BVY 06-079, 2006/08/22-Vermont Yankee License Renewal Application, Amendment 11

2006/08/22-Vermont Yankee License Renewal Application, Amendment 11

ML062400342
Person / Time
Site:	Vermont Yankee
Issue date:	08/22/2006
From:	Ted Sullivan Entergy Nuclear Operations
To:	Document Control Desk, Office of Nuclear Reactor Regulation
References
%dam200610, BVY 06-079, TAC MC9668
Download: ML062400342 (33)

Text

'Entergy Entergy Nuclear Operations, Inc.Vermont Yankee P.O. Box 0500 185 Old Ferry Road Brattleboro, VT 05302-0500 Tel 802 257 5271 August 22, 2006 Docket No. 50-271 BVY 06-079 TAC No. MC 9668 ATTN: Document Control Desk U.S. Nuclear Regulatory Commission Washington, DC 20555-0001

Subject:

1. Letter, Entergy to USNRC, "Vermont Yankee Nuclear Power Station, License No.DPR-28, License Renewal Application," BVY 06-009, dated January 25, 2006.Vermont Yankee Nuclear Power Station License No. DPR-28 (Docket No. 50-271)License Renewal Application.

Amendment 11 On January 25, 2006, Entergy Nuclear Operations, Inc. and Entergy Nuclear Vermont Yankee, LLC (Entergy) submitted the License Renewal Application for the Vermont Yankee Nuclear Power Station (VYNPS) as indicated by Reference

1. This amendment provides the following updated information.

• Attachment 1: VYNPS License Renewal Commitments List, Revision 1,* Attachment 2: VYNPS LRA Amendment List, Revision 1,* Attachment 3: Time Limited Aging Analysis (TLAA) Tables, Revision 1.Should you have any questions concerning this letter, please contact Mr. James DeVincentis at (802)258-4236.I declare under penalty of perjury that the foregoing is true and correct. Executed on August 22, 2006.Sincerely,-t Tedd AA. ~uivjar Site Vice President Vermont Yankee Nuclear Power Station Enclosed:

Attachment 1, 2, 3.cc: See next page.Aii?

BVY 06-079 Docket No. 50-271 Page 2 of 2 cc: Mr. James Dyer, Director U.S. Nuclear Regulatory Commission Office 05E7 Washington, DC 20555-00001 Mr. Samuel J. Collins, Regional Administrator U.S. Nuclear Regulatory Commission, Region 1 475 Allendale Road King of Prussia, PA 19406-1415 Mr. Jack Strosnider, Director U.S. Nuclear Regulatory Commission Office T8A23 Washington, DC 20555-00001 Mr. Jonathan Rowley, Senior Project Manager U.S. Nuclear Regulatory Commission 11555 Rockville Pike MS-O-1 1 F1 Rockville, MD 20853 Mr. James J. Shea, Project Manager U.S. Nuclear Regulatory Commission Mail Stop 08G9A Washington, DC 20555 USNRC Resident Inspector Entergy Nuclear Vermont Yankee, LLC P.O. Box 157 (for mail delivery)Vernon, Vermont 05354 Mr. David O'Brien, Commissioner VT Department of Public Service 112 State Street -Drawer 20 Montpelier, Vermont 05620-2601 BVY 06-079 Docket No. 50-271 Attachment 1 Vermont Yankee Nuclear Power Station License Renewal Application

-Amendment 11 License Renewal Commitment List, Revision 1 VERMONT YANKEE NUCLEAR POWER STATION LICENSE RENEWAL COMMITMENT LIST REVISION 1 During the development and review of the Vermont Yankee Nuclear Power Station License Renewal Application, Entergy made commitments to provide aging management programs to manage the effects of aging on structures and components during the extended period of operation.

The following table lists these license renewal commitments, along with the implementation schedule and the source of the commitment.

ITEM COMMITMENT IMPLEMENTATION SOURCE Related LRA SCHEDULE Section No./Comments 1 Guidance for performing examinations of buried piping will be enhanced to March 21, 2012 BVY 06-009 B.1.1/Audit specify that coating degradation and corrosion are attributes to be Items 5 & 130 evaluated.

2 Fifteen (15) percent of the top guide locations will be inspected using As stated in the BVY 06-009 B.1.7/Audit enhanced visual inspection technique, EVT-1, within the first 18 years of commitment Item 14 the period of extended operation, with at least one-third of the inspections to be completed within the first 6 years and at least two-thirds within the first 12 years of the period of extended operation.

Locations selected for examination will be areas that have exceeded the neutron fluence threshold.

3 The Diesel Fuel Monitoring Program will be enhanced to ensure ultrasonic March 21,2012 BVY 06-009 B.1.9 thickness measurement of the fuel oil storage tank bottom surface will be performed every 10 years during tank cleaning and inspection.

4 The Diesel Fuel Monitoring Program will be enhanced to specify UT March 21,2012 BVY 06-009 B.1.9 measurements of the fuel oil storage tank bottom surface will have acceptance criterion

-> 60% Tnom.5 The Fatigue Monitoring Program will be modified to require periodic update March 21, 2012 BVY 06-009 B.1.11 of cumulative fatigue usage factors (CUFs), or to require update of CUFs if the number of accumulated cycles approaches the number assumed in the design calculation.

6 A computerized monitoring program (e.g., FatiguePro) will be used to March 21,2012 BVY 06-009 B.1.11 directly determine cumulative fatigue usage factors (CUFs) for locations of interest.7 The allowable number of effective transients will be established for March 21, 2012 BVY 06-009 B.1.11 monitored transients.

This will allow quantitative projection of future margin.Attachment 1 Page 1 of 6 BVY 06-079 VERMONT YANKEE NUCLEAR POWER STATION LICENSE RENEWAL COMMITMENT LIST REVISION 1 ITEM COMMITMENT IMPLEMENTATION SOURCE Related LRA SCHEDULE Section No./Comments 8 Procedures will be enhanced to specify that fire damper frames in fire March 21, 2012 BVY 06-009 B.1.12.1/Audit barriers will be inspected for corrosion.

Acceptance criteria will be Items 35, 151, enhanced to verify no significant corrosion.

152, 153 and 159 9 Procedures will be enhanced to state that the diesel engine sub-systems March 21, 2012 BVY 06-009 B.1.12.1/Audit (including the fuel supply line) will be observed while the pump is running. Items 33, 150 Acceptance criteria will be enhanced to verify that the diesel engine did not & 155 exhibit signs of degradation while it was running; such as fuel oil, lube oil, coolant, or exhaust gas leakage.10 Fire Water System Program procedures will be enhanced to specify that in March 21, 2012 BVY 06-009 B.1.12.2 accordance with NFPA 25 (2002 edition), Section 5.3.1.1.1, when sprinklers have been in place for 50 years a representative sample of sprinkler heads will be submitted to a recognized testing laboratory for field service testing.This sampling will be repeated every 10 years.11 The Fire Water System Program will be enhanced to specify that wall March 21, 2012 BVY 06-009 B.1.12.2/Audit thickness evaluations of fire protection piping will be performed on system Items 37 & 41 components using non-intrusive techniques (e.g., volumetric testing) to identify evidence of loss of material due to corrosion.

These inspections will be performed before the end of the current operating term and during the period of extended operation.

Results of the initial evaluations will be used to determine the appropriate inspection interval to ensure aging effects are identified prior to loss of intended function.12 Implement the Heat Exchanger Monitoring Program as described in LRA March 21, 2012 BVY 06-009 B.1.14 Section B.1.14.13 Implement the Non-EQ Inaccessible Medium-Voltage Cable Program as March 21, 2012 BVY 06-009 B.1.17 described in LRA Section B.1.17.14 Implement the Non-EQ Instrumentation Circuits Test Review Program as March 21, 2012 BVY 06-009 B.1.18 described in LRA Section B.1.18.15 Implement the Non-EQ Insulated Cables and Connections Program as March 21,2012 BVY 06-009 B.1.19 described in LRA Section 8.1.19.Attachment 1 Page 2 of 6 BVY 06-079 VERMONT YANKEE NUCLEAR POWER STATION LICENSE RENEWAL COMMITMENT LIST REVISION 1 ITEM COMMITMENT IMPLEMENTATION SOURCE Related LRA SCHEDULE Section No./Comments 16 Implement the One-Time Inspection Program as described in LRA Section March 21, 2012 BVY 06-009 B.1.21 B.1.21. Include destructive or non-destructive examination of one (1) Audit Items socket welded connection using techniques proven by past industry 239, 240, 330, experience to be effective for the identification of cracking in small bore 331 socket welds. Should an inspection opportunity not occur (e.g., socket weld failure or socket weld replacement), a susceptible small-bore socket weld will be examined either destructively or non-destructively prior to entering the period of extended operation.

17 Enhance the Periodic Surveillance and Preventive Maintenance Program to March 21,2012 BVY 06-009 B.1.22 assure that the effects of aging will be managed as described in LRA Audit Item 377 Section B.1.22.18 Enhance the Reactor Vessel Surveillance Program to proceduralize the March 21, 2012 BVY 06-009 B.1.24 data analysis, acceptance criteria, and corrective actions described in the program description in LRA Section B.1.24.19 Implement the Selective Leaching Program as described in LRA Section March 21, 2012 BVY 06-009 B.1.25 B.1.25.20 Enhance the Structures Monitoring Program to specify that process facility March 21, 2012 BVY 06-009 B.1.27.2 crane rails and girders, condensate storage tank (CST) enclosure, C02 Audit Item 377 tank enclosure, N 2 tank enclosure and restraining wall, CST pipe trench, diesel generator cable trench, fuel oil pump house, service water pipe trench, man-way seals and gaskets, and hatch seals and gaskets are included in the program.21 Guidance for performing structural examinations of wood to identify loss of March 21, 2012 BVY 06-009 B.1.27.2 material, cracking, and change in material properties will be added to the Structures Monitoring Program.22 Guidance for performing structural examinations of elastomers (seals and March 21, 2012 BVY 06-009 B.1.27.2 gaskets) to identify cracking and change in material properties (cracking when manually flexed) will be enhanced in the Structures Monitoring Program procedure.

Attachment 1 Page 3 of 6 BVY 06-079 VERMONT YANKEE NUCLEAR POWER STATION LICENSE RENEWAL COMMITMENT LIST REVISION 1 ITEM COMMITMENT IMPLEMENTATION SOURCE Related LRA SCHEDULE Section No./Comments 23 Guidance for performing structural examinations of PVC cooling tower fill to March 21, 2012 BVY 06-009 B.1.27.2 identify cracking and change in material properties will be added to the Structures Monitoring Program procedure.

24 System walkdown guidance documents will be enhanced to perform March 21, 2012 BVY 06-009 B.1.28 periodic system engineer inspections of systems in scope and subject to Audit Items aging management review for license renewal in accordance with 10 CFR 187,188 & 190 54.4 (a)(1) and (a)(3). Inspections shall include areas surrounding the subject systems to identify hazards to those systems. Inspections of nearby systems that could impact the subject system will include SSCs that are in scope and subject to aging management review for license renewal in accordance with 10 CFR 54.4 (a)(2).25 Implement the Thermal Aging and Neutron Irradiation Embrittlement of Cast March 21, 2012 BVY 06-009 B.1.29 Austenitic Stainless Steel (CASS) Program as described in LRA Section B.1.29.26 Procedures will be enhanced to flush the John Deere Diesel Generator March 21,2012 BVY 06-009 B.1.30.1 cooling water system and replace the coolant and coolant conditioner every Audit Items 84 three years. I I & 164 Attachment 1 Page 4 of 6 BVY 06-079 VERMONT YANKEE NUCLEAR POWER STATION LICENSE RENEWAL COMMITMENT LIST REVISION 1 ITEM COMMITMENT IMPLEMENTATION SOURCE Related LRA SCHEDULE Section No./Comments 27 For each location that may exceed a CUF of 1.0 when considering March 21, 2012 BVY-06-058 4.3.3 environmental effects, VYNPS will implement one or more of the following:

Audit Items 29, (1) further refinement of the fatigue analyses to lower the predicted CUFs to March 21,2010 for 107 & 318 less than 1.0; performing a fatigue (2) management of fatigue at the affected locations by an inspection analysis that program that has been reviewed and approved by the NRC (e.g., periodic addresses the effects non-destructive examination of the affected locations at inspection intervals of reactor coolant to be determined by a method acceptable to the NRC); environment on (3) repair or replacement of the affected locations, fatigue (in accordance with an NRC Should VYNPS select the option to manage environmental-assisted fatigue approved version of during the period of extended operation, details of the aging management the ASME Code)program such as scope, qualification, method, and frequency will be provided to the NRC two years prior to the period of extended operation for review and approval.28 Revise program procedures to indicate that the Instrument Air Program will March 21, 2012 BVY 06-009 B.1.16 maintain instrument air quality in accordance with ISA S7.3 Audit Item 47 29 VYNPS will perform one of the following:

March 21, 2012 BVY 06-009 B.1.7/ Audit 1. Install core plate wedges, or, Item 9 2. Complete a plant-specific analysis to determine acceptance criteria for continued inspection of core plate hold down bolting in accordance with BWRVIP-25 and submit the inspection plan to the NRC two years prior to the period of extended operation for NRC review and approval.30 Revise System Walkdown Program to specify C02 system inspections March 21, 2012 BVY 06-009 B.1.28 every 6 months. Audit Items 30, 141, 146 & 298 31 Revise Fire Water System Program to specify annual fire hydrant gasket March 21, 2012 BVY 06-009 B.1.12.2 inspections and flow tests. Audit Items 39& 40 Attachment 1 Page 5 of 6 BVY 06-079 VERMONT YANKEE NUCLEAR POWER STATION LICENSE RENEWAL COMMITMENT LIST REVISION 1 ITEM COMMITMENT IMPLEMENTATION SOURCE Related LRA SCHEDULE Section No./Comments 32 Implement the Metal Enclosed Bus Program. March 21, 2012 BVY 06-058 Audit Item 97 (Details to be provided in a LRA Amendment) 33 Include within the Structures Monitoring Program provisions that will ensure March 21, 2012 BVY 06-009 B.1.27 an engineering evaluation is made on a periodic basis of groundwater Audit Item 77 samples to assess aggressiveness of groundwater to concrete.34 Implement the Bolting Integrity Program. March 21,2012 BVY 06-058 Audit Items Details to be provided in a LRA Amendment with specific locations in the 198, 216, 218, LRA referenced.

237, 331 & 333 35 Provide within the System Walkdown Training Program a process to March 21, 2012 BVY 06-058 Audit Item document biennial refresher training of Engineers to demonstrate inclusion 384 of the methodology for aging management of plant equipment as described in EPRI Aging Assessment Field Guide or comparable instructional guide.36 If technology to inspect the hidden jet pump thermal sleeve and core spray March 21, 2010 BVY06-058 Audit Item 12 thermal sleeve welds has not been developed and approved by the NRC at least two years prior to the period of extended operation, VYNPS will initiate plant-specific action to resolve this issue. That plant specific action may be justification that the welds do not require inspection.

37 Continue inspections in accordance with the Steam Dryer Monitoring March 21, 2010 BVY 06-079 Audit Item 204 Program, Revision 3 in the event that the BWRVIP-139 is not approved prior to the period of extended operation.

I Attachment 1 Page 6 of 6 BVY 06-079 BVY 06-079 Docket No. 50-271 Attachment 2 Vermont Yankee Nuclear Power Station License Renewal Application

-Amendment 11 License Renewal Application Amendment List, Revision 1 ATTACHMENT 2 LICENSE RENEWAL APPLICATION SUPPLEMENT AMENDMENT LIST, Revision 1 Audit item 11: LRA Section B.1.7 is revised as follows.1. Delete the exception to the BWR vessel internals program related to the core shroud (page B-27).2. Delete exception Note #1 on page B- 29.Audit item 26: Add the following text to LRA Section B.1.10 to include the "EQ Component Reanalysis Attributes" specified in NUREG-1801 Vol. 2 Section X.El.EQ Component Re-analysis Attributes The re-analysis of an aging evaluation is normally performed to extend the qualification by reducing excess conservatism incorporated in the prior evaluation.

Reanalysis of an aging evaluation to extend the qualification of a component is performed on a routine basis pursuant to 10 CFR 50.49(e) as part of an EQ program. While a component life limiting condition may be due to thermal, radiation, or cyclical aging, the vast majority of component aging limits are based on thermal conditions.

Conservatism may exist in aging evaluation parameters, such as the assumed ambient temperature of the component, an unrealistically low activation energy, or in the application of a component (de-energized versus energized).

The re-analysis of an aging evaluation is documented according to the station's quality assurance program requirements that require the verification of assumptions and conclusions.

As already noted, important attributes of a re-analysis include analytical methods, data collection and reduction methods, underlying assumptions, acceptance criteria, and corrective actions (if acceptance criteria are not met). These attributes are discussed below.Analytical Methods The analytical models used in the re-analysis of an aging evaluation are the same as those previously applied during the prior evaluation.

The Arrhenius methodology is an acceptable thermal model for performing a thermal aging evaluation.

The analytical method used for a radiation aging evaluation is to demonstrate qualification for the total integrated dose (that is, normal radiation dose for the projected installed life plus accident radiation dose). For license renewal, one acceptable method of establishing the 60-year normal radiation dose is to multiply the 40-year normal radiation dose by 1.5 (that is, 60 years/40 years). The result is added to the accident radiation dose to obtain the total integrated dose for the component.

For cyclical aging, a similar approach may be used. Other models may be justified on a case-by-case basis.Data Collection and Reduction Methods Reducing excess conservatism in the component service conditions (for example, temperature, radiation, cycles) used in the prior aging evaluation is the chief method used for a re-analysis.

Temperature data used in an aging evaluation is to be conservative and based on plant design temperatures or on actual plant temperature data. When used, plant temperature data can be obtained in several ways, including monitors used for Technical Specification compliance, other installed monitors, measurements made by plant operators during rounds, and temperature sensors on large motors (while the motor is not running).

A representative number of temperature measurements are conservatively evaluated to establish the temperatures used in an BVY 06-079 Page 1 of 12 A'TACHMENT 2 LICENSE RENEWAL APPLICATION SUPPLEMENT AMENDMENT LIST, Revision 1 aging evaluation.

Plant temperature data may be used in an aging evaluation in different ways, such as; (a) directly applying the plant temperature data in the evaluation, or (b)using the plant temperature data to demonstrate conservatism when using plant design temperatures for an evaluation.

Any changes to material activation energy values as part of a re-analysis are to be justified on a plant-specific basis. Similar methods of reducing excess conservatism in the component service conditions used in prior aging evaluations can be used for radiation and cyclical aging.Underlying Assumptions EQ component aging evaluations contain sufficient conservatism to account for most environmental changes occurring due to plant modifications and events. When unexpected adverse conditions are identified during operational or maintenance activities that affect the normal operating environment of a qualified component, the affected EQ component is evaluated and appropriate corrective actions are taken that may include changes to the qualification bases and conclusions.

Acceptance Criteria and Corrective Actions The re-analysis of an aging evaluation could extend the qualification of the component.

If the qualification cannot be extended by re-analysis, the component is to be refurbished, replaced, or re-qualified prior to exceeding the period for which the current qualification remains valid. A re-analysis is to be performed in a timely manner (that is, sufficient time is available to refurbish, replace, or re-qualify the component if the re-analysis is unsuccessful).

Audit items 30, 141, 146 and 298: LRA Section B.1.28 is revised to include an enhancement to perform C02 system inspections every 6 months under the System Walkdown Program. The required inspections will be initiated prior to the period of extended operation.

Commitment 30.Audit item 39: LRA Section B.1.12.2 is revised to delete the exception to the annual fire hydrant gasket inspections.

Commitment 31.Audit item 40: LRA Section B.1.12.2 is revised to delete the exception to the annual fire hydrant flow tests. Commitment 31.Audit item 48: LRA Section B.1.17 is revised as follows. "VYNPS inspection for water accumulation in manholes is conducted in accordance with a plant procedure.

An evaluation per the Corrective Action Process will be used to determine the need to revise manhole inspection frequency based on inspection results." Audit item 51: LRA Section B.1.18 is revised as follows. 'The first test of neutron monitoring system cables that are disconnected during instrument calibrations shall be completed before the period of extended operation and subsequent tests will occur at least once every 10 years.In accordance with the corrective action program, an engineering evaluation will be performed when test acceptance criteria are not met and corrective actions, including modified inspection frequency, will be implemented to ensure that the intended functions of the cables can be maintained consistent with the current licensing basis for the period of extended operation." BVY 06-079 Page 2 of 12 ATTACHMENT 2 LICENSE RENEWAL APPLICATION SUPPLEMENT AMENDMENT LIST, Revision 1 Audit item 53: To clarify the technical basis for sampling, the sampling discussion in LRA Section B.1.19 for the Non-EQ Insulated Cables and Connections Program is revised to read as follows. "Most cables and connections installed in adverse localized environments are accessible.

This program is a sampling program. Selected cables and connections from accessible areas will be inspected and represent, with reasonable assurance, all cables and connections in the adverse localized environments.

If an unacceptable condition or situation is identified for a cable or connection in the inspection sample, a determination will be made as to whether the same condition or situation is applicable to other accessible cables or connections.

The sample size will be increased based on an evaluation per the Corrective Action Process." Audit items 76, 80, 81, 243, 266, and 270: Aging effects on the drywell moisture barrier will be managed under the Containment Inservice Inspection Program instead of the Structures Monitoring Program. In support of this, the LRA is revised as follows.1. In the LRA Table 3.5.2-1 line item for "Drywell floor liner seal" change the aging management program from "Structures Monitoring" to "CII-IWE".

For clarification, change "drywell floor liner seal" to "drywell shell to floor seal (moisture barrier)." The clarification of this terminology also applies to Table 2.4-1 and Section B.1.27.2.2. In LRA Table 3.5.1 line Item 3.5.1-16 the Discussion column is revised to read: "The aging effects cited in the NUREG-1 801 item are loss of sealing and leakage. Loss of sealing is a consequence of the aging effects "cracking" and "change in material properties." For VYNPS, the Containment Leak Rate Program manages cracking and changes in material properties for the primary containment seal and gaskets. The Inservice Inspection -IWE Program manages cracking and changes in material properties for the drywell shell to floor seal (moisture barrier)." 3. In LRA Table 3.5.1, Line Item 3.5.1-5, the Discussion column last paragraph is revised to read 'The drywell steel shell and the moisture barrier where the drywell shell becomes embedded in the drywell concrete floor are inspected in accordance with the Containment Inservice Inspection (IWE) Program." 4. LRA Section 3.5.2.2.1.4 is revised to delete from the end of the first paragraph, the phrase "and Structures Monitoring Program".

The drywell to floor moisture barrier will be inspected under the Containment Inservice Inspection (IWE) Program only. The Structures Monitoring Program is not used.Audit item 77: LRA Section B.1.27.2 for the Structures Monitoring Program is revised to include an enhancement to perform at least once every five years an engineering evaluation of groundwater samples to assess for groundwater being aggressive to concrete.

Commitment 33.Audit items 85,. 86, 87, 166, 200, 227, 232, 233, 239, 240, 295, 297, 310, 312, 313, and 359: The effectiveness of the Water Chemistry Control -Auxiliary Systems, BWR, and Closed Cooling Water programs is confirmed by the One-Time Inspection program. To provide further clarification, LRA Appendix A is revised for these three water chemistry control programs to include the sentence 'The One-Time Inspection Program will confirm the effectiveness of the program".BVY 06-079 Page 3 of 12 ATTACHMENT 2 LICENSE RENEWAL APPLICATION SUPPLEMENT AMENDMENT LIST, Revision 1 Audit item 93: In order to address transmission connections, in LRA Table 3.6.2-1, change line item Transmission conductors to Transmission conductors and connections.

Revise Section 3.6.2.2.3 to include the following text after the second paragraph.

The aging effects for transmission conductors evident in industry operating experience are loss of conductor strength and loss of material (wear).The prevalent mechanism contributing to loss of conductor strength of an aluminum conductor steel reinforced (ACSR) transmission conductor is corrosion, which includes corrosion of the steel core and aluminum strand pitting. Corrosion in ACSR conductors is a very slow acting mechanism, and the corrosion rates depend on air quality, which includes suspended particles chemistry, S02 concentration in air, precipitation, fog chemistry and meteorological conditions.

Air quality in rural areas generally contains low concentrations of suspended particles and S02, which keeps the corrosion rate to a minimum. Tests performed by Ontario Hydroelectric showed a 30% loss of composite conductor strength of an 80 year old ACSR conductor due to corrosion.

VYNPS transmission conductors include ACSR and aluminum conductor alloy reinforced (ACAR) conductors.

ACAR conductors are aluminum conductors reinforced with alloy steel. ACAR conductors are more resistant to loss of conductor strength since the core of the conductor is a more corrosion resistant alloy steel. AMR conclusions regarding ACSR conductors conservatively bound ACAR conductors.

The National Electrical Safety Code (NESC) requires that tension on installed conductors be a maximum of 60% of the ultimate conductor strength.

The NESC also sets the maximum tension a conductor must be designed to withstand under heavy load requirements, which includes consideration of ice, wind and temperature.

These requirements are reviewed concerning the specific conductors included in scope at VYNPS.The 4/0 ACSR conductors have the lowest initial design margin of any transmission conductors included in the AMR. The Ontario Hydro test and the NESC requirements illustrate with reasonable assurance that transmission conductors will have ample strength through the period of extended operation.

Therefore, loss of conductor strength due to corrosion of the transmission conductors in not an aging effect requiring management for the period of extended operation.

Loss of material due to mechanical wear can be an aging effect for strain and suspension insulators that are subject to movement caused by transmission conductor vibration or sway from wind loading. Design and installation standards for transmission conductors consider sway caused by wind loading. Experience has shown that transmission conductors do not normally swing and that when they do swing because of substantial wind, they do not continue to swing for very long once the wind has subsided.

Wear has not been identified during routine inspection; therefore, loss of material due to wear in not an aging effect requiring management.

Audit item 97: The VYNPS Metal-Enclosed Bus program ten element comparison to NUREG-1801 (excerpt from the Aging Management Program Evaluation Report LRPD-02) will be provided in later correspondence along with associated revisions to the LRA.BVY 06-079 Page 4 of 12 ATTACHMENT 2 LICENSE RENEWAL APPLICATION SUPPLEMENT AMENDMENT LIST, Revision 1 Audit item 118: LRA Section B.1.17 is revised to replace the last sentence in the Program Description with; 'The specific type of test to be performed will be determined prior to the initial test and is to be a proven test for detecting deterioration of the insulation system due to wetting as described in EPRI TR-1 03834-Pl -2, or other testing that is state-of-the-art at the time the test is performed." Audit item 120: LRA Section B.1.17 Program Description is revised to state that medium-voltage cables include cables with operating voltage level from 2kV to 35kV.Audit item 124: LRA Section B.1.19 Program Description is revised to include the following.

'The program applies to accessible electrical cables and connections within the scope of license renewal that are installed in adverse localized environments caused by heat or radiation in the presence of oxygen." Audit Item 159: LRA Section B.1.12.1 is revised to add fire dampers to the list of components in the Program Description that require a periodic visual inspection.

Audit item 165: Line Items 3.3.1-50 and 3.3.1-51 in LRA Table 3.3.1 are revised to replace the Water Chemistry Control -Auxiliary Systems program in the Discussion column with the Water Chemistry Control -BWR Program Audit item 187: LRA section B.1.28 is revised to add the following enhancements.

The System Walkdown Program implementing procedure will be enhanced to specify that systems in scope and subject to aging management review for license renewal in accordance with 10 CFR 50.54 (a)(1) and (a)(3) shall be inspected.

In addition, the implementing procedure will be enhanced to provide guidance to inspect nearby systems with the potential for spatial interaction.

These enhancements will be implemented as shown in Commitment 24.Audit item 198, 216, 218, 237, 331 and 333: The VYNPS Bolting Integrity Program ten element comparison to NUREG-1801 (excerpt from the Aging Management Program Evaluation Report LRPD-02) will be provided in later correspondence along with associated changes to the LRA.The Bolting Integrity Program will be implemented prior to the period of extended operation in accordance with Commitment 34.Audit item 203: LRA Table 3.1.2-3 is revised to indicate that with the exception of the head seal leak detection line, the Inservice Inspection Program applies to all component types of Piping and fittings < 4" NPS with an aging effect of cracking in addition to the Water Chemistry Control-BWR and One-Time Inspection Programs.Audit Item 209 and 291: LRA Table 3.1.2-1 on page 3.1-52 is revised to remove all the line items for the component type of Thermal Sleeves Feedwater Inlets (N4). The thermal sleeves are not subject to aging management review since they perform no intended function for license renewal. The sleeves are installed with an interference fit rather than welded so they have no impact on the reactor coolant pressure boundary.Audit items 224, 225, 226, 229, 293, 294, 315, and 369: LRA Section B.1.21and the associated table, are revised to state that the One-Time Inspection program will verify effectiveness of the Oil Analysis and Diesel Fuel Monitoring programs by confirming the absence of loss of material, cracking and fouling, where applicable.

BVY 06-079 Page 5 of 12 ATTACHMENT 2 LICENSE RENEWAL APPLICATION SUPPLEMENT AMENDMENT LIST, Revision 1 Audit item 235: In LRA Table 3.3.2-10 for the NUREG-1801 Vol. 2 Item for component types"humidifier housing" and "piping", change item VIII.F1-8 to item VII.F1-8.

The incorrect number was entered due to a typographical error.Audit item 242: LRA Table 3.5.2-1 is revised to delete line items for "Bellows (reactor vessel and drywell)".

Also the corresponding line item in Table 2.4-1 is deleted.Audit item 244: LRA Table 3.5.2-6 is revised to indicate that Note "A" applies to component seals and gaskets (doors, man-ways and hatches) with the aging management program of Structures Monitoring Program.Audit item 248: LRA Table 3.5.2-6 is revised to change Note "A" to Note "C" for electrical and instrument panels and enclosures with a material of galvanized steel in a protected from weather environment.

Aging effect and associated aging management program are unchanged.

Audit item 249: LRA Table 3.5.2-6 is revised to change Note "A" to Note "C" for flood curb with a material of galvanized steel in a protected from weather environment.

Aging effect and associated aging management program are unchanged.

Audit item 250: LRA Table 3.5.2-1 is revised to change Note "E" to Note "A" for torus shell with an aging effect of cracking-fatigue.

Aging effect and associated aging management program are unchanged.

Audit items 255, 257, 258, 259, 263, and 278: The LRA is revised to indicate loss of material as an aging effect requiring management with the Structures Monitoring Program as the aging management program and the NUREG-1801 Vol. 2 Item as 111.B4-7 with a Note C in the following cases.1. Table 3.5.2-5 for transmission towers with a material of galvanized steel in an exposed to weather environment

2. Table 3.5.2-6 for conduit with a material of galvanized steel in an exposed to weather environment

3. Table 3.5.2-6 for conduit support with a material of galvanized steel in an exposed to weather environment

4. Table 3.5.2-6 for electrical and instrument panels and enclosures with a material of galvanized steel in an exposed to weather environment

5. Table 3.5.2-6 for structural bolting with a material of galvanized steel in an exposed to weather environment LRA Table 3.5.1, item 3.5.1-50 is revised to include the following in the Discussion column: "Consistent with NUREG-1 801 for galvanized steel components in outdoor air.The Structures Monitoring Program will manage loss of material." BVY 06-079 Page 6 of 12 ATTACHMENT 2 LICENSE RENEWAL APPLICATION SUPPLEMENT AMENDMENT LIST, Revision 1 Audit item 267: LRA Table 3.5.2-1 is revised to add the following line.Torus PB, Carbon Protected Cracking TLAA- II.B4-4 3.5.1-9 A mechanical SSR steel from (fatigue) metal (C-1I3)penetrations weather fatigue LRA Table 3.5.2-1 is revised to delete the following line.Drywellto PB, Carbon Protected Cracking TLAA- II.B1.1-4 3.5.1-8 A torus vent SS steel from (fatigue) metal (C-21)system weather fatigue The Discussion column for LRA Table 3.5.1 item 3.5.1-8 is revised to read as follows."Fatigue analysis is a TLAA for the torus shell. Fatigue of the torus to drywell vent system is event driven and the analysis is not a TLAA. See Section 3.5.2.2.1.6.

The Discussion column of LRA Table 3.5.1 item 3.5.1-9 is revised to read as follows."Fatigue analysis is a TLAA for the torus penetrations.

See Section 3.5.2.2.1.6.

The Discussion column of LRA Section 3.5.2.2.1.6 is revised to read as follows. 'TLAA are evaluated in accordance with 10 CFR 54.21(c) as documented in Section 4. Fatigue TLAAs for the torus and associated penetrations are evaluated and documented in Section 4.6.LRA Section 3.5.2.3, Time-Limited Aging Analyses, is revised to read as follows. 'TLAA identified for structural components and commodities include fatigue analyses for the torus and torus penetrations.

These topics are discussed in Section 4.6." Audit items 268 and 269: The LRA is revised as follows.1. For clarification, the Discussion column of Table 3.5.1, line items 3.5.1-12 and 3.5.1-13 is revised to add the following statement at the end of the existing information."See Section 3.5.2.2.1.8".

2. LRA Section 3.5.2.2.1.8 is revised to read as follows. "Cyclic loading can lead to cracking of steel and stainless steel penetration bellows, and dissimilar metal welds of BWR containments and BWR suppression pool shell and downcomers.

Cracking due to cyclic loading is not expected to occur in the drywell, torus and associated penetration bellows, penetration sleeves, un-braced downcomers, and dissimilar metal welds. A review of plant operating experience did not identify cracking of the components, and primary containment leakage has not been identified as a concern.Nonetheless the existing Containment Leak Rate Program with augmented ultrasonic exams and Containment Inservice Inspection

-IWE, will continue to be used to detect cracking.

Observed conditions that have the potential for impacting an intended function are evaluated or corrected in accordance with the corrective action process. The Containment Inservice Inspection

-IWE and Containment Leak Rate programs are described in Appendix B." Audit item 279: For clarification, LRA Table 3.5.1, Item 3.5.1-52 discussion is revised to read as follows. "Loss of mechanical function due to the listed mechanisms is not considered an aging BVY 06-079 Page 7 of 12 ATTACHMENT 2 LICENSE RENEWAL APPLICATION SUPPLEMENT AMENDMENT LIST, Revision 1 effect. Such failures typically result from inadequate design or operating events rather than from the effects of aging. Failures due to cyclic thermal loads are rare for structural supports due to their relatively low temperatures." Audit item 280: For clarification, LRA Table 3.5.1, Item 3.5.1-54 discussion is revised as follows. "Loss of mechanical function due to distortion, dirt, overload, fatigue due to vibratory, and cyclic thermal loads is not considered an aging effect requiring management.

Such failures typically result from inadequate design or events rather than the effects of aging. Loss of material due to corrosion, which could cause loss of mechanical function, is addressed under Item 3.5.1-53 for Groups B1.1, B1.2, and B1.3 support members." Audit item 282: For clarification, LRA Table 3.5.1, Line Item 3.5.1-34 discussion is revised to add "See Section 3.5.2.2.2.4(1)".

Audit item 283: LRA Table 3.5.1, Item 3.5.1-35 discussion is revised to replace ACI 301 with ACl 318 and add "See Section 3.5.2.2.2.4(2)" at the end of the existing discussion.

Audit item 284: LRA Table 3.5.1, Line item Number 3.5.1-36 discussion column is revised as follows. "Reaction with aggregates is not an applicable aging mechanism for VYNPS concrete components.

See Section 3.5.2.2.2.1(5) (although for Groups 1-5, 7, 9 this discussion is also applicable for Group 6). See Section 3.5.2.2.2.4(3) additional discussion.

Nonetheless, the Structures Monitoring Program will confirm the absence of aging effects requiring management for VYNPS Group 6 concrete components." To correct an administrative error, the heading of LRA Section 3.5.2.2.2.4 (3) is revised to begin with "Cracking Due to Expansion, Reaction with Aggregates...".

The term stress corrosion cracking is deleted from the heading as it does not apply to this section.Audit item 285: The Discussion column of LRA Table 3.5.1, Item Number 3.5.1-37, is revised to state the following. "Not applicable.

Nonetheless the Structures Monitoring Program will confirm the absence of aging effects requiring management for VYNPS Group 6 concrete components.

See Section 3.5.2.2.2.4(3)".

Audit item 286: For clarification, LRA Table 3.5.1, Item Number 3.5.1-40 discussion column is revised to add "See Section 3.5.2.2.2.6(1)".

Audit Item 300 and 304: LRA Table 3.3.2.13-32 is revised to replace the aging management program of One-Time Inspection with Periodic Surveillance and Preventive Maintenance for all line items containing carbon steel and copper alloy with an environment of untreated water.Audit item 309 and 321: LRA Section 3.1, 3.2, 3.3 and 3.4 tables will be revised to remove'TLAA-metal fatigue" from all line items for which Section 4 does not discuss evaluation of a TLAA. Line by line changes to the tables are provided in Attachment 3 to this letter.Audit item 318: LRA Table 4.3-1 is revised to remove the NUREG/CR-6260 values for core spray safe end, feedwater piping, RHR return piping, and RR piping tee and replace them with N/A. Commitment 27 requires an analysis that addresses the effects of reactor coolant environment on fatigue performed to an NRC-approved version (year) of the ASME code.BVY 06-079 Page 8 of 12 ATTACHMENT 2 LICENSE RENEWAL APPLICATION SUPPLEMENT AMENDMENT LIST, Revision 1 Audit item 319: The last paragraph of LRA Section 4.3.1.1 is replaced with the following.

'The VYNPS Fatigue Monitoring Program will assure that the allowed number of transient cycles is not exceeded.

The program requires corrective action if transient cycle limits are approached.

Consequently, the TLAA (fatigue analyses) based on those transients will remain valid for the period of extended operation in accordance with 10 CFR 54.21(c)(1)(i).

However, when the effects of reactor coolant environment on fatigue are considered in the existing fatigue analyses, several locations have a projected cumulative usage factor in excess of 1.0. See Section 4.3.3 for further discussion of the effects of reactor water environment on fatigue." Audit item 320: LRA Reference 4.3.1 on page 4.3-9 is revised as follows; "4.3-1 Sojka, R. E.(VYNPS), to USNRC Document Control Desk, "Response to Request for Additional Information Regarding Vermont Yankee Core Shroud Modification," BVY 96-96, letter dated August 7, 1996." Audit item 322: LRA Section 4.3.1.3 is replaced with the following."VYNPS replaced reactor recirculation (RR) system piping in 1986. Also replaced were connecting portions of the residual heat removal (RHR) system piping. The new piping was designed and analyzed to ANSI B31.1 but was inspected and tested to ASME Section III requirements.

Stress analyses for the reactor recirculation system were performed to B31.1 requirements.

B31.1 does not require a detailed fatigue analysis that calculates a CUF, but allows up to 7000 cycles with a stress reduction factor of 1.0 in the stress analyses.

The 7000 thermal cycle assumption is valid and bounding for 60 years of operation.

Therefore, the pipe stress calculations are valid for the period of extended operation in accordance with 10 CFR 54.21 (c)(1)(i).

There are no TLAA for Class 1 non-piping components other than the reactor vessel as none of them are designed to codes that require fatigue analyses.UFSAR Section 4.6.3 states that the main steam isolation valves are designed for 40 years based on 100 cycles of operation the first year and 50 cycles of operation per year thereafter.

This statement may be interpreted to imply a TLAA. This TLAA will remain valid through the period of extended operation per 10 CFR 54.21 (c)(1)(i).

The MSIVs will not exceed 2050 cycles in 60 years (34 cycles per year)." In addition LRA section 4.3.2 is replaced with the following.

'The design of safety class 2 and 3 piping systems incorporates the Code stress reduction factor for determining acceptability of piping design with respect to thermal stresses.

The design of ASME B31.1 Code piping also incorporates stress reduction factors based upon an assumed number of thermal cycles. In general, 7000 thermal cycles are assumed, leading to a stress reduction factor of 1.0 in the stress analyses.VYNPS evaluated the validity of this assumption for 60 years of plant operation.

The results of this evaluation indicate that the 7000 thermal cycle assumption is valid and bounding for 60 years of operation.

Therefore, the pipe stress calculations are valid for the period of extended operation in accordance with 10 CFR 54.21 (c)(1)(i).

There are no TLAA for any non-Class 1, non-piping components as they are not built to codes that require fatigue analyses.BVY 06-079 Page 9 of 12 ATTACHMENT 2 LICENSE RENEWAL APPLICATION SUPPLEMENT AMENDMENT LIST, Revision 1 Some applicants for license renewal have estimated that piping in the primary sampling system will have more than 7000 thermal cycles before the end of the period of extended operation.

The sampling system is used to take reactor coolant samples every 96 hours0.00111 days <br />0.0267 hours <br />1.587302e-4 weeks <br />3.6528e-5 months <br /> during normal operation.

However, the normal samples are taken from the RWCU filter influent, where the water has already been cooled. Thus normal sampling does not cause a thermal cycle. Alternate samples may be taken directly from the B discharge header of the reactor recirculation system via containment penetration X-41; however, this is an infrequently performed procedure and this piping, designed to ASME B31.1, will not exceed 7000 cycles prior to 60 years of operation." Audit item 335: LRA Table 3.5.2-6 lists the aging effects for component Penetration sealant, material elastomer in a protected from weather environment as "cracking" and "change in material properties." For clarification, the LRA is revised to separate this component line item into two line items as follows: 1. Delete line item: Penetration EN, Elastomer Protected Cracking, Fire Ill.A6- 3.5.1- C sealant FB, from Change protection, 12 44 (fire, flood, FLB, weather in Structures (TP-7)radiation)

PB, material Monitoring SNS properties

2. Add line item: Penetration EN, Elastomer Protected Cracking, Fire VII.G-1 3.3.1- B sealant FB, from Change in protection (A-19) 61 (PB, weather material (fire) SNS __properties

3. Add line item: Penetration EN, Elastomer Protected Cracking, Structures lllI.A6- 3.5.1- C sealant FLB, from Change Monitoring 12 44 (flood, PB, weather in (TP-7)radiation)

SNS material r properties Audit item 336: LRA Table 3.5.2-6 lists the aging effects for the Seismic isolation joint, with a material of elastomer in a protected from weather environment as "cracking" and "change in material properties." For clarification, the LRA is revised to make the following changes.1. Note C is changed to Note E for this line item.2. The discussion in Table 3.3.1 line Item 3.3.1-61, Page 3.3-49 is revised to read as follows. 'This line item was not used in the auxiliary systems tables. Fire barrier BVY 06-079 Page 10 of 12 ATTACHMENT 2 LICENSE RENEWAL APPLICATION SUPPLEMENT AMENDMENT LIST, Revision 1 seals are evaluated as structural components in Section 3.5. Cracking and change in material properties of elastomer seals, including seismic isolation joints located in fire barriers, are managed by the Fire Protection Program." 3. An additional line item is added to read as follows.Seismic SSR Elastomer Protected Cracking, Structures Ill.A6- 3.5.1- C isolation from Change in Monitoring 12 44 joint weather material (TP-7)properties Audit item 337: LRA Table 3.5.2-6 lists the aging effect for Fire doors, with a material of carbon steel in a protected from weather environment as "loss of material." For clarification, the LRA is revised to change 'Note C' to 'Note B' for this line item.Audit item 342: LRA Section 3.3.2.2.13 Loss of Material due to Wear is revised to state the following:

'Wear is the loss of surface layers due to relative motion between two surfaces.

At VYNPS, in the auxiliary systems, this specific aging effect is not applicable because the heating, ventilation, and air conditioning elastomer coated fiberglass duct flexible connections are fixed at both ends, precluding wear. This item is not applicable to VYNPS auxiliary systems." Audit item 345: LRA Table 3.3.2-13 lists the aging effect for component type of bolting, with a material of stainless steel in an air -outdoor (ext) environment as "none." The LRA is revised to identify loss of material as an aging effect for this line item as shown below.Bolting Pressure Stainless Air -Loss of System G boundary steel outdoor material walkdown Audit item 350: LRA Section A.2.1.31 Structures Monitoring-Vernon Dam FERC Program is replaced with the following.

'The Vernon dam is subject to the Federal Energy Regulatory Commission (FERC) inspection program. This program consists of visual inspections in accordance with FERC guidelines and complies with Title 18 of the Code of Federal Regulations, Conservation of Power and Water Resources, Part 12 (Safety of Water Power Projects and Project Works) and Division of Dam Safety and Inspections Operating Manual.The operation inspection frequency for licensed and exempt low hazard potential dams is biennially.

As indicated in NUREG-1801 for water control structures, NRC has found that FERC/ US Army Corp of Engineers dam inspections and maintenance programs are acceptable for aging management.

" Audit item 354: The LRA is revised to delete Sections 4.7.2.5, 4.7.2.6, A.2.2.7 and A.2.2.8.Also the component type of vessel ID attachment welds and instrument penetrations in LRA Table 4.1-1 is deleted. The items discussed in these sections do not meet the definition of time-limited aging analyses.BVY 06-079 Page 11 of 12 ATTACHMENT 2 LICENSE RENEWAL APPLICATION SUPPLEMENT AMENDMENT LIST, Revision 1 In LRA table 3.1.2-1 (page 3.1-54) for the component type of internals attachments the line with the aging effect of cracking-fatigue and TLAA-metal fatigue as the aging management program is deleted. Cracking managed by the BWR Vessel ID Attachment Welds Program remains in the table.I n LRA table 3.1.2-1 (page 3.1-44) for the component type of nozzles, instrumentation, N11 and N12, the line item with the aging effect of cracking-fatigue and TLAA-metal fatigue as the aging management program is deleted. Cracking managed by the BWR Penetrations Program remains in the table.Audit item 371: LRA Section B.1.11 is revised as follows. 'The VYNPS Fatigue Monitoring Program includes counting of the cycles incurred by the plant. Five transients are monitored by plant operations and recorded as they occur. It is projected that less 60% of the design cycles for these five transients will be used through the first 60 years of operation, including the period of extended operation.

The remaining transients are monitored by plant engineering based on review of operating data at the end of each fuel cycle. These remaining transients are summarized in the Fatigue Monitoring Program as the sixth transient (reactor startups and shutdowns).

Engineering evaluates these transients and advises operations if the number of design cycles is being approached." Audit item 373: LRA Section 3.3.2.2.13 Loss of Material due to Wear is revised to state, 'Wear is the removal of surface layers due to relative motion between two surfaces.

At VYNPS, in the auxiliary systems, this specific aging effect is not applicable because the heating, ventilation, and air conditioning elastomer coated fiberglass duct flexible connections are fixed at both ends, precluding wear. This item is not applicable to VYNPS auxiliary systems." Audit item 376: LRA Table 3.3.1 line item 3.3.1-69 is revised to remove the reference to the One-Time Inspection Program.Audit item 379: LRA Table 3.5.1 line item 3.5.1-16 discussion is revised to add the following paragraph. "For reactor building seals and gaskets, the Periodic Surveillance and Preventive Maintenance Program manages cracking and change in material properties for the railroad inner and outer lock doors elastomer seals." Audit item 382: The operating experience discussion in LRA Appendices B.1.17, B.1.18, and B.1.19 is replaced with the following.

'This program is a new aging management program. Industry operating experience that forms the basis for the program is described in the operating experience element of the NUREG-1 801 program description.

VYNPS plant-specific operating experience has been reviewed against the industry operating experience identified in NUREG-1801.

Although VYNPS has not experienced all of the aging effects listed in NUREG-1801, the VYNPS program will manage all of the aging effects identified in the Operating Experience section of NUREG-1 801.The program is based on the program description in NUREG-1 801, which in turn is based on relevant industry operating experience.

As such, this program will provide reasonable assurance that effects of aging will be managed such that applicable components will continue to perform their intended functions consistent with the current licensing basis for the period of extended operation.

As additional operating experience is obtained, lessons learned can be used to adjust the program, as needed." BVY 06-079 Page 12 of 12 BVY 06-079 Docket No. 50-271 Attachment 3 Vermont Yankee Nuclear Power Station License Renewal Application

-Amendment 11 Time Limited Aging Analysis Table List, Revision 1 ATTACHMENT 3 LICENSE RENEWAL APPLICATION SUPPLEMENT TLAA TABLE CHANGES, Revision 1 Audit item 309, 321 and 354 -Tables and text of LRA Sections 3.1, 3.2, 3.3 and 3.4 are modified as follows: Intended Aging Effect Aging NUREG- Table Component Type Function Material Environment Requiring Management 1801 Vol. 1 Item Notes Change Description Management Programs 2 Item Table 3.1.2-1 Reactor Vessel Closure flange Pressure Low alloy Air-indoor (ext)studs, nuts, boundary steel washers and bushings Incore housing Pressure Stainless Air-indoor (ext)bolting boundary steel" Flange bolts" Flange" Nut and washer Other pressure Pressure Low alloy Air-indoor (ext)boundary bolting boundary steel* Flange bolts and nuts (N6A, N6B, N7)* CRD flange caps-crews and washers Aging effect entry for component line deleted -Cracking managed by Reactor Head Closure Studs Program in following entrv of line.Aging effect entry for component line deleted -Cracking managed by Inservice Inspection Program in following entry of line.I Aging effect entry for component line deleted -Cracking managed by Inservice Inspection Program in following entry of line.CAP Pressure boundary Stainless steel Treated water>270QF (int)* CRD return line (N9)Aging effect entry for component line deleted -Cracking managed by BWR CRD Return Line Nozzle Program in following entry of line.BVY 06-079 Page 1 of 10 ATTACHMENT 3 LICENSE RENEWAL APPLICATION SUPPLEMENT TLAA TABLE CHANGES, Revision 1 Intended Aging Effect Aging NUREG- Table FunctionMaterial Environment Requiring Management 1801 Vol. Talem Notes Change Description Management Programs 2 Item Thermal sleeves Pressure Stainless Treated water Grasing- T,=AA -metal IY.Al7 3.1.1-2 A Aging effect entry for" Recirc inlet (N2) boundary steel >2709F (int) fatigue fatigue (R-04) component line deleted -" Core spray (N5) Cracking managed by BWR Vessel Internals Program in following entry of line.Thermal sleeves Pessu-e Stainless T-eated wateF GaGking T=AA- metal l.A-1-7 3..-2 A Deleted entire line -SFeedwator

..l+ t bunday steel and >270 2 F_(int gue fatigue (R-04) Feedwater inlet thermal (e4-) sleeves are not welded to based nozzles and are not subject alley to aging management review (See audit items 209 and 291).Weld Pressure Nickel- Treated water Graking TAA.- metal lV.A4 7 1-2 A Aging effect entry for o SLC nozzle to boundary based >2702F (int) fatigue fatigue (0-04) component line deleted -safe end weld alloy Cracking managed by BWR (N10) Penetrations Program in following entry of line.Table 3.1.2-2 Reactor Vessel Internals Control rod guide Support for Stainless Treated water Gra-kig= ThAA-etaI

!V.131-14 3-.-.-5 A Aging effect entry for tubes Criterion steel >2709F (int) fatigue fatigue (R-53) component line deleted -o Tubes (a)(1) Cracking managed by BWR equipment Vessel Internals Program in following entry of line.Control rod guide Support for CASS Treated water Graking :-L=AA-meta

!V.3B1--14 3.11-5 A Aging effect entry for tubes Criterion

>482 9 F (int) fatigue fatigue (R-63) component line deleted -o Bases (a)(1) Cracking managed by BWR equipment Vessel Internals Program in following entry of line.Core plate Support for Stainless Treated water GraGkiRg TLAA-metal IV.R1-14 3.-1 5 A Aging effect entry for* Plate, beams Criterion steel >2702F (int) fatigue fatigue (R-63) component line deleted -" Blocks, plugs, (a)(1) Cracking managed by BWR" Alignment equipment Vessel Internals Program in assemblies following entry of line.BVY 06-079 Page 2 of 10 ATTACHMENT 3 LICENSE RENEWAL APPLICATION SUPPLEMENT TLAA TABLE CHANGES, Revision 1 Intended Aging Effect Aging NUREG- Table Component Function Material Environment Requiring Management 1801 Vol. 1 Item Notes Change Description Management Programs 2 Item Core spray lines Flow Stainless Treated water GaGkig T-AA-metnI AVl.R1-14 3.,. 1 5 A Aging effect entry for distribution steel >2 7 0QF (int) fatigue fatigue (R-53) component line deleted -Cracking managed by BWR Vessel Internals Program in following entry of line.Fuel support Support for CASS Treated water GraGkiRg-TLAA-Vetal W.13V 14 3.1-5 A Aging effect entry for pieces Criterion

>4829F (int) fatigue fatigue (R-63) component line deleted -* Orificed supports (a)(1) Cracking managed by BWR* Peripheral equipment Vessel Internals Program in supports following entry of line.Incore dry tubes Pressure Stainless Treated water GaGkiRg- T-AA-6mefa

!BV-1-314 3.4-1.-6 A Aging effect entry for boundary steel >270 2 F (ext) fatigue fatigue (R-3) component line deleted -Cracking managed by BWR Vessel Internals Program in following entry of line.Incore guide tubes Pressure Stainless Treated water GraGkifg--

TI=AA-meta

!V.11-4 4 -.4-3.1.5 A Aging effect entry for boundary steel >2709F (ext) fatigue fatigue (R-R3) component line deleted -Cracking managed by BWR Vessel Internals Program in I_ I_ I_ following entry of line.BVY 06-079 Page 3 of 10 ATTACHMENT 3 LICENSE RENEWAL APPLICATION SUPPLEMENT TLAA TABLE CHANGES, Revision 1 Intended Aging Effect Aging NUREG- Table Component Type Function Material Environment Requiring Management 1801 Vol. 1 Item tes Change Description Management Programs 2 Item Jet pump Floodable Stainless Treated water Graeking-T=AA-meta4 W.131-44 3.41-5 A Aging effect entry for assemblies volume steel >2702F (int) fatigue fatigue P-53) component line deleted -* Risers, riser Cracking managed by BWR braces Vessel Internals Program in* Riser hold down following entry of line.bolts" Mixer barrels and adapters* Restraint brackets, wedges, bolts" Diffusers and tailpipes" Adapter upper rings Jet pump Floodable Nickel- Treated water Gracking -T-=-metal V.1B31-14 3..-5 A Aging effect entry for assemblies volume based >270F (int) fatigue fatigue (R-53) component line deleted -" Hold-down alloy Cracking managed by BWR beams Vessel Internals Program in" Adapter lower following entry of line.ring Jet pump castings Floodable CASS Treated water G=raGkiRg--

TLAA-met W13-14 3.1.4-5 A Aging effect entry for Transition piece volume >482QF (int) fatigue fatigue (R-53) component line deleted -Inlet elbow/ Cracking managed by BWR nozzle Vessel Internals Program in* Mixer flange following entry of line.and flare* Diffuser collar Shroud Floodable Stainless Treated water Gaking- T-LAA-mnetal W.B31-14 344-& A Aging effect entry for volume steel >270QF (int) fatigue fatigue (R-.3) component line deleted -Cracking managed by BWR Vessel Internals Program in following entry of line.BVY 06-079 Page 4 of 10 ATTACHMENT 3 LICENSE RENEWAL APPLICATION SUPPLEMENT TLAA TABLE CHANGES, Revision 1 Intended Aging Effect Aging NUREG- Table Component Type Function Material Environment Requiring Management 1801 Vol. 1 Item Notes Change Description Management Programs 2 Item Shroud support Support for Nickel- Treated water Graekirg-TIAA-metal WP.13-14 3.4-1.-6 A Aging effect entry for" Ring, cylinder, Criterion based >270'F (int) fatigue fatigue (R-W component line deleted -and legs (a)(1) alloy Cracking managed by BWR" Access hole equipment Vessel Internals Program in cover following entry of line.Top guide Support for Stainless Treated water T1AA-metpa V. I4314 3-.11- A Aging effect entry for assembly Criterion steel >2702F (int) fatigue fatigue (R- component line deleted -(a)(1) Cracking managed by BWR equipment Vessel Internals Program in following entry of line.Table 3.1.2-3: Reactor Coolant System Pressure Boundary Detector (CRD) Pressure Stainless Treated water TIAA -mealV.CG 15 3-1.- 3 A Aging effect entry for boundary steel >270°F (int) fatigue fatigue (R-220) component line deleted -Cracking managed by One-Time Inspection Program in previous entry of line.Drive (CRD) Pressure Stainless Treated water G"akb,,- TI-=AA--metal

,,.G, 4_, 3.4.-.3 A Environment for this boundary steel >27o ,.(i,,) fatigue fatigue (R-220) component line changed.CRD drive temperatures maintained below threshold for fatigue. Aging effect entry for component line deleted.BVY 06-079 Page 5 of 10 ATTACHMENT 3 LICENSE RENEWAL APPLICATION SUPPLEMENT TLAA TABLE CHANGES, Revision 1 Intended Aging Effect Aging NUREG- Table Component Type Function Material Environment Requiring Management 1801 Vol. 1 Item Notes Change Description Management Programs 2 Item Pump casing and Pressure CASS Treated water GraG.kig-rJAA -me 4GcI-5 3.-41-3 A Aging effect entry for cover (RR) boundary >482 0 F (int) fatigue fatigue (R-220) component line deleted -Cracking managed by BWR Stress Corrosion Cracking and Inservice Inspection Programs in preceding entry of line.Restrictors (MS) Flow CASS Treated water Gaking- V.C-145 3.1.3 A Aging effect entry for control >482°F (int) fatigue fatigue (R-220) component line deleted -Cracking managed by One-Time Inspection Program in preceding entry of line.Intended Aging Effect Aging NUREG- Table Component Type Function Material Environment Requiring Management 1801 Vol 1 Item Notes Change Description Management Programs 2 Item Table 3.2.2-1: Residual Heat Removal System lreaeAGhanW Pessure Garben T-wateF Metal fatigue V2-32 3.2A-4 G Line deleted. See next line.(shell) bun"da " steel o-,atiue TLA (0)_Heat exchanger Pressure Carbon Treated water Cracking One-Time V.D2-32 3.2.1-1 E New line item.(shell) boundary steel >270°F (int) Inspection (E-10)HetexaW Pssmwe Stainless T-eated-wate Metal-fatigue 3.4 2 G Line deleted -Cracking (tubes) beudaF. steel F- 4 fatigue TLAA (A-6") managed by Water Chemistry Control -BWR augmented by One-Time Inspection in preceding line of table BVY 06-079 Page 6 of 10 ATTACHMENT 3 LICENSE RENEWAL APPLICATION SUPPLEMENT TLAA TABLE CHANGES, Revision 1 Intended Aging Effect Aging NUREG- Table Component Type Inten Material Environment Requiring Management 1801 Vol. T Notes Change Description Management Programs 2 Item PFUe Stailess ig, Metal-fatigue kl3 -,4_4 3.-2 G Line deleted -Cracking (tubes) bu..a.. steel ,0F- (it,) fatigue T-IAA (A-62) managed by Water Chemistry Control -BWR augmented by One-Time Inspection in preceding line of table Pump-casing Gabre, 1reatedwateF G.r~askg-Metal-fatigue YV 7 2.32 .2. A Line deleted. See next line.bu.da.ry steel -n= fatigue TA (E___Pump casing Pressure Carbon Treated water Cracking One-Time V.D2-32 3.2.1-1 E New line item.boundary steel >270°F (int) Inspection (E-10)Table 3.2.2-4: High Pressure Coolant Injection System IbiResasing PFessU-e GaFI:e Steam 27-02P CGrak!Rig-Metalfatigue V 2-5 3.-4 G Line deleted. See next line.beuqday steel j fatigue 3:1=AA (&-W8)Turbine casing Pressure Carbon Steam > 27001 Cracking One-Time VIII.B2-5 3.4.1-1 E New line item.boundary steel (int) Inspection (S-08)Table 3.2.2-5: Reactor Core Isolation Coolingcasing PressuFe (Garb.n Stoam -> 220F Graking, Metal-fatigue 3-.41-4 G Line deleted. See next line.h___ b.uedaý, steel (4 fatigue T-AA (&-W8)Turbine casing Pressure Carbon Steam > 220°F Cracking One-Time VIII.B2-5 3.4.1-1 E New line item.boundary steel (int) Inspection (S-08)3.3.2-13-36:

Reactor Water Clean-Up System HeateXehane P ,essuro Stainless Teated-water g Metal-fatigue VI.,3.,4 343.1-2 G Line deleted -Cracking (shell) b.u..day Steel >

fatigue T-I (A-62) managed by Water Chemistry Control -BWR augmented by One-Time Inspection in preceding line of table BVY 06-079 Page 7 of 10 ATTACHMENT 3 LICENSE RENEWAL APPLICATION SUPPLEMENT TLAA TABLE CHANGES, Revision 1 Intended Aging Effect Aging NUREG- Table Component Type Function Material Environment Requiring Management 1801 Vol. 1 Item Notes Change Description Management Programs 2 Item Pump Ga g P~esee Stainless Treated.wa.e.

G.a.k.ng-Metal- atie V1k.9-14 3.-_1--2 A Line deleted -Cracking bouIdaFy steel > 2700F. ,,n, fatigue T-IAA (A-62) managed by Water Chemistry Control -BWR augmented by One-Time Inspection in preceding line of table Praessure Stainless 6 Featedwate Ga.L4,n_-

Metalfati.ue V-,..-44 3..1-2 A Line deleted -Cracking be,,.da.y steel > 270OF (i,) fatkue :T-IAA (A-62-) managed by Water Chemistry Control -BWR augmented by One-Time Inspection in preceding line of table 3.4.2-1: Main Condenser and MSIV Leakage Pathway Heat-exGhanWe (tuAbes)Line deleted -Cracking managed by Water Chemistry Control -BWR augmented by One-Time Inspection in preceding line of table BVY 06-079 Page 8 of 10 ATTACHMENT 3 LICENSE RENEWAL APPLICATION SUPPLEMENT TLAA TABLE CHANGES, Revision 1 Table 3.2.1: Engineered Safety Features, NUREG-1801 Vol. 1 Further Item Component Aging Efech Aging Management Evaluation Discussion Change Description Number Mechanism Programs Reomnd Recommended 3.2.1-1 Steel and stainless Cumulative fatigue TLAA, evaluated in Yes, TLAA Fatigue is a TLAA for Discussion modified as steel piping, piping damage accordance with 10 most components.

shown components, and CFR 54.21(c) The One-Time piping elements in Inspection Program emergency core manages cracking for cooling system components susceptible to fatigue with no TLAA.See Section 3.2.2.2.1.

Section 3.2.2.2.1 is revised as follows: 3.2.2.2.1 Cumulative Fatigue Damage Where identified as an aging effect requiring management for components designed to ASME Code requirements, the analysis of fatigue is a TLAA as defined in 10 CFR 54.3. TLAAs are evaluated in accordance with 10 CFR 54.21(c).

Evaluation of this TLAA is addressed in Section 4.3.Where fatigue damage is identified as an aging effect requiring management for components with no fatigue design requirements, the aging effect is managed by inspection.

The One-Time Inspection program will manage cracking due to fatigue for these components.

BVY 06-079 Page 9 of 10 ATTACHMENT 3 LICENSE RENEWAL APPLICATION SUPPLEMENT TLAA TABLE CHANGES, Revision 1 Table 3.4.1: Steam and Power Conversion Systems, NUREG-1801 Vol. 1 Further Item Aging Effect/ Aging Management Fute Item Component A ec t aname Evaluation Discussion Change Description Number Cm netMechanism Programs Reomnd Recommended 3.4.1-1 Steel piping, piping Cumulative fatigue TLAA, evaluated in Yes, TLAA Fatigue is a TLAA for Discussion modified as components, and damage accordance with 10 most components.

shown piping elements CFR 54.21(c) The One-Time exposed to steam Inspection Program or treated water manages cracking for components susceptible to fatigue with no TLAA.See Section 3.4.2.2.1.

Section 3.4.2.2.1 is revised as follows: 3.4.2.2.1 Cumulative Fatigue Damage 11 Where identified as an aging effect requiring management for components designed to ASME Code requirements, the analysis of fatigue is a TLAA as defined in 10 CFR 54.3. TLAAs are evaluated in accordance with 10 CFR 54.21(c).

Evaluation of this TLAA is addressed in Section 4.3.Where fatigue damage is identified as an aging effect requiring management for components with no fatigue design requirements, the aging effect is managed by inspection.

The One-Time Inspection program will manage cracking due to fatigue for these components.

BVY 06-079 Page 10 of 10