ML082530278

Vermont Yankee July 2008 Evidentiary Hearing - Applicant Exhibit E4-10-VY, VY Engineering Report VY-RPT-08-0022

ML082530278
Person / Time
Site:	Vermont Yankee
Issue date:	05/02/2008
From:	O'Connor T Entergy Operations
To:	NRC/SECY/RAS
SECY RAS
References
06-849-03-LR, 50-271-LR, Entergy-Applicant-E4-10-VY, RAS M-325 VY-RPT-08-0022, Rev 0
Download: ML082530278 (22)

Text

DOCKETED USNRC August 12, 2008 (11:00am)

OFFICE OF SECRETARY RULEMAKINGS AND ADJUDICATIONS STAFF FORM EN-DC-1 47 ATTACHMENT 9.1 ENGINEERING REPORT COVER SHEET Engineering Report No. VY-RPT-08-0022 Rev. 0 Page 1 of 21 ENTERGY NUCLEAR 9ýý4Entffgy Engineering Report Cover Sheet Engineering Report

Title:

VERMONT YANKEE PIPING FLOW ACCELERATED CORROSION INSPECTION PROGRAM (EN-DC-315) 2007 REFUELING OUTAGE INSPECTION REPORT (RFO 26- Spring 2007)

Engineering Report Type:

New [ Revision [] Cancelled [] Superseded E]

Applicable Site(s)

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(5) Report Origin: Z] Entergy E1 Vendor Vendor Document No.: N/A (6) Quality-Related: Z Yes nl No Prepared by: Thomas M. O'Connor M IlvoA4~ Go f~a'Jko Date: *_-_Z-()_"

Responsible Engineer (Print Na, ne/Sign Verified/

Reviewed by: Scott D. Goodwin Date:

Design Verifier/Reviewer (Prin-Tlame/Sign)

Reviewed by:* N/A Date: N/A Authorized Nuclear In-service Inspecto (ANII)

Approved by: Mark P. LeFrancois/g,'ZZ* I/,U C.,A_.-- Date: 5--/'2-0 &

Supervisor (Print Name/Sign)

For ASME Section XI Code Program plans per ENN-DC-120, if required.

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VY-RPT-08-0022 Page I of 21

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REVISION

SUMMARY

Revision Description of Change Reason for Change No. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _

0 Original Report N/A VY-RPT-08-0022 Page 2 of 21

VY Piping FAC Inspection Proaram 2007 Refueling Outage Inspection Report (RF026- Spring 2007)

TABLE OF CONTENTS Section Description Page No.

Engineering Report Cover Sheet (ENN-DC-147 Att.9.1) 1 REVISION

SUMMARY

2 TABLE OF CONTENTS 3 1.0 EXECUTIVE

SUMMARY

4 2.0 SCOPE / PURPOSE 5 3.0 ASSUMPTIONS 5.

4.0 2007 REFUELING OUTAGE INSPECTION PLAN 6 5.0 EVALUATION OF INSPECTION RESULTS 7 5.1 Large Bore Piping 7 5.2 Turbine Cross Around Piping 8 5.3 Small Bore Piping 9 5.4 Feedwater Heater Shells 9 6.0 COMPONENTS REQUIRING FUTURE MONITORING 10 7.0 COMPONENTS REQUIRING POSSIBLE REPAIR OR REPLACEMENT 10

8.0 CONCLUSION

S / RECOMMENDATIONS FOR FUTURE FAC 11 INSPECTIONS

9.0 REFERENCES

12 ATTACHMENT 1:

SUMMARY

OF LARGE BORE PIPING UT INSPECTION 13-16 RESULTS ATTACHMENT 2:

SUMMARY

OF SMALL BORE PIPING UT INSPECTION 17-19 RESULTS ATTACHMENT 3: COMPONENTS RECOMMENDED FOR FUTURE 20-21 MONITORING VY-RPT-08-0022 Page 3 ot 21

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SUMMARY

External UT measurements were taken on forty-nine (49) large bore piping components in the Feedwater, Condensate, and Main Steam. Four (4) components in the Steam Seal Header system that were de-scoped during RFO 25 were inspected in RFO 26. External UT inspections were performed on thirteen (13) sections of carbon steel small bore piping. An internal visual inspection of the B 30 inch diameter Turbine Cross Around piping was performed. The inspection was performed under Work Order 51079729.

Component selection was based on a combination of; previous inspection results, the CHECWORKS models, industry and plant operating experience, input from the Turbine Performance Monitoring System, projections for EPU operation on FAC wear rates in plant piping, and engineering judgment.

A detailed selection process was used and was documented in Reference (4).

The large bore and small bore inspection results were evaluated using a three level screening process defined in Entergy procedure EN-DC-315. All components inspected were found to have a wall thickness greater than the code minimum wall thickness. The predicted thickness at the next refueling outage was greater than the code minimum wall thickness for all components. No large bore piping components required repair or replacement during the refueling outage. Remaining service life (RSL) calculations based on the UT inspection data have been factored to account for a 20%

extended power update which commenced in March 2006.

A summary of the large bore piping component screening is contained in Attachment 1. Attachment 2 contains a summary of the small bore piping inspection results.

Section 6.0 discusses the criteria used to screen components as requiring future monitoring.

Attachment 3 contains a summary of piping components recommended for future inspections.

No components inspected in RFO 26 required repair or replacement. There were no immediate operability concerns as the result of FAC inspections performed during RF026 Section 8.0 contains conclusions and recommendations for future FAC Inspections. Eight (8) components on the Steam Seal Header and Steam Packing Exhauster lines scheduled for inspection in RF026 and were de-scoped due to accessibility and LP turbine work in the same location. These locations should be inspected in RFO 27.

VY-RPT-08-0022 Page 4 of 21

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2.0 SCOPE / PURPOSE Each refueling outage, ultrasonic thickness (UT) measurements and/or internal visual inspections are performed on plant piping per Entergy Corporation Flow Accelerated Corrosion Program Procedure.

EN-DC-315, Reference (1). For RFO 26, the inspections, scaffolding installation, insulation removal, and surface preparation activities were performed under Work Orders 51079729-01 to 51079729-99.

This report summarizes the results of the inspections performed.

3.0 ASSUMPTIONS There are no assumptions.

Page 5 of 21 VY-RPT-08-0022 VY-RPT-08-0022 Page 5 of 21

VY Pinina FAC Insnection Proaram VY nsi~ctio PolnaFAC Proram2007 Refueling Outagze Inspection Report (RF026- Spring 2007) 4.0 2007 REFUELING OUTAGE INSPECTION PLAN The 2007 refueling outage inspection scope was developed to satisfy the following goals:

• Inspection of large bore components, requiring or recommended for follow up inspections, based on UT data from previous refueling outages.

• Inspection of components identified by the EPRI CHECWORKS computer code as being ranked high for susceptibility to wear and/or having the least time remaining to reach code minimum wall thickness.

• Perform repeat inspections and new inspections on selected large bore components for calibration of- the CHECWORKS models.

" To incorporate industry experience into the program through inspection of components at VY that are similar to those that have either failed or showed significant wall thinning at other plants.

During the 2007 RFO, inspections were performed on piping at the Main Steam Drain Collector Header in response to industry experience. Also, 6" C-44 at the condenser was inspected based on OE at the Hatch Plant which experienced leaks in both units.

" Perform an internal visual inspection of the LAST remaining carbon steel turbine cross around line 30"-CAR-B, to confirm its condition after approximately one full year of increased flow due to the 20% extended power uprate.

o Inspection of selected small bore components contained in the Small Bore Database which have had an initial inspection and are now possibly subjected to increased flows from the extended power uprate. Also, inspection of locations identified through review of industry operation experience (OE) and locations identified by Thermal Performance Monitoring as having possible leakage to the condenser past normally closed valves.

" Inspection of small bore piping components subjected to off normal flow conditions, such as components downstream of normally closed valves which connect directly to the condenser.

These components are typically identified by the cognizant Systems Engineer, using the turbine performance monitoring system.

• Inspect piping components identified as having the largest change in projected wear rate under EPU conditions. Component selection was based primarily on the increased velocity. Piping downstream of the Feedwater Reg valve FCV-6-12B was selected for inspection.

" Inspect components based on leaks at VY. Inspections on the Turbine Steam Seal header (SSH) lines to determine the extent of condition for CR-VTY-2004-02985, Reference (11).

Due to the planned duration for RFO 26 FAC activities consideration was given to optimizing the locations and number of components to be inspected, and also to be consistent with previous outage inspection efforts. The detailed reasoning for component selection is contained in the Inspection Location Worksheets, Reference (4). The complete planned scope for RFO 26 is contained in Reference (5).

Page 6 of 21 VY-RPT-08-0022 VY-RPTo08-0022 Page 6 ot21

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M U M M ,jnn7 P iialin n"+o a Inc ection Re ort '09:Q9Q- Q rin 20071 5.0 EVALUATION OF INSPECTION RESULTS 5.1 Large Bore Piping The planned large bore piping inspection scope for RFO 26 included external UT exams on forty-one (41) large bore piping components at sixteen locations on the Feedwater, Condensate, Main Steam, Turbine Steam Seal, and Steam Packing Exhauster Systems. Planned inspections on eight (8) components of the Turbine Steam Seal header (SSH) and the Steam Packing Exhauster (SPE) lines were "de-scoped" from the 2007 RFO due to accessibility. Some of the components on the SSH lines that were de-scoped in RFO 25 were inspected during RFO 26. A total of forty-nine (49) large bore components were inspected using external UT, this includes the sixteen (16) components on the 6" C-44 line at the condenser. At those locations only the component indicating the highest apparent wear was recorded in Attachment 1.

The thickness data were evaluated using a three level screening process as defined in EN-DC-315, Reference 1. The UT inspection results for each component were reviewed for anomalies and consistency with piping geometry. Wear rates (wear/cycle) were calculated for each component using methods specified in EN-DC-315, and are consistent with NSAC-202L, Reference (6). The calculated wear rates for piping components which experience flow during normal operation were increased by a factor of 1.25 to account for a 20% extended power update (EPU) commenced in March 2006. The 1.25 factor is to envelope possible increases in wear rates due to the increased EPU flow velocities.

The larger of the factored wear rate or a minimum wear rate of 0.005 inches/cycle was used in the trending projections.

Using the calculated wear rates and the 2007 measured thickness, the predicted thickness at the end of the next cycle (2008 Tpred ) was calculated using a safety factor of 1.1 on the calculated wear per cycle. Using both the wear rate and 2007 measurement data, the Remaining Service Life (RSL) for each component was calculated. The RSL is the projected number of cycles beyond the Spring 2007 refueling outage (RF026) for each component to wear down to the code minimum wall thickness.

Components passing the Level 1 screen have 2008 Tpred greater than .875Tnom (the manufacturing tolerance of new piping) and require no further evaluation. The Level 2 screen is for components with 2008 Tpred less than .875Tnom but greater than Tmin (the code minimum wall thickness to resist pressure and mechanical loads). These components are acceptable for continued operation but future monitoring may be recommended. The Level 3 screening is for components with 2008 Tpred less than Tmin. The Level 3 screening is a detailed analytical methodology. It also requires that additional piping components be inspected this outage (sample expansion), and considered for inspection during future refueling outages.

All components inspected were found to have wall thickness greater than code minimum wall thickness. All predicted wall thickness (at the 2008 refueling outage) values were above code minimum wall thickness. Of the 49 large bore piping components inspected, 40 (81.6%) passed the Level 1 screen, and the remaining 9 (18.4%) passed the Level 2 screen. A summary of the large bore piping component screening is contained in Attachment 1.

No large bore repairs or replacements were required. Two components were recommended for future monitoring. These are discussed in Section 6 of this report. Additional discussion on monitoring of the carbon steel sections of the Feedwater Pump Recirculator lines, and inspection of components removed from the inspection scope in 2007 are included in Section 6.

Page 7 of 21 VY-RPT.08-0022 VY-RPT-08-0022 Page 7 of 21

VY Piping FAC Inspection Piogram 2007 Refueling Outage Insaection Reaort (RF026- SDring 2007) 5.2 Turbine Cross Around Piping 30 Inch Diameter Line B:

The 30 inch diameter B line is the only remaining original carbon steel line. The other three lines have been completely replaced with Chrome-Moly material (P22) which has been demonstrated to be resistant to FAC damage. A full internal visual inspection of the B 30 inch diameter cross around line on the east side of the turbine was performed to confirm the internal condition of the line prior to operation under EPU flows.

The interior of the line generally appears the same as observed in 1999 and 2002. The extent of areas of red/black oxide identified in previous inspections is essentially the same. Markings on the interior of the pipe to identify the 1995 inspection/repair locations and the 1996 UT locations are still visible. The presence of china white markings are evidence that there is no significant wall loss occurring in the line under increased steam flows under EPU conditions.

VY-RPT-08-0022 Page 8 of 21

VY Piping FAC Inspection Prociram F2007 Refueling Outage Inspection Report (RF026- Spring 2007) 5.3 Small Bore Piping Thirteen (13) sections of small bore piping were scheduled for external UT inspection during the 2007 refueling outage. Components were selected based on plant and industry operating experience (OE),

input from the Turbine Performance Monitoring system, projections for EPU potential impact on conditions that effect FAC wear rates, and locations without previous inspections.

Using the calculated wear rates and the 2007 measured thickness, the predicted thickness at the end of the next cycle (2008 Tpred ) was calculated using a safety factor of 1.1 on the calculated wear per cycle. Using both the wear rate and 2007 measurement data, the Remaining Service Life (RSL) for each component was calculated. The RSL is the projected number of cycles beyond the fall 2008 refueling outage (RF027) for each component to wear down to the code minimum wall thickness.

Components were assessed using the same screening process as the Large Bore Piping. Three levels of screening assess the condition of each section and evaluate further inspection or replacement requirements.

All components inspected were found to have wall thickness greater than code minimum wall thickness. All predicted wall thickness (at the 2008 refueling outage) values were above code minimum wall thickness. Thirteen small bore components were inspected. Ten (77%) of the sections of small bore piping inspected passed the Level 1 screen and the remaining three (23%) passed the Level 2 screen. A summary of the small bore piping inspection results is contained in Attachment 2.

No small bore repairs or replacements were required.

Two components in the Auxiliary Steam Drains were recommended for future monitoring. A pipe stub at the Condenser wall should be checked.

No significant wear was found in the small bore piping inspected. All projected remaining service life (RSL) values are greater than the life of the plant (including a projected 20 year license renewal period). A summary of the small bore piping inspection results is contained in Attachment 2.

5.4 Feedwater Heater Shells All four HP feedwater heaters were replaced during RFO 24. All ten feedwater heater shells have been replaced with either chrome-moly or stainless steel materials. There are no planned UT inspections for the feedwater heater shells in the near term.

VY-RPT-08-0022 Page 9 of 21

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i 6.0 COMPONENTS REQUIRING FUTURE MONITORING Large bore components requiring future monitoring are identified using the predicted thickness at the next refueling outage (2008 Tpedicted ), the "Screening Level" which the component passed, and the "RSL', the approximate Cycles to Tmin, shown in Attachment 1. From the wear rates and cycles to Tmin calculated in Attachment 1, only two components were identified with less than 20 cycles to Tmin. Re-inspection was recommended for these components and the adjacent components. See for a detailed description.

The 2007 refueling outage inspection results will be incorporated into the existing CHECWORKS models. The 2007 inspection data along with data from previous inspections will be used to refine the wear rate predictions. The results shown in Attachment 1 and the updated CHECWORKS analyses will be used to determine the inspection scope for future refueling outages.

Planned inspections on eight (8) components on the Steam Seal header (SSH) and the Steam Packing Exhauster (SPE) in RF026 were de-scoped due to accessibility issues. These locations should be inspected in RFO 27.

7.0 COMPONENTS REQUIRING POSSIBLE REPAIR OR REPLACEMENT No specific large bore components or small bore components were identified as requiring repairs or replacements during RFO 26.

VY-RPT-08-0022 Page 10 of 21

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8.0 CONCLUSION

S / RECOMMENDATIONS FOR FUTURE'FAC INSPECTIONS There were no immediate operability concerns as the result of FAC inspections performed during RF026.

Based on results from the RFO 26 inspections, no new immediate or near term repairs or replacements are required.

Inspection data taken this outage will serve to identify any increase in wear that may be occurring due to operation with the increased flows from power uprate.

Data from repeat inspections of large bore components in the Feedwater System which experience continuous flow shows essentially no wear has occurred since commencement of EPU in March, 2006.

Eight (8) components on the SSH and SPE lines scheduled for inspection in RF026 were de-scoped due to accessibility issues. Six(6) of these locations should be inspected in RFO 27. The other two (2007-03, -04) components were replaced.

The data from Section 12 of 6" C-44 indicates that some wear may be occurring; this section of straight pipe and the elbows upstream and downstream (Sections 11 and 13) should be inspected in RFO 27.

Small Bore location 07-SBO4 has a low cycles to Tmin when including the additional wall thickness for corrosion allowance, it has been included in the recommendations to be re-inspected during RFO 27.

VY-RPT-08-0022 Page 11 ot2l VY-RPT-08-0022 Page 11 of 21

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9.0 REFERENCES

1. Entergy Corporation Program Procedure EN-DC-315, Rev.0, Flow Accelerated Corrosion Program, Effective 12/1/2006.

2. EN-CS-S-008, Pipe Wall Thinning Structural Evaluation.

3. ENN-NDE-9.05, Revision 0, Ultrasonic Thickness Examination

4. V.Y. Piping FAC Inspection Program - 2006 Refueling Outage: Inspection Location Worksheets / Methods and Reasons for Component Selection, dated 5/11/06.

5. ENVY Memo: J.C.Fitzpatrick to S.D.Goodwin, subject: Piping FAC Inspection Scope for the 2007 Refueling Outage (Revision la), VYM-FAC-2006-001a, dated 2/8/07.

6. EPRI Report, Recommendations for an Effective Flow-Accelerated Corrosion Program, EPRI NSAC-202L-R2, April 1999.

7. CHECWORKS - Computer Program User Guide, TR 103496, August 1994 by Altos Engineering Applications Inc. for EPRI.

8. VY Calculation No. VYPC 92-004, Rev. 0, Turbine Cross Around Piping Wall Thinning Evaluation.

9. VY Design Engineering - Bolton MEMO: J.C. Fitzpatrick to D.Girroir(VY-ISI), VYM 98/91, dated May 8,1998, subject:1998 Refueling Outage Turbine Cross Around Piping Inspections.

10. INPO OE19368/OE18895: Mihama 3 - PWR, 8/9/2004 Rupture of Condensate line downstream of restriction orifice.

11. CR-VTY-2004-02985, Through wall leaks in the Turbine Steam Seal Header Piping.

(Corrective Action: CA-03 for additional inspections).

12. VY-RPT-04-00010, Revision 0, Vermont Yankee Piping Flow Accelerated Corrosion Inspection Program (PP 7028) 2004 Refueling Outage Inspection Report (RFO 24).

13. VY-RPT-06-00002, Revision 0, Vermont Yankee Piping Flow Accelerated Corrosion Inspection Program (PP 7028) 2005 Refueling Outage Inspection Report (RFO 25).

VY-RPT-08-0022 Page 12 of 21

V.Y. PIPING FAC INSPECTION PROGRAM 2007 REFUELING OUTAGE INSPECTION REPORT (RF026- Spring 2007)

ATTACHMENT 1:

SUMMARY

OF LARGE BORE PIPING UT INSPECTION RESULTS LARGE BORE I nspec. Component ID DIA Tno .875Tnor Tmin 2007 Wear Factored 2008 Passed (RSL) Comments / Future Inspections No. Min.Tmeas Rate Wear Tpredicted IScreen Recommended (in.) (in.) (in.) (in.) (inJcycle) Rate for Level (in.)

EPU Notes 2.3 Note 4 Note 5 Note 6 Note 7 2007-05 1SSH5EI01 5 0.258 0.226 0.095 0.218 0.003 0.005 0.212 2 25.3 2007-06 1SSH5SP02US 5 0.258 0.226 0.048 0.208 0.003 0.005 0.202 2 29.1 2007-07 1SSH6EL06 5 0.258 0.226 0.095 0.167 0.0057 0.0057 0.161 2 25.3 2007-08 1SSH6SP08 5 0.258 0.226 0-048 0.320 .0045 0.006 0.313 1 41.2 2007-13 FD02EL05 16 1.219 1.067 0.964 1.494 0.021 0.026 1.465 1 18.5 This is a repeat inspection(Fall

......... _ 1996) 2007-14 FD02SP05 16 1.219 1.067 0.967 1.113 0.0 0.005 1.107 1 22.6 This is a repeat inspection(FaIll 1996) 2007-15 FD07SPO1DS 18 1.375 1.203 0.964 1.224 0.008 0.010 1.213 1 29.5 This is a repeat inspection(Fall 1996) 2007-j16 FDO7EL02 18 1.375 1.203 0.964 1.337 0.002 0.005 1.331 1 67.8 2007-17 FDO7SP02US 18 1.375 1.203 0.964 1.214 0.008 0.010 1.203 1 22.7 2007-18 FD08SP05 18 1.375 1.203 0.964 1.184 0.0096 0.012 1.171 2 20.0 1999 recommendation for repeat inspection.

2007-19 FD07TE01 Run 18 1.375 1.203 0.964 1.244 0.007 0.0088 1.234 1 28.9 Ranked High in CHECWORKS model. Also increased EPU flows.

Asbestos removal required.

2007-20 FD07EL10 18 1.375 1.203 0.964 1.382 0.015 0.0188 1.361 1 20.2 2007-21 FD07SP11 18 1.375 1.203 964 ..1.210 0.008 0.010 1.199 2 22.4 72007-22 FD07RD03 18 1.375 1.203 1.085 1.227- 0.000 0.005 1.221 1 25.8 EPU flows increase (Highest Velocity in Feedwater system) 2007-23 FD07SP03 18 1.375 1.203 1.085 1.305 0.004 0.005 1.299 1 40.0 Page 13 of 21 VY-RPT-08-0022 VY-RPT-08-0022 *Page 13 of 21

V.Y. PIPING FAC INSPECTION PROGRAM 2007 REFUELING OUTAGE INSPECTION REPORT (RF026- Spring 2007)

ATTACHMENT 1:

SUMMARY

OF LARGE BORE PIPING UT INSPECTION RESULTS Inspect. Component ID ILIA Tnom (875T.n. Tmin 2007 Wear Factored 2008 IPassed (RSL) Comments / Future Inspections No. Min.Tmeas Wear T200 Screen Recommended Rate for Level (in.) (in.) (in.) (in.) (in.) (inicycle) EPU Notes 2,3 Note 4 Note 5 Note 6 Note 7 2007-24 MSD9SPO7DS 8 0.500 0.438 0.348 0.460 0.002 0.005 0.454 1 21.3 Industry QE on Drain Collector Headers. Asbestos removal required. Note this is part of AST

_ALT Boundary 2007-25 CD28EL04 20 0.594 0.520 0.511 0.663 - 0.001 0.006 0.656 1 23.0 Checworks Calibration and increased flow and temperature effects form EPU 2007-26 CD28SP03US 20 0.594 0.520 0.551 0.565 0.002 0.005 0.559 1 31.1 2007-27 HDlAEL06 6 0,280 0.245 0.120 0.268 0.001 0.005 0.262 1 26.9 Checworks Calibration, HWC, and increased flow and temperature effects form EPU 2007-28 HDlASP08 6 0.280 0.245 0.120 0.252 0.001 0.005 0.219 2 24.0 2007-29 HD3BTE01 6 0.280 0.245 0.120 0.330 0.001 0.005 0.344 1 21.8 Checworks Calibration, HWC, and increased flow and temperature effects form EPU 2007-30 HD3BEL02 10 0.375 0.328 0.190 0.326 0.003 0.005 0.382 1 21.1 2007-31 HD3BSP05US 10 0.375 0.328 0.190 0.344 0.002 0.005 0.338 1 24.4 2007-32 HD5ATE01 Run 14 0.375 0.328 0.210 0.635 0.004 0.005 0.630 1 72.7 Checworks Calibration, HWC, and increased flow and temperature I _effects form EPU 2007- HD5ASP06 14 0.375 0.328 0.235 0.332 0.004 0.005 0.326 2 72.7 33a 10 0.365 0.319 0.210 0.353 0.001 0.005 0.347 1 27.8 2007- HD5ASP06 10 0.365 0.319 0.085 0.346 0.007 0.008 0.337 1 29.7 33b 2007-34 HD5ASP05US 14 0.375 0.328 0.210 0.342 0.003 0.005 0.337 1 44.0 2007-35 HD25RD02 Pipe 14 0.75 0.656 0.350 0.638 0.016 0.020 0.616 2 13.1 Checworks Calibration, HWC, and increased flow and temperature effects form EPU Page 14 of 21 VY-RPT-08-0022 VY-RPT-08-0022 Page 14 of 21

V.Y. PIPING FAC INSPECTION PROGRAM 2007 REFUELING OUTAGE INSPECTION REPORT (RF026- Spring 2007)

ATTACHMENT 1:

SUMMARY

OF LARGE BORE PIPING UT INSPECTION RESULTS Inspect. Component ID DIA Tno .875Tnom Tmini 2007 wear Factored 2008 Passed (RSL) Comments / Future Inspections Mifl.Tmeas Rate Wear Tpredlcted Screen Recommended No.

(in.) (in.) (in.) (in.) (in.) (inicycle) Rate for Level EPU Notes 2,3 Note 4 Note 5 Note 6 [Note 7 2007-36 HD25SP02 NzA. 14 0.75 0.656 0.160 0.738 0.002 0.005 0.732 1 70.5 2007-37 HD12TE01 6 0.280 0.245 0.142 0.362 0.006 0.008 0.353 1 25.0 Checworks Calibration, HWC, and increased flow and temperature effects form EPU 2007-38 HD12SPO1 6 0.280 0.245 0.142 0.274 0.001 0.005 0.267 1 24.0 2007-39 HD12EL06 6 0.280 0.245 0.118 0.250 0.008 0.010 0.239 2 12.0 Checworks Calibration, HWC, and increased flow and temperature effects form EPU 2007-40 HD12SP07US 6 0.280 0.245 0.142 0.268 0.003 0.005 0.262 1 26.9 2007-41 6" C-44 at 6 0.280 0.245 0.142 0.253 0.001 0.005 0.247 1 28.2 OE from Hatch (leaks in both Unit s condenser 1 &2) nozzle 63 3 0.216 0.189 0.095 0.215 0.001 0.005 0.209 1 21.8 Susceptible Non Modeled (SNM)

I_ I I I_ I Piping Page 15 of 21 v -nr I -UO-UUZZ i -rMI V T -uo-uu~ Page 15 of 21

V.Y. PIPING FAC INSPECTION PROGRAM 2007 REFUELING OUTAGE INSPECTION REPORT (RF026- Spring 2007)

ATTACHMENT 1:

SUMMARY

OF LARGE BORE PIPING UT INSPECTION RESULTS NOTES:

1. All thickness values are inches.

2. Wear/Cycle is approximately inches/1 8 months. The wear per cycle was calculated 19.9 equivalent 18 month cycles based on approx. 157,000 operating hours up to 1996 outage, and an ave. 12000 + hrs./cycle since then.

3. Minimum Wear/Cycle used to calculate Tpred and Cycles to Tmin is 0.005 inches per cycle.

4. Factored Wear Rate to account for EPU flows = 1.25 x calculated wear rate or 0.005 in/cycle whichever is less larger

5. 2008 T predicted = 2007 T measured - F.S. * (Factored Wear Rate/Cycle), F.S. =Factor of Safety = 1.10.

6. Highest screening level for the entire piping component. For example when multiple areas of a component-such as the small end & large end of a piping reducer are evaluated, the highest screening level for either end the component governs.

7. Remaining Service Life = Cycles to Tmin is calculated from: (2007 T measured - Tmin) (i.e. Cycles from 2007 RFO)

F.S. x Factored Wear Rate /Cycle VT-MY I Page 16 of 21 V Y-P*IPT-UU-UU22 Page 16 of 21

V.Y. PIPING FAC INSPECTION PROGRAM 2007 REFUELING OUTAGE INSPECTION REPORT (RF026- Spring 2007)

ATTACHMENT 2:

SUMMARY

OF SMALL BORE PIPING UT INSPECTION RESULTS SMALL BORE Description!/ Sect. Size Sch Tnom. .875T..m T min. 2007 Min. Apparent Cycles Comments Small Bore (in.) (inch) (inch) (inch) Measured Wear Rate to Inspection. Location Thickness (inch/cycle) Tmin.

Number (Note 1) (inch) (Note 2) (Note3) 07-SB01 T.B. Heater Bay 3" MSD-4 from 3 80 0.300 0.262 0.206 0.278 0.00125 >50 Connections from AOG steam Supply to condenser nozzle 67 07-SBO2 Rx Bldg. off Torus 1" & 2-1/2" Pipe & 1 160 0.250 0.219 0.118 0.234 0.006 17.6 Catwalk - West Fittings D.S. of Steam Trap ST-60-3 07-SB03 Rx Bldg. off Torus 1" & 2-1/2" Pipe & 1 160 0.250 0.219 0.118 0.223 0.00375 25.5 Catwalk - West Fittings D.S. LCV-2-143 07-SB04 Turb. Bldg. Heater 2" CS pipe stub at 2 80 0.218 0.191 0.161 0.169 0.0025 2.9/13.3 Inspect Bay, Condenser A - Condenser wall RF027 on line 2"-MSD- (Note 4)

North 406 at condenser nozzle 35 (Steam Lead Drains) .........

07-SB05 Turb. Bldg. Heater 2" CS pipe stub at 2 80 0.218 0.191 0.161 0.194 0.0012 25.0

- Bay, Condenser B Condenser wall Northeast on line 2"-

HPCI/RCIC Drain line at condenser nozzle 56 07-SB06 Turbine Bldg. 1" & 2-1/2" Pipe & 160 0.250 0.219 0.118 0.226 0.001 >50 WJAt Hoom LCV-1 01 -39 VY-RPT-08-0022 Page 17 of 21

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V.Y. PIPING FAC INSPECTION PROGRAM 2007 REFUELING OUTAGE INSPECTION REPORT (RF026- Spring 2007)

ATTACHMENT 2:

SUMMARY

' OF SMALL BORE PIPING UT INSPECTION RESULTS Sect. Size Sch Tnom. .875Tnom T min. 2007 Min. Apparent Cycles Comments Small Bore Description/

(in.) (inch) (inch) (inch) Measured Wear Rate (Inch/cycle) to Tmin.

Location Inspection. IIn.be NumerThickness (Note 1) (inch) (Note 2) (Note3)

Turbine Bldg. 1" & 2" Pipe & 2.5 160 0.375 0.328 0.181 0.305 0.005 28.2 07-SBO7 SJAE Room Fittings U.S &

D.S. of Steam Trap ST-62-1 Turbine Bldg. 2" -MSD-465 Pipe 2 160 0.344 0.301 0.161 0.315 0.001 >50 07-SBO8 Heater Bay & Fittings at Condenser B south connection to side condenser B Nozzle 68 07-SB09 Turbine Bldg. 4"-HV-8A at 4 STD 0.237 0.207 0.075 0.225 0.001 >50 Heater Bay Condenser A Condenser A Nozzle 22B 07-SB10 Turbine Bldg. Piping DS of LCV- 2 80 0.218 0.191 0.073 0.182 0.002 49.5 Heater Bay 101-3B Condenser A I Turbine Bldg. 1" & 2-1/2" Pipe & 1 160 0.250 0.219 0.118 0.204 0.002 39.1 07-SB11 SJAE Room Fittings D.S. of LCV-1 01-40 07-SB12 Turbine Bldg. 1" & 2" Pipe & 1 160 0.250 0.219 0.060 0.184 0.005 26.8 SJAE Room Fittings U.S &

D.S. of Steam Trap ST-62-2 Turbine Bldg. 2"-MSD-464 Pipe 1.5 160 0.281 0.246 0.142 0.262 0.002 >50 07-SB13 Heater Bay & Fittings at Condenser B south connection to side condenser B Nozzle 69 Page 18 of 21 VY-RPT-OB-0022 VY-RPT-08-0022 Page 18 of 21

V.Y. PIPING FAC INSPECTION PROGRAM 2007 REFUELING OUTAGE INSPECTION REPORT (RF026- Spring 2007)

ATTACHMENT 2:

SUMMARY

OF SMALL BORE PIPING UT INSPECTION RESULTS NOTES:

1. Tmin includes a 0.065 inch corrosion allowance per ANSI B31.1-1967.

2. Apparent wear = Tnom - Tmeasured.

3. Cycles to Tmin from 2007 refueling outage.

4. Tmin includes a 0.065 inch corrosion allowance per ANSI B31.1-1967. This is an original code requirement to account for corrosion, including this in Tmin maintains that original margin for corrosion. The 13.3 cycles to Tmin is based solely on stress.

Page 19 of 21 VY-RPT-08-0022 Page 19 of 21

V.Y. PIPING FAC INSPECTION PROGRAM 2007 REFUELING OUTAGE INSPECTION REPORT (RF026- Spring 2007)

ATTACHMENT 3: COMPONENTS RECOMMENDED FOR FUTURE MONITORING Inspection Component Calculated Recommend Evaluation / Reasons for Recommendation Cycles to Re-inspection Tmin RFO 2007-01 1SSH3EL05 RFO 27 Planned inspections on the turbine Steam Seal header (SSH) lines to determine the 2007-02 1SSH3SP06US extent of condition for CR-VTY-2004-02985 CA 03(wall leak at elbow on line 1SSH4) were "de-scoped" from the 2005 RFO due to higher priority LP turbine work in the same location Inspect these locations during RF027 in Fall 2008.

2007-09 2SPE3EL01

• RFO 27 Planned inspections on the turbine Packing Exhaust (SPE) lines to determine the 2007-10 2SPE3SPOIUS

• extent of condition for CR-VTY-2004-02985 CA 03(walI leak at packing 3 and 5 due to 2007-11 2SPE5EL01

• through wall leak at elbow on line 1 SSH4) were "de-scoped" from the 2005 RFO due to 2007-12 2SPE5SP01US

• higher priority LP turbine work in the same location Inspect these locations during RF027 in Fall 2008.

2007-05 1SSH5EL01 25.3 RFO 30 Component test results met Level 2 criteria per EN-DC-315 "Acceptable for Continued 2007-06 1SSH5SP02US 29.1 Operation, Future inspection required".

2007-07 1SSH6EL06 25.3 2007-18 FD08SP05 20.0 RFO 29 Component test results met Level 2 criteria per EN-DC-315 "Acceptable for Continued Operation, Future inspection required" 2007-21 FD07SP11 22.4 RFO 29 Component test results met Level 2 criteria per EN-DC-315 "Acceptable for Continued Operation, Future inspection required" 2007-28 HD1ASPO8 24.0 RFO 30 Component test results met Level 2 criteria per EN-DC-315 "Acceptable for Continued Operation, Future inspection required" Page 20 of 21 VY-HP I -U~-UU22 VY-RPT-08-0022 Page 20 of 21

V.Y. PIPING FAC INSPECTION PROGRAM 2007 REFUELING OUTAGE INSPECTION REPORT (RF026- Spring 2007)

ATTACHMENT 3: COMPONENTS RECOMMENDED FOR FUTURE MONITORING 2007-35 HD25RD02 13.1 RFO 28 Component test results met Level 2 criteria per EN-DC-315 "Acceptable for Continued Operation, Future inspection required" 2007-39 HD12EL06 12.0 RFO 28 Component test results met Level 2 criteria per EN-DC-315 "Acceptable for Continued Operation, Future inspection required" 2007-41: 6" C-44 at N/A RFO 27 The data from Section 12 of 6" C-44 indicates that some wear may be

-11,-12, condenser nozzle occurring; this section of straight pipe and the elbows upstream and

-13 63: Section 12 downstream (Sections 11 and 13) should be inspected in RFO 27.

07-SB04 2" CS pipe stub at 13.3/2.9 RFO 27 Component test results met Level 2 criteria per EN-DC-315 "Acceptable for Continued Condenser wall on Operation, Future inspection required" line 2"-MSD-406 at condenser nozzle 35 (Steam Lead Drains) 07-SB11 1" &2-1/2" Pipe & 29.1 RFO 30 Component test results met Level 2 criteria per EN-DC-315 "Acceptable for Continued Fittings D.S. of Operation, Future inspection required" LCV-101-40 22.5 07-SB12 1" & 2" Pipe &

Fittings U.S & D.S.

of Steam Trap ST-62-2

• - Denotes new first time inspection for RF027.

Page 21 of 21 VY-RPT-08-0022 VY-RPT-08-0022 Page 21 of 21