ML030980154

Ltr, Upcoming Steam Generator Tube Inservice Inspection (Tac No. MB8134)

ML030980154
Person / Time
Site:	Saint Lucie
Issue date:	04/08/2003
From:	Moroney B NRC/NRR/DLPM/LPD2
To:	Stall J Florida Power & Light Co
Moroney B, NRR/DLPM, 415-3974
References
TAC MB8134
Download: ML030980154 (6)

Text

April 8, 2003 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:

SAINT LUCIE NUCLEAR PLANT, UNIT 2 - UPCOMING STEAM GENERATOR TUBE INSERVICE INSPECTION (TAC NO. MB8134)

Dear Mr. Stall:

Inservice inspections (ISI) of steam generator (SG) tubes play a vital role in assuring that adequate structural integrity of the tubes is maintained. As required by the plant Technical Specifications, reporting requirements range from submitting a special report, within 15 days following completion of each ISI of SG tubes, that identifies the number of tubes plugged and/or repaired; to submitting a special report, within 12 months following completion of the inspection, that provides complete results of the SG tube ISI. The special report containing the complete results shall include the following:

1. Number and extent of tubes inspected,

2. Location and percent of wall-thickness penetration for each indication of an imperfection, and

3. Identification of tubes plugged and/or repaired.

A phone conference has been arranged with members of your staff to discuss the ongoing results of the SG tube inspections to be conducted during the upcoming Saint Lucie, Unit 2 refueling outage. This phone call will occur after the majority of the tubes have been inspected, but before the SG inspection activities have been completed. Attached is a list of discussion points to facilitate this phone conference.

Mr. J. A. Stall April 8, 2003 The staff plans to document a brief summary of the conference call as well as any material that you may have provided to the staff in support of the call.

Sincerely,

/RA/

Brendan T. Moroney, Project Manager, Section 2 Project Directorate II Division of Licensing Project Management Office of Nuclear Reactor Regulation Docket No. 50-389

Enclosure:

List of Discussion Points cc w/encl: See next page

ML030980154 OFFICE PDII-2/PM PDII-2/PM PDII-2/LA EMCB/SC PDII-2/SC NAME EBrown BMoroney BClayton LLund AHowe DATE 3/31/03 3/31/03 3/31/03 4/02/03 04/8/03 Mr. J. A. Stall ST. LUCIE PLANT Florida Power and Light Company cc:

Senior Resident Inspector Mr. R. E. Rose St. Lucie Plant Plant General 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 Mr. Kelly Korth Division of Emergency Preparedness Licensing Manager Department of Community Affairs St. Lucie Nuclear Plant 2740 Centerview Drive 6351 South Ocean Drive Tallahassee, Florida 32399-2100 Jensen Beach, Florida 34957 M. S. Ross, Attorney Mr. William Jefferson Florida Power & Light Company Vice President, Nuclear Operations Support P.O. Box 14000 Florida Power & Light Company Juno Beach, FL 33408-0420 P.O. Box 14000 Juno Beach, FL 33408-0420 Mr. Douglas Anderson County Administrator Mr. Rajiv S. Kundalkar St. Lucie County Vice President - Nuclear Engineering 2300 Virginia Avenue Florida Power & Light Company Fort Pierce, Florida 34982 P.O. Box 14000 Juno Beach, FL 33408-0420 Mr. William A. Passetti, Chief Department of Health Mr. J. Kammel Bureau of Radiation Control Radiological Emergency 2020 Capital Circle, SE, Bin #C21 Planning Administrator Tallahassee, Florida 32399-1741 Department of Public Safety 6000 SE. Tower Drive Mr. Donald E. Jernigan, Site Vice President Stuart, Florida 34997 St. Lucie Nuclear Plant 6351 South Ocean Drive Jensen Beach, Florida 34957

DISCUSSION POINTS STEAM GENERATOR TUBE INSPECTION PREPARED BY THE OFFICE OF NUCLEAR REACTOR REGULATION FLORIDA POWER AND LIGHT COMPANY SAINT LUCIE NUCLEAR PLANT, UNIT 2 DOCKET NO. 50-389 The following discussion points have been prepared to facilitate the phone conference arranged with Florida Power and Light to discuss the results of the steam generator (SG) tube inspections to be conducted during the upcoming Saint Lucie Unit 2 refueling outage. This phone call is scheduled to occur towards the end of the planned SG tube inspection interval, but before the unit exits its refueling outage.

The Nuclear Regulatory Commission (NRC) staff plans to document a brief summary of the conference call as well as any material that may be provided to the NRC staff in support of the call.

1. Discuss whether any primary to secondary leakage existed in this unit prior to shutdown.

2. Discuss the results of secondary side pressure tests.

3. For each SG, provide a general description of areas examined, including the expansion criteria utilized and type of probe used in each area. Also, be prepared to discuss your inspection of the tube within the tubesheet, particularly the portion of the tube below the expansion/transition region.

4. Discuss any exceptions taken to the industry guidelines.

5. Provide a summary of the number of indications identified to-date of each degradation mode and SG tube location (e.g., tube support plate, top-of-tubesheet, etc.). Also provide information, such as voltages, and estimated depths and lengths of the most significant indications.

6. Describe repair/plugging plans for the SG tubes that meet the repair/plugging criteria.

7. Discuss the previous history of SG tube inspection results, including any "look backs" performed. Specifically for significant indications or indications where look backs are used in support of dispositioning (e.g., manufacturing burnish marks).

8. Discuss, in general, new inspection findings (e.g., degradation mode or location of degradation new to this unit).

Enclosure

9. If SGs contain Alloy 600 thermally treated tubing, discuss actions taken (if any) based on Seabrooks recent findings. Refer to NRC Information Notice 2002-21, Supplement 1 (ADAMS Accession Number ML030900517).

10. Discuss the use or reliance on inspection probes (eddy current or ultrasonic) other than bobbin and typical rotating probes, if applicable.

11. Describe in situ pressure test plans and results, if applicable and available, including tube selection criteria.

12. Describe tube pull plans and preliminary results, if applicable and available; include tube selection criteria.

13. Discuss the assessment of tube integrity for the previous operating cycle (i.e., condition monitoring).

14. Discuss the assessment of tube integrity for next operating cycle (i.e., operational assessment).

15. Provide the schedule for SG-related activities during the remainder of the current outage.