ML031060249
| ML031060249 | |
| Person / Time | |
|---|---|
| Site: | San Onofre  |
| Issue date: | 04/14/2003 |
| From: | Scherer A Southern California Edison Co |
| To: | Document Control Desk, Office of Nuclear Reactor Regulation |
| References | |
| Download: ML031060249 (9) | |
Text
[KiV SOUTHERN CALIFORNIA EDDISONb An EDISON P%
TERNATIO NAL Company A. Edward Scherer Manager of Nuclear Regulatory Affairs April 14, 2003 U. S. Nuclear Regulatory Commission Attention: Document Control Desk Washington, DC 20555
Subject:
Docket Nos. 50-361, and 50-362 Steam Generator Tubesheet Inspections San Onofre Nuclear Generating Station Units 2 and 3
Reference:
Letter from the Nuclear Energy Institute to R. J. Barrett, NRC dated February 4, 2003,
Subject:
"Steam Generator Tubesheet Inspection Information"
Dear Sir or Madam:
The Referenced letter responded to a Nuclear Regulatory Commission (NRC ) request for Nuclear Energy Institute (NEI) to coordinate utility responses to steam generator questions at several pressurized water reactors. As a result, NEI developed a template for utilities to use in responding to the NRC request.
Enclosures 1 and 2 to this letter provide the completed templates for San Onofre Unit 2 and Unit 3 respectively.
Please contact Mr. J. L. Rainsberry at (949) 368-7420 if you have any questions or require additional information regarding these responses.
Sincerely, Enclosures cc:
E. W. Merschoff, Regional Administrator, NRC Region IV B. M. Pham, NRC Project Manager, San Onofre Units 2, and 3 C. C. Osterholtz, NRC Senior Resident Inspector, San Onofre Units 2 & 3 PO Box 128 San Clemente, CA 92674-0128 949-368-7501 Fax 949-368-7575 J
ENCLOSURE 1 San Onofre Unit 2 Steam Generator Tubesheet Inspection Information
TUBESHEET INSPECTION PRACTICES San Onofre Unit 2 Item Plant Information Plant Name:
San Onofre Unit 2 Thot assumed 593-6200F (Note 1)
Thot example 5961F (Actual, 3/24/2003)
Normal Steady State Full Power DP, assumed 1465 psi Normal Steady State Full Power DP, example 1464 psi (Actual, 3/24/2003)
Model of Steam Generator:
Combustion Engineering 3410 MWt Tube Material:
Nickel Alloy 600 HTMA (Ni-Cr-Fe-SB-163)
Tube Diameter:
.750 inches Tube Wall Thickness:
0 048' nom Expansion Process and Extent CE 'Explansion' Explosive, Full Depth Tubesheet Thickness 23" Susceptible to degradation below expansion transition region:
Yes If no, provide basis for non-susceptibility determination n/a Historical Inspection Practices and Results Most recent outage:
Date of Outage June 2002 Cycle #
Beginning of Cycle 12 Inspection technique used Bobbin coil I Rotating Coil Technology (RCT)
Extent of inspections (be specific on landmarks used to determine All tubes; Hot leg, Bobbin coil full depth / RCT partial depth, 5 inches inspection extent) below the Top of tubesheet Primary Water Stress Corrosion Cracking (PWSCC); Hot leg, Results (degradation mechanisms identified and orientation)11Crufenil35Aal(oe) 1 1 Circumferential; 35 Axial (Note 3)
Bases for inspection technique and inspection extent Bobbin = Tech Spec RCT = analytical Technical Document reference (Generic or Plant Specific?)
WCAP 15894 (Note 2a-2c); Plant Specific If generic, provide statement that plant conditions and design are n/a bounded by Technical Document inputs and assumptions__
Previous outages:
Inspection techniques used Bobbin, RCT Cycle 7 and Later Extent of inspections (be specific on landmarks used to determine Note 4a & 4b inspection extent)
Results (degradation mechanisms and orientation)
PWSCC; Hot leg; 28 Circumferential; 95 Axial ( Note 5)
Bases for inspection technique and inspection extent Bobbin = Tech Spec: RCT = analytical (Unit 2 C1I and later)
Planned Inspection for Next Outage Anticipated date of outage 1 st Quarter 2004 Techniques to be used Bobbin coil I RCT Extent of inspections (be specific on landmarks used to determine All tubes; Hot leg; Bobbin coil full depth I RCT partial depth, 7 inches inspection extent) below the Bottom of the Expansion Transition Bases for inspection technique and inspection extent Bobbin = Tech Spec RCT = analytical
Notes:
1 By design, the SONGS NSSS controlling temperature parameter is cold leg temperature.
2 WCAP-1 5894 Refers to:
2a WCAP 15894-P Revision 0; "NDE Inspection Strategy For the tubesheet Region in SONGS Units 2 and 3;" Dated May 2002; Westinghouse Proprietary Class 2 2b WCAP 15894-NP Revision 0; "NDE Inspection Strategy For the tubesheet Region in SONGS Units 2 and 3;" Dated May 2002; Non Proprietary Version 2c "Westinghouse Report WCAP 15984-P ERRATA;"
Transmitted as -- Westinghouse Letter LTR-SGDA-02-174 2d WCAP 15894-P Supplement 1,Revision 0; "NDE Supplement to Inspection Strategy For the tubesheet Region in SONGS Units 2 and 3;" Dated November 2002; Westinghouse Proprietary Class 2 2e WCAP 15894-NP Supplement 1,Revision 0; "NDE Supplement to Inspection Strategy For the tubesheet Region in SONGS Units 2 and 3;" Dated November 2002; Non Proprietary 3
As reported in 15 day letter in Tables and Appendices. The table summarizes the number of tubes repaired and active degradation mechanisms found. Each tube is only counted once in this listing, although it may also have an eddy current indication of a type below the point in the listing where it appears. The appendices provide the complete results of the steam generator tubing inspection. For Unit 2, Table 3 lists 10 tubes with circumferential indications within the tubesheet. By examination the appendices indicate an additional tube that contains a circumferential indication. This additional tube contained another pluggable indication.
Notes (con't.)
4a Prior to 1993 - No rotating coil examinations; Cycle 7 and later inspections were Rotating Coil Technology (RCT) tested down to TTS-2" then to TTS-3". For the Cycle 11 and Unit 2 Cycle 12 outages (2000-2002) RCT tested down to TTS-5'.
4b The landmarks to determine the inspection extent are: 1)
Prior to Unit 3 cycle 12 (Jan. 2003) Nominal top-of-tubesheet. 2) Unit 3 Cycle 12 and upcoming outages -
Bottom of expansion transition.
5 Unit 2 has experienced degradation within the tubesheet since 1993. These indications have been reported to NRC pursuant to the technical specification requirement via the "15 Day" letter following each inspection. This refers to previous inspections through Cycle 11.
6 Unit 3 has experienced degradation within the tubesheet since 1999. These indications have been reported to NRC pursuant to the technical specification requirement via the "15 Day" letter following each inspection. This refers to previous inspections through Cycle 11.
ENCLOSURE 2 San Onofre Unit 3 Steam Generator Tubesheet Inspection Information
TUBESHEET INSPECTION PRACTICES San Onofre Unit 3 Item Plant Information Plant Name:
San Onofre Unit 3 Thot assumed 593-6201F (Note 1)
Thot example 5930F (Actual, 3/24/2003)
Normal Steady State Full Power DP, assumed 1465 psi Normal Steady State Full Power DP, example 1447 psi (Actual, 3124/2003)
Model of Steam Generator Combustion Engineering 3410 MWt Tube Material.
Nickel Alloy 600 HTMA (Ni-Cr-Fe-SB-1 63)
Tube Diameter
.750 inches Tube Wall Thickness, 0.048" nom Expansion Process and Extent CE 'Explansion" Explosive, Full Depth Tubesheet Thickness:
23" Susceptible to degradation below expansion transition region:
Yes If no, provide basis for non-susceptibility determination n/a Historical Inspection Practices and Results Most recent outage:
Date of Outage January 2003 Cycle #
Beginning of Cycle 12 Inspection technique used Bobbin coil / Rotating Coil Technology (RCT)
Extent of inspections (be specific on landmarks used to determine All tubes; Hot leg; Bobbin coil full depth I RCT partial depth; 7 inches inspection extent) below the Bottom of the Expansion Transition Results (degradation mechanisms identified and orientation)
Primary Water Stress Corrosion Cracking (PWSCC); Hot leg, Resuts degadaton echniss idntiiedand rietaton)3 Circumferential; 9 Axial (Note 3)
Bases for inspection technique and inspection extent Bobbin = Tech Spec RCT = analytical Technical Document reference (Generic or Plant Specific?)
WCAP 15894 (Note 2a-2e); Plant Specific If generic, provide statement that plant conditions and design are bounded by Technical Document inputs and assumptions Previous outages:
Inspection techniques used Bobbin, RCT Cycle 7 and Later Extent of inspections (be specific on landmarks used to determine Note 4a & 4b inspection extent)
Results (degradation mechanisms and orientation)
PWSCC; Hot leg; 0 Circumferential, 14 Axial. (Note 6)
Bases for inspection technique and inspection extent Bobbin = Tech Spec; RCT = analytical (Unit 3 C11 and later)
Planned Inspection for Next Outage Anticipated date of outage 4th Quarter 2004 Techniques to be used Bobbin coil / RCT Extent of inspections (be specific on landmarks used to determine All tubes; Hot leg, Bobbin coil full depth / RCT partial depth; 7 inches inspection extent) below the Bottom of the Expansion Transition Bases for inspection technique and inspection extent Bobbin = Tech Spec RCT = analytical
Notes:
1 By design, the SONGS NSSS controlling temperature parameter is cold leg temperature.
2 WCAP-1 5894 Refers to:
2a WCAP 15894-P Revision 0; "NDE Inspection Strategy For the tubesheet Region in SONGS Units 2 and 3;" Dated May 2002; Westinghouse Proprietary Class 2 2b WCAP 15894-NP Revision 0; "NDE Inspection Strategy For the tubesheet Region in SONGS Units 2 and 3;" Dated May 2002; Non Proprietary Version 2c "Westinghouse Report WCAP 15984-P ERRATA;"
Transmitted as -- Westinghouse Letter LTR-SGDA-02-174 2d WCAP 15894-P Supplement 1,Revision 0; "NDE Supplement to Inspection Strategy For the tubesheet Region in SONGS Units 2 and 3;" Dated November 2002; Westinghouse Proprietary Class 2 2e WCAP 15894-NP Supplement 1,Revision 0; "NDE Supplement to Inspection Strategy For the tubesheet Region in SONGS Units 2 and 3;" Dated November 2002; Non Proprietary 3
As reported in 15 day letter in Tables and Appendices. The table summarizes the number of tubes repaired and active degradation mechanisms found. Each tube is only counted once in this listing, although it may also have an eddy current indication of a type below the point in the listing where it appears. The appendices provide the complete results of the steam generator tubing inspection. For Unit 2, Table 3 lists 10 tubes with circumferential indications within the tubesheet. By examination the appendices indicate an additional tube that contains a circumferential indication. This additional tube contained another pluggable indication.
I Notes (con't.)
4a Prior to 1993 - No rotating coil examinations; Cycle 7 and later inspections were Rotating Coil Technology (RCT) tested down to TTS-2" then to TTS-3". For the Cycle 1 1 and Unit 2 Cycle 12 outages (2000-2002) RCT tested down to TTS-5".
4b The landmarks to determine the inspection extent are: 1)
Prior to Unit 3 cycle 12 (Jan. 2003) Nominal top-of-tubesheet. 2) Unit 3 Cycle 12 and upcoming outages -
Bottom of expansion transition.
5 Unit 2 has experienced degradation within the tubesheet since 1993. These indications have been reported to NRC pursuant to the technical specification requirement via the "15 Day" letter following each inspection. This refers to previous inspections through Cycle 11.
6 Unit 3 has experienced degradation within the tubesheet since 1999. These indications have been reported to NRC pursuant to the technical specification requirement via the "15 Day" letter following each inspection. This refers to previous inspections through Cycle 11.