prior outages and remaining in the SGs.
In response to a question from the staff, the licensee stated that the oldest of these objects dates back to Cycle 2. For these parts, the licensee inspects and evaluates the need for plugging and stabilizing the surrounding tubes.
With respect to the attached Figure 1, the data plotted in the graph is for outside diameter flaws detected at the eggcrate supports, and KSU and KSL are the upper and lower Kolmogorov-Smirnov limits, respectively. The licensee indicated that there is no statistical difference between the Cycle 14 and Cycle 15 data sets. With respect to Figures 2 and 3, OPCON-CY 15 refers to the SG tube integrity projections made following the previous SG tube inspections.
At the end of the call, the licensee was asked to inform the staff if they did not install sleeves, or if they found other unexpected results such as new degradation mechanisms or leakage or burst during an in situ pressure test. The licensee subsequently informed the staff that no sleeves were installed.
