NL-12-089, Official Exhibit - ENT000554-00-BD01 - NL-12-089, Letter from F. Dacimo, Entergy, to NRC, Reply to Request for Additional Information Regarding the License Renewal Application Indian Point Nuclear Generating Unit Nos. 2 & 3 .

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Official Exhibit - ENT000554-00-BD01 - NL-12-089, Letter from F. Dacimo, Entergy, to NRC, Reply to Request for Additional Information Regarding the License Renewal Application Indian Point Nuclear Generating Unit Nos. 2 & 3 .
ML12340A735
Person / Time
Site: Indian Point  Entergy icon.png
Issue date: 08/20/2012
From:
Entergy Nuclear Northeast, Entergy Nuclear Operations
To:
Document Control Desk, Office of Nuclear Reactor Regulation
SECY RAS
References
RAS 23331, 50-247-LR, 50-286-LR, ASLBP 07-858-03-LR-BD01, NL-12-089
Download: ML12340A735 (41)
v • d • e


Text

United States Nuclear Regulatory Commission Official Hearing Exhibit Entergy Nuclear Operations, Inc.

In the Matter of:

(Indian Point Nuclear Generating Units 2 and 3)

",,~P.REGV~.,. ASLBP #: 07-858-03-LR-BD01 l~\

Docket #: 05000247 l 05000286

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< 0 Exhibit #: ENT000554-00-BD01 Identified: 10/15/2012

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Admitted: 10/15/2012 Withdrawn:

ca. '!/ i ENT000554 Rejected: Stricken:

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" .. *** .. .. 0' Other: Submitted: August 20, 2012 Enteray Nuclear Northeast Indian Point Energy Center

~Entergx 450 Broadway, GSB P.O. Box 249 Buchanan, NY 10511-0249 Tel (914) 254-2055 Fred Dacimo Vice President Operations License Renewal NL-12-089 June 14, 2012 U.S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20555-0001

SUBJECT:

Reply to Request for Additional Information Regarding the License Renewal Application Indian Point Nuclear Generating Unit Nos. 2 & 3 Docket Nos. 50-247 and 50-286 License Nos. DPR-26 and DPR-64

REFERENCE:

1. NRC Letter, "Request for Additional Information for the Review of the Indian Point Nuclear Generating Unit Nos. 2 and 3, License Renewal Application," dated May 15, 2012 .

Dear Sir or Madam:

Entergy Nuclear Operations, Inc is providing, in Attachment 1, a reply to the additional information requested in the referenced letter pertaining to NRC review of the License Renewal Application (LRA) for Indian Point 2 and Indian Point 3. The reply provided in this transmittal addresses questions on LRA Amendment NO.9 and the Reactor Vessel Internals (RVI)

Program .

  • As an initial matter, with regard to the RAls on the RVI Program, Entergy notes that Indian Point is in a unique position with respect to the timing and implementation of the generic industry guidance for reactor vessel internals aging management (MRP-227-A). The Electric Power Research Institute (EPRI) just issued the NRC-approved version of MRP-227-A in January of this year, and the industry is working, through EPRI and the Pressurized Water Reactor Owners' Group (PWROG), to develop guidance on the required plant-specific evaluations for submittal to the NRC, including evaluations referenced in the RAls. As a result of Indian Point's unique position, however, Entergy must prepare the requested evaluations in advance of this guidance which will require additional time beyond the requested 30-day response period.

Nevertheless, in this letter Entergy provides responses to RAls 1-5, 8, and 12. Entergy will develop the required evaluations and submit responses to the remaining RAls by 09/28/2012.

Attachment 2 provides the latest list of regulatory commitments including the commitment made in response to RAI 11 in this letter.

If you have any questions, or require additional information, please contact Mr. Robert Walpole at 914-254-6710.

Docket Nos. 50-247 & 50-286 NL-12-089 Page 2 of 2 I declare under penalty of perjury that the foregoing is true and correct. Executed on

.ficn<c lif, 1-1) I z, .

Sincerely, I~ ~ w.j .,4" hut /)ae.~.

FRD/rw

Attachment:

1. Reply to NRC Request for Additional Information Regarding the License Renewal Application
2. License Renewal Application IPEC List of Regulatory Commitments Revision 18.

cc: Mr. William Dean, Regional Administrator, NRC Region I Mr. Sherwin E. Turk, NRC Office of General Counsel, Special Counsel Mr. Dave Wrona, NRC Branch Chief, Engineering Review Branch I Mr. Robert F. Kuntz, NRC Sr. Project Manager, Division of License Renewal Mr. Douglas Pickett, NRR Senior Project Manager Ms. Bridget Frymire, New York State Department of Public Service NRC Resident Inspector's Office Mr. Francis J. Murray, Jr., President and CEO NYSERDA

ATTACHMENT 1 TO NL-12-089 REPLY TO NRC REQUEST FOR ADDITIONAL INFORMATION REGARDING THE LICENSE RENEWAL APPLICATION ENTERGY NUCLEAR OPERATIONS, INC.

INDIAN POINT NUCLEAR GENERATING UNIT NOS. 2 & 3 DOCKET NOS. 50-247 AND 50-286

NL-12-089 Attachment 1 .

Page 1 of 19 INDIAN POINT NUCLEAR GENERATING UNIT NOS. 2 AND 3 LICENSE RENEWAL APPLICATION (LRA)

REQUESTS FOR ADDITIONAL INFORMATION (RAI)

NRC RAI's Related to License Renewal Application Amendment No.9 (Ref. 1)

On page 3 of license renewal application (LRA) Amendment 9 (Ref. 1), it is stated that Table 2.3.1-2-IP2 and Table 2.3.1-2-IP3 list the mechanical components subject to aging management review and component intended functions for the reactor vessel internals. However, Table 2.3.1-2-IP3 (the table for Indian Point Nuclear Generating Unit No.3 (IP3>>, is missing, and the table for Indian Point Nuclear Generating Unit No.2 (IP2) listing the components subject to aging management review is numbered Table 2.3.1-4-IP2. Provide Table 2.3.1-2-IP3 and correct the numbering of the table for IP2.

Response to RAI 1 Table 2.3.1.4-IP2 was numbered incorrectly in Amendment 9 and should have been identified as Table 2.3.1-2-IP2. Table 2.3.1-2-IP3 was inadvertently omitted from the Amendment 9 submittal; however it would have been the same as Table 2.3.1-2-1 P2. Tables 2.3.1-2-1 P2 and 2.3.1-2-1 P3 are presented below as they should have appeared in Amendment 9.

NL-12-089 Attachment 1 Page 2 of 19 Table 2.3.1-,6-IP2 Reactor Vessel Internals Components Subject to Aging Management Review Component Type Intended Function

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Low;; Core Sitpporl Structure ..

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Core baffle/former assembly Structural support

  • bolts Core baffle/former assembly Structural support
  • plates Flow distribution Shielding Core barrel assembly Structural support
  • bolts and screws Core barrel assembly Structural support
  • axial flexure plates (thermal shield flexures)

Core barrel assembly Structural support

  • flange Core barrel assembly Structural support
  • ring Flow distribution
  • shell
  • thermal shield Shielding Core barrel assembly Structural support
  • upper core barrel flange weld Core barrel assembly Flow distribution
  • outlet nozzles Lower internals assembly Structural support o clevis insert bolt
  • fuel alignment pin
  • lower core support plate column sleeves
  • lower core support plate column bolt
  • radial key

NL-12-089 Attachment 1 Page 3 of 19 Table 2.3.1-~-IP2 Reactor Vessel Internals Components Subject to Aging Management Review Component Type Intended Function Lower internals assembly Flow distribution

  • intermediate diffuser plate Lower internals assembly Structural support
  • lower core plate Flow distribution
  • lower core support castings
  • column cap
  • lower core support
  • secondary core support

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Upper Core Support Stn,lcture-Upper InternalsAssembly

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RCCA guide tube assembly Structural support

  • bolt RCCA guide tube assembly Structural support
  • guide tube (including lower flange welds)

RCCA guide tube assembly Structural support

  • guide plates RCCA guide tube assembly Structural support
  • support pin Core plate alignment pin Structural support Head I vessel alignment pin Structural support Hold-down spring Structural support Mixing devices Structural support
  • support column orifice base Flow distribution
  • support column mixer Support column Structural support Upper core plate, fuel alignment Structural support pin Flow distribution

NL-12-089 Attachment 1 Page 4 of 19 Table 2.3.1-£-IP2 Reactor Vessel Internals Components Subject to Aging Management Review Component Type Intended Function Upper support plate, support Structural support assembly (including ring)

Upper support column bolt Structural support

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1ilco~e Instrwnentaiionf/ulicp6rt Striitiilte

.. :Y.h>',' ,:'.". : " * <~ .~~':Y' Bottom mounted instrumentation Structural support column Flux thimble guide tube Structural support Thermocouple conduit Structural support

NL-12-089 Attachment 1 Page 5 of 19 Table 2.3.1-2-IP3 Reactor Vessel Internals Components Subject to Aging Management Review Component Type Intended Function

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~wer Core Support Structure .',: \<;1'c f 0! ,.'

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Care baffle/farmer assembly Structural support

  • bolts Care baffle/farmer assembly Structural support
  • plates Flaw distribution Shielding Care barrel assembly Structural support
  • bolts and screws Gare sarrel assefFIsly Strlolstlolral slolppeFt
  • l3*ial flexloIFe plates Flow distrisloltion
  • flango

~ Shielding

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  • therfFIal shield Care barrel assembl~ Structural suggort
  • axial flexure glates (thermal shield flexures}

Care barrel assembl~ Structural suggort

  • flange Care barrel assembl~ Structural suggort
  • ring Flaw distribution
  • shell
  • thermal shield Shielding Care barrel assembl~ Structural suggort
  • ugger core barrel flange weld Care barrel assembly Flow distribution
  • outlet nozzles

NL-12-089 Attachment 1 Page 6 of 19 Table 2.3.1-2-IP3 Reactor Vessel Internals Components Subject to Aging Management Review Component Type Intended Function

-

Lower internals assembly Structural support

  • fuel alignment pin
  • lower core support plate column bolt
  • lower core support plate column sleeves
  • radial key Lower internals assembly Flow distribution
  • intermediate diffuser plate Lower internals assembly Structural support
  • lower core plate Flow distribution G lower core support castings
  • column cap
  • lower core support
  • secondary core support

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Upper COfiSllp~?tr SlruCiiife~Uppe'Jn~ernals Assempl! f:<.' :'4}2:;; .. ., ".. ' .

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  • gl:lide tl:lbe
  • SI:lf3f3eFt f3iR RCCA guide tube assembl~ Structural SUI2I20rt
  • bolt RCCA guide tube assembl~ Structural SUI2I20rt
  • guide tube (including lower flange welds}

RCCA guide tube assembl~ Structural SUI2I20rt

  • guide I2lates RCCA guide tube assembl~ Structural SUI2I20rt
  • SUI2I20rt l2in Core plate alignment pin Structural support Head / vessel alignment pin Structural support

NL-12-089 Attachment 1 Page 7 of 19 Table 2.3.1-2-IP3 Reactor Vessel Internals Components SUbject to Aging Management Review Component Type Intended Function Hold-down spring Structural support Mixing devices Structural support

  • support column orifice base Flow distribution
  • support column mixer Support column Structural support Upper core plate, fuel alignment Structural support pin Flow distribution Upper support plate, support Structural support assembly (including ring}

Upper support column bolt Structural support

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IncarJ'ihstrumentation Support Structure

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Bottom mounted instrumentation Structural support column Flux thimble guide tube Structural support Thermocouple conduit Structural support

NL-12-089 Attachment 1 Page 8 of 19 LRA Sections 3.1.2.2.6, 3.1.2.2.9, 3.1.2.2.15, and 3.1.2.2.17, provided in LRA Amendment 9 refer to MRP-227. For consistency with the revised LRA Section B.1.42 submitted by letter dated February 17, 2012, the staff requests that the applicant revise the LRA sections listed above to update the reference to MRP-227-A.

Response to RAI 2 LRA Sections 3.1.2.2.6, 3.1.2.2.9, 3.1.2.2.15, and 3.1.2.2.17 are revised as shown below to update the reference to MRP-227-A. (underline - added) 3.1.2.2.6 Loss of Fracture Toughness due to Neutron Irradiation Embrittlement and Void Swelling Loss of fracture toughness due to neutron irradiation embrittlement and change in dimensions (void swelling) in stainless steel and nickel alloy reactor vessel internals components exposed to reactor coolant and neutron flux will be managed by the Reactor Vessel Internals (RVI) Program. The RVI Program will implement the EPRI Pressurized Water Reactor Internals Inspection and Evaluation Guidelines, MRP-227-A. The RVI Program will use nondestructive examinations (NDE) and other inspection methods to manage aging effects for reactor vessel internals.

3.1.2.2.9 Loss of Preload due to Stress Relaxation Loss of preload due to thermal stress relaxation (creep) would only be a concern in very high temperature applications (> 700°F) as stated in the ASME Code,Section II, Part D, Table 4. No IPEC internals components operate at > 700°F. Therefore, loss of preload due to thermal stress relaxation (creep) is not an applicable aging effect for the reactor vessel internals components. However, irradiation-enhanced creep (irradiation creep) or irradiation enhanced stress relaxation (ISR) is an athermal process that depends on the neutron fluence and stress; and, on void swelling if present. Therefore, loss of preload of stainless steel and nickel alloy reactor vessel internals components will be managed by the Reactor Vessel Internals (RVI) Program. The RVI Program will implement the EPRI Pressurized Water Reactor Internals Inspection and Evaluation Guidelines, MRP-227-A. The RVI Program will use nondestructive examinations (NDE) and other inspection methods to manage aging effects for reactor vessel internals.

3.1.2.2.15 Changes in Dimensions due to Void Swelling Changes in dimensions due to void swelling in stainless steel and nickel alloy reactor internal components exposed to reactor coolant will be managed by the Reactor Vessel Internals (RVI) Program. The RVI Program will implement the EPRI Pressurized Water Reactor Internals Inspection and Evaluation Guidelines, MRP-227-A. The RVI Program will use nondestructive examinations (NDE) and other inspection methods to manage aging effects for reactor vessel internals.

NL-12-089 Attachment 1 Page 9 of 19 3.1.2.2.17 Cracking due to Stress Corrosion Cracking, Primary Water Stress Corrosion Cracking, and Irradiation-Assisted Stress Corrosion Cracking Cracking due to stress corrosion cracking (SCC), primary water stress corrosion cracking (PWSCC), and irradiation-assisted stress corrosion cracking (IASCC) in PWR stainless steel and nickel alloy reactor vessel internals components will be managed by the Reactor Vessel Internals (RVI) Program. The RVI Program will implement the EPRI Pressurized Water Reactor Internals Inspection and Evaluation Guidelines, MRP-227-A. The RVI Program will use nondestructive examinations (NDE) and other inspection methods to manage aging effects for reactor vessel internals.

The applicant addressed the further evaluation criteria in Section 3.1.2.2.12 of NU REG-1800, "Standard Review Plan for Review of License Renewal Applications for Nuclear Power Plants,"

Rev. 1 (SRP-LR) by stating (in the "Discussion" column of Table 3.1.1 Item 3.1.1-30) that cracking will be managed by the Water Chemistry Control Program (Primary and Secondary) and either the Reactor Vessel Internals (RVI) Program or the Inservice Inspection (lSI) Program.

Crediting the lSI Program for managing cracking is inconsistent with LRA Tables 3.1.2-2-IP2 and 3.1.2-2-IP3, in which the components aligned with Table 3.1.1 Item 3.1.1-30 only credit the Water Chemistry Control - Primary and Secondary Program and the RVI Program for aging management. Further, LRA Amendment 9 does not include a revised LRA Section 3.1.2.2.12. In addition, the use of the Inservice Inspection Program (lSI) Aging Management Program (AMP) is not consistent with the NUREG-1801, "Generic Aging Lessons Learned Report", Revision 1 (GALL Report, Rev. 1), Table 1, Item 30 for this line item or the recommendations of SRP-LR Section 3.1.2.2.12.

The staff therefore requests the following information:

1. Correct the inconsistency between Table 3.1.1 Item 3.1.1-30 and the associated line items in Tables 3.1.2-2-IP2 and 3.1.2-2-:P3.
2. Provide a markup to LRA Section 3.1.2.2.12 consistent with the changes in LRA Table 3.1.1 provided in LRA Amendment 9.
3. If the lSI Program is being used as the AMP to manage cracking for certain RVI components aligned with Table 3.1.1 Item 3.1.1-30, justify the use of the lSI Program rather than the RVI Program for managing aging of the affected components, and mal<e all the necessary conforming changes to Table 3.1.1, Table 3.1.2-2-IP2, and Table 3.1.2-2-IP3.

Response to RAI 3

1. There is no inconsistency between Table 3.1.1 Item 3.1.1-30 and the associated line items in Tables 3.1.2-2-IP2 and 3.1.2-2-IP3. In Tables 3.1.2-2-IP2 and 3.1.2-2-IP3, cracking for the "Upper support plate, support assembly (including ring)" is managed by the Water Chemistry Control - Primary and Secondary and Inservice Inspection Programs. This item is compared to NUREG-1801, Rev. 1, Volume 2 Item IV.B2-42, and aligned to Table 1 Item 3.1.1-30. Therefore, the RAI statement that "the components aligned with Table 3.1.1 Item 3.1.1-30 only credit the Water Chemistry Control - Primary and Secondary Program and the RVI Program," is incorrect.

NL-12-089 Attachment 1 Page 10 of 19

2. LRA Section 3.1.2.2.12 was revised by Letter NL-11-1 01, dated August 22, 2011, to correct the omission of the section from Amendment 9. LRA Section 3.1.2.2.12, as revised by NL-11-101 is shown below. Additional revisions are shown, with strikethrough for deletion and underline for additions, to provide clarification on the use of the Inservice Inspection Program, and the updated reference to MRP-227-A.

3.1.2.2.12 Cracking due to Stress Corrosion Cracking and Irradiation-Assisted Stress Corrosion Cracking (IASCC)

Cracking due to SCC and IASCC in PWR stainless steel reactor internals exposed to reactor coolant will be managed by the Water Chemistry Control - Primary and Secondary Program and the Reactor Vessel Internals (RVI) or Inservice Inspection (lSI) Programs. The RVI Program will implement the EPRI Pressurized Water Reactor Internals Inspection and Evaluation Guidelines, MRP-227-A. The RVI Program will use nondestructive examinations (NDE) and other inspection methods to manage aging effects for reactor vessel internals. The RVI Program includes inspections of core support structures using the existing ASME Section XI, lSI Program as delineated in MRP-227-A, Table 4-9. Where credited for the management of cracking, the existing lSI Program is listed in Tables 3.1.2-2-IP2 and 3.1.2-2-IP3 in lieu of the RVI Program.

3. In Tables 3.1.2-2-IP2 and 3.1.2-2-IP3, cracking for the "Upper support plate, support assembly (including ring)" is managed by the Water Chemistry Control- Primary and Secondary and Inservice Inspection Programs. This item is compared to NUREG-1801, Rev. 1, Volume 2 Item IV.B2-42, and aligned to Table 1 Item 3.1.1-30. This item corresponds to the matching entry in MRP-227-A, Table 4-9, Westinghouse Plants Existing Programs Components. Consistent with MRP-227-A, the lSI program is the "existing program" credited to manage cracking for this item. No other changes are required.

RAl's Related to Reactor Vessel Internals Program NUREG-1801, "Generic Aging Lessons Learned Report," Revision 2 (GALL Report, Rev. 2),

Section XI.M16A, recommends, under the "Monitoring and Trending" program element, using the methods of the latest Nuclear Regulatory Commission (NRC)-approved version of Materials Reliability Program: Pressurized Water Reactor Internals Inspection and Evaluation Guidelines MRP-227, Section 6 for monitoring, recording, evaluating and trending the data from the program inspection results. MRP-227 Section 6 includes recommendations for flaw depth sizing and crack growth determinations as well as for performing applicable limit load, linear elastic and elastic-plastic fracture analyses of relevant flaw indications.

However, in the staff's final safety evaluation (SE) on MRP-227, Revision 0 (Ref. 2), the staff noted that in a request for additional information (RAI) response, Electric Power Research Institute (EPRI) stated that topical report WCAP-17096-NP is the document that will be used as the framework to develop those generic and plant-specific evaluations triggered by findings in the RVI examinations, and observed that the NRC staff is currently reviewing WCAP-17096-NP.

Revision 2. Therefore, the staff requests that the applicant clarify whether the Indian Point Energy Center (IPEC) RVI Program will use the guidance of WCAP-17096-NP, Rev. 2 (Ref. 3) for evaluating the acceptability of relevant conditions found by the inspections conducted under the RVllnspection Plan.

NL-12-089 Attachment 1 Page 11 of 19 Response to RAI 4 The IPEC RVI Program plans to use the guidance of WCAP-17096-NP, Rev. 2 for evaluating the acceptability of relevant conditions found by the inspections conducted under the RVI Inspection Plan.

For baffle-former bolts, MRP-227-A, Table 5-3 states that the examination acceptance criteria for the ultrasonic test (UT) shall be established as part of the examination technical justification.

"Materials Reliability Program: Inspection Standard for PWR Internals," (MRP-228)(Ref. 4) provides additional guidance on preparation of technical justifications (TJs). However, the IPEC RVI Program does not indicate whether a T J has been or will be developed for the baffle-former bolts. Therefore, the staff requests the applicant submit a T J for the IP2 and IP3 baffle-former bolts.

Response to RAI 5 MRP-227-A and its associated safety evaluation contain no requirement for the submittal of a technical justification for these inspections with the application to implement MRP-227-A.

Baffle-former bolt inspections are not required to be performed until between 25 and 35 EFPY.

Currently both IPEC units are at less than 28 EFPY. Therefore, inspections are required prior to 2019 at IP2 and 2021 at IP3. As a result, IPEC has not yet finalized the inspection schedule and has not yet selected the vendor to perform the inspections. Since the technical justification will be prepared by the vendor selected to perform the inspections, a technical justification has not yet been prepared for IPEC. A technical justification is planned to be developed for the baffle-former bolts when the inspection vendor is selected but no later than 6 months prior to the beginning of the outage when the inspections will be performed.

RAI's Related to Reactor Vessel Internals Inspection Plan (Ref. 6)

Applicant/Licensee Action Item 1 from the staff's final SE on MRP-227, Revision 0 requires that applicants/licensees submit an evaluation that demonstrates that their plant is bounded by the assumptions regarding plant design and operating history that were made in the failure modes, effects and consequences analyses (FMECA) and functionality analyses for reactors of their design.

The applicant's response to Applicant/Licensee Action Item 1 in the RVI inspection plan addresses the core loading assumptions (switch to a low-leakage core) and operational (base loaded plant) aspects of design and operation that are mentioned in MRP-227-A, Section 2.4.

An additional assumption listed in Section 2.4 of MRP-227-A is that there have been no design changes to the RVI beyond those identified in general industry guidance or recommended by the original vendors. Section 2.4 of MRP-227-A indicated that these assumptions are considered to conservatively represent any U.S. Pressurized Water Reactor operating plant provided that these three assumptions are met, given the information on design and operation known to the MRP as of May 2007.

MRP-191, Revision 0, "Materials Reliability Program: Screening, Categorization and Ranking of Reactor Internals of Westinghouse and Combustion Engineering PWR Designs," documents the

NL-12-089 Attachment 1 Page 12 of 19 screening for susceptibility to aging effects, the FMECA results, and the categorization and ranking of the RVI components. In addition to the assumptions listed in Section 2.4 of MRP-227-A, MRP-191 documents additional assumptions that were used. In particular, neutron fluence range, temperature, and material grade for each generic component of the Westinghouse design internals were used for input to the screening process. These values were determined based on an "expert elicitation" process. Stress values were not explicitly tabulated, but were recorded as either above the stress threshold (>30 ksi) or not based on the expert interviews.

MRP-232, Revision 0, "Materials Reliability Program: Aging Management Strategies for Westinghouse and Combustion Engineering PWR Internals," reported more specific stress, temperature and neutron fluence values based on finite element analyses for selected high consequence of failure components identified in MRP-191.

MRP-227 -A did not verify that the values of fluence, temperature, stress, and material, documented in MRP-191 and MRP-232 were bounding for all individual plants, and in fact MRP-227-A states, "These evaluations were based on representative configurations and operational histories, which were generally conservative, but not necessarily bounding in every parameter."

Each plant should have access to design information enabling verification that the material for each RVI component is bounded by the design assumptions of the MRP. In this context, the staff requests the following information:

1 ) To provide reasonable assurance that the RVI components are bounded by assumptions in the FMECA and functionality analyses supporting the development of MRP-227-A, the applicant is requested to respond to either 2.a or 2.b of this RAI:

2.a) 2 Provide the plant-specific values of neutron fluence (n/cm , E> 1.0 MeV), temperature, stress, and materials for a sample of RVI components. The components selected should represent a range of neutron fluences, and temperatures. This information should identify whether the stress is greater or less than 30 ksi. Values of neutron fluence and temperature may be estimated or analytical values. The values should be the peak values of each parameter for each component (e.g., peak end-of-life value for fluence). Provide the method used to estimate the values, or describe the analysis method. An acceptable sample of components is:

i) Lower Core Plate ii) Core Barrel Flange iii) Barrel-Former Bolts iv) Upper Core Barrel Welds v) Lower Core Barrel Welds vi) Upper Core Plate Alignment Pins 2.b) If the sample verification approach in Part (a) is not used, describe the process used to verify that the RVI components at IP2 and IP3 are bounded by the assumptions regarding the neutron fluence, temperature, stress values, and materials that were made for each component in the FMECA and functionality analyses supporting the development of MRP-227-A.

3) If there are any components at IP2 or IP3 not bounded by assumptions regarding neutron fluence, temperature, stress or material used in the development of MRP-227-A, describe

NL-12-089 Attachment 1 Page 13 of 19 how the differences were addressed in the plant-specific RVllnspection Plan. The staff requests that the applicant, as a part of its demonstration, discuss whether there would be any changes to the screening, categorization, FMECA process and functionality analyses if the plant-specific variables (the neutron fluence, temperature, stress values, plant-specific operating experience, and materials) are used. This evaluation should address whether additional aging mechanisms would become applicable to the component.

4) For any non-bounded components, determine if any changes to the inspection requirements of MRP-227-A are needed. Provide plant-specific inspection requirements or an alternate aging management program, as appropriate. If no changes to the inspection requirements are proposed, provide a justification for the adequacy of the existing MRP-227-A inspections for the unbounded components.
5) Identify all design changes to the IP2 and IP3 RVI, and describe (1) if any of these are beyond those identified in general industry guidance or recommended by the original vendors, and (2) if any of the design changes were implemented after May 2007. Assess the impact of these design changes on the recommendations of the RVI Inspection Plan.

Provide plant-specific inspection requirements if necessary for the affected components.

Response to RAI 6 As noted in the cover letter the response to this RAI requires that additional evaluations be performed. The response will be submitted to the NRC by 09/28/2012.

The staff reviewed the applicant's response to Applicant/Licensee Action Item 2 from the NRC staff's final SE on MRP-227, Revision O. In Section 3.6 of the RVllnspection Plan (Ref. 5), the applicant stated that it reviewed the information in Table 4-4 of MRP-191 and determined that this table contains all the RVI components that are within the scope of license renewal and that this is shown in Table 5-7. The staff notes that Table 5-1 contains a cross-index between the component designations in Entergy Letter NL-10-063 (Amendment 9 to the LRA, Ref. 1) and the component names as designated in MRP-191, Table 4-4 (Ref. 6). All the IPEC component designations correlate with an equivalent component designation in MRP-191 (Ref. 7), Table 44 with the exception of the Lower Internals Assembly - Column Cap.

The staff therefore requests that the applicant verify that the Lower Internals Assembly - Column Cap would be subject to the same inspection requirements that are applied to the lower support assembly, lower support column bodies (cast) in MRP-227-A, Table 4-6. If not, provide plant-specific aging management requirements for the Lower Internals Assembly - Column Cap.

Response to RAI 7 As noted in the cover letter the response to this RAI requires that additional evaluations be performed. The response will be submitted to the NRC by 09/28/2012.

The staff requests the following information related to the applicant's response to Applicant/Licensee Action Item 3 from the NRC staffs final SE on MRP-227, Revision O.

NL-12-089 Attachment 1 Page 14 of 19

1. Provide more detail on the operating experience for cold-worked type 316 split pins to support the prediction that split pins of this material will last until the end of the period of extended operation (PEO) for IP3.
2. Describe the inspection schedule, methods, and basis for replacement split pins at IP3.

If no inspections are planned, provide a justification for no"( inspecting the split pins.

3. Describe the criteria for the replacement split pin material and design for IP2.
4. Describe the inspection strategy for the replacement IP2 split pins during the PEO.

Response to RAI 8 1: Cold-worked type 316 split pins have been installed at other nuclear power plants since 1997. No plants have experienced failures of cold-worked type 316 split pins to date.

2: No inspections are planned for the split pins at IP3. However, based on industry operating experience, if failures of cold-worked type 316 split pins occur, an IP3 plant specific evaluation will be performed at that time to determine if inspections are required.

Since the IP3 split pins were replaced in 2009 and other plants have installed cold-worked type 316 split pins starting in 1997, failure of other plant split pins would be expected before potential failures at IP3. Any failure would be evaluated by IP3 to determine the need for an inspection and other actions. No plants have experienced any failures of cold-worked type 316 split pins to date.

3: I P2 plans to use the same replacement split pin material and design that was used for IP3. IP2 plans to use cold-worked type 316 split pins.

4: The inspection strategy for the replacement IP2 split pins during the PEO will be the same as the IP3 inspection strategy. No inspections are planned for the replacement IP2 split pins. However, based on industry operating experience, if failures of cold-worked type 316 split pins occur, an IP2 plant specific evaluation will be performed at that time to determine if inspections are warranted.

The applicant's response to Applicant/Licensee Action Item 5 from Revision 1 of the staff's final SE on MRP-227, states in part that the acceptance criteria will ensure the remaining compressible height of the spring shall provide hold down forces within the IPEC design tolerance. If a plant specific acceptance criterion is not developed for the hold down spring, IPEC will replace the spring in lieu of performing the first required physical measurement.

MRP-227-A, Table 4-3, calls for direct measurement of the hold-down spring height within three cycles of the beginning of the license renewal period. If the first set of measurements is not sufficient to determine life, spring height measurements must be taken during the next two outages, in order to extrapolate the expected spring height to 60 years.

The staff requires clarification of how the applicant will determine whether the first set of measurements could be extrapolated to demonstrate acceptable spring functionality through 60 years. Therefore, the staff requests the following information:

NL-12-089 Attachment 1 Page 15 of 19

1. Provide the specific acceptance criteria for spring height andlor hold down force from the IP211P31icensing basis.
2. Describe the procedure by which the remaining hold down forces will be projected to end-of-life based on one measurement. Address whether the decrease in spring height or hold-down force is assumed to occur linearly over time or via some other function of time.
3. What results of the first spring measurements would indicate a need for successive measurements?

Response to RAI 9 As noted in the cover letter the response to this RAI requires that additional evaluations be performed. The response will be submitted to the NRC by 09/28/2012.

RAI10 The applicant's response to Applicant/Licensee Action Item 7 indicates that the plant-specific analysis to demonstrate functionality of the lower support column bodies during the period of extended operation will be submitted to the NRC prior to the PE~. In the aging management review tables submitted in LRA Amendment 9, the applicant credits the "Thermal Aging and Neutron Irradiation Embrittlement of Cast Austenitic Stainless Steel (CASS) Program" for managing loss of fracture toughness of the lower core support column bodies, as well as several other CASS components. NUREG-1930 indicates that the staff determined this program was consistent with the Generic Aging Lessons Learned Report, Revision 1, Aging Management Program (AMP) XI,M13, "Thermal Aging and Neutron Irradiation Embrittlement of Cast Austenitic Stainless Steel (CASS) Program." Per GALL, Rev. 1,Section XI,M13, the "Thermal Aging and Neutron Irradiation Embrittlement of CASS Program" generally requires supplemental visual inspections (equivalent to an EVT-1) for CASS RVI components that are either susceptible to thermal aging based on chemistry and other manufacturing parameters, or receive a neutron fluence;;:: 1x1017 n/cm 2 , unless it can be demonstrated that the stresses on the component are either compressive or low in magnitude if tensile. The RVI Program is credited with managing cracking of the core support column bodies and other CASS components. Under the RVI Program, the core support column bodies are expansion components that would be subject to an EVT-1 visual examination for cracking due to irradiation assisted stress corrosion cracking if cracking were found in the associated primary component.

The staff requests the following information:

Since both the plant-specific analysis and Thermal Aging and Neutron Irradiation Embrittlement of CASS Program could both potentially involve screening for thermal or neutron irradiation embrittlement, stress analyses, and flaw tolerance evaluations, and both the RVI Program and Thermal Aging and Neutron Irradiation Embrittlement of CASS Program could potentially require inspections, discuss the relationship of the two programs and the plant-specific analysis.

Response to RAI 10 As noted in the cover letter the response to this RAI requires that additional evaluations be performed. The response will be submitted to the NRC by 09/28/2012.

NL-12-089 Attachment 1 Page 16 of 19 RAI11 In response to Applicant/Licensee Action Item 7, the applicant stated that the plant-specific analyses to demonstrate the lower support column bodies will maintain their functionality during the period of extended operation will consider the possible loss of fracture toughness in these components due to thermal and irradiation embrittlement. The analyses will be consistent with the IP2/1 P3 licensing basis and the need to maintain the functionality of the lower support column bodies under all licensing basis conditions of operations.

The staff requests the following additional information:

1) Section 3.3.7 of Revision 1 of the staff's final SE on MRP-227, Revision 0 lists three possible options for the type of plant-specific analysis used to fulfill the requirements of this action item. The three approaches are 1) functionality analyses of the set of like components, 2) component-specific flaw tolerance evaluations, or 3) a screening approach demonstrating that the CASS Components are not susceptible to thermal embrittlement, neutron embrittlement, or the combined effects of both. Discuss which of these approaches will be used and why.
2) Describe the acceptance criteria for the plant-specific analysis results that are derived from the IP2/1P3 licensing basis.
3) Since the applicant stated that the analysis of the core support columns will be submitted prior to the period of extended operation for IP2 and IP3, the staff requests the applicant submit a letter documenting this as a formal licensing commitment.

Response to RAI 11 As noted in the cover letter the response to this RAI requires that additional evaluations be performed. The response will be submitted to the NRC by 09/28/2012.

Commitment 47 IPEC will perform and submit analyses that demonstrate that the lower support column bodies will maintain their functionality during the period of extended operation considering the possible loss of fracture toughness due- to thermal and irradiation embrittlement. The analyses will be consistent with the IP2/1P31icensing basis and will be submitted prior to the PE~.

RAI12

Background

In its letter dated February 17, 2012, the applicant provided the response to Applicant/Licensee Action Item 8 of the Staff SE of MRP-227-A. The applicant stated that the RVI AMP description has been revised to be consistent with MRP-227-A, and the applicant's response to Applicant/licensee Action Item 8 does not request any deviations from the guidance provided in MRP-227-A. The staff noted that Applicant/Licensee Action Item 8 also addresses cumulative usage factor (CUF) analyses that are time-limited aging analyses (TLAAs).

The applicant's response does not address LRA Section 4.3.1.2, which provides the applicant's TLAA and associated CUF values for the IP2 and IP3 RVI. The staff noted that in Amendment 3

NL-12-089 Attachment 1 Page 17 of 19 to the LRA dated March 24, 2008, (ADAMS Accession No. ML081070255), the applicant amended LRA Section 4.3.1 .2 to state that "fatigue on the reactor vessel internals will be managed by the Fatigue Monitoring Program in accordance with 10 CFR 54.21 (c)(1)(iii) for both IP2 and IP3. "

The staff noted that Applicant/Licensee Action Item 8 indicates that RVI Program may be used as the basis for accepting CUF analyses in accordance with 10 CFR 54.21 (c)(1)(iii) only if the RVI components in the CUF analyses are periodically inspected for fatigue-induced cracking during the period of extended operation. Applicant/Licensee Action Item 8 also indicates that the Fatigue Monitoring Program may be used as the basis for accepting CUF analyses in accordance with 10 CFR 54.21 (c)(1 )(iii), in which case the evaluation requirements of ASME Code Section III, Section NG are to be satisfied.

It is not clear to the staff whether the applicant will use (a) its RVI Program, (b) its Fatigue Monitoring Program, or (c) a combination of both programs to manage RVI fatigue during the period of extended operation.

Request Identify the aging management program that is used to manage fatigue of the reactor vessel internals:

1) If the RVI Program will be used:
a. Verify that each RVI component with a CUF value will be periodically inspected for fatigue-induced cracking during the period of extended operation.
b. For each component to be inspected for fatigue-induced cracking:
i. Identify the examination method(s).

ii. Provide the inspection periodicity, including the initial inspection timing and timing of subsequent examinations.

iii. Justify that the periodicity of the inspections for each RVI component is adequate.

2) If the Fatigue Monitoring Program will be used, verify that the requirements of ASME Code Section Iii, Subsections NG-2160 and NG-3121, as delineated in Applicant/Licensee Action Item 8, will be satisfied.

Response to RAI 12 IPEC will use the RVI Program to manage the effects of aging due to fatigue on the reactor vessel internals. The aging management strategy development described in MRP-227 -A was based on consideration of susceptibility to eight age-related degradation mechanisms. Fatigue was one of the eight degradation mechanisms considered. As provided in Section 3.5.1 of the NRC's safety evaluation for MRP-227-A, for locations with a fatigue time-limited aging analysis, IPEC will manage the effects of aging due to fatigue through the Fatigue Monitoring Program in

NL-12-089 Attachment 1 Page 18 of 19 accordance with 10 CFR 54.21(c)(1)(iii). For locations which do not have a current licensing basis fatigue analysis, IPEC will rely on the inspection requirements of MRP-227-A to manage the effects of aging due to fatigue.

Consistent with 10 CFR 54.21 (c)(1)(iii) and the NRC's safety evaluation for MRP-227-A, the Fatigue Monitoring Program will manage the effects of aging due to fatigue on RVI components with a fatigue time-limited aging analysis. The Fatigue Monitoring Program as described in LRA Section 8.1.12 provides assurance that the CUF remains below the allowable limit of 1.0.

Consistent with Section 3.5.1 of the safety evaluation for MRP-227 -A, prior to entering the period of extended operation the existing RVI fatigue calculations will be reviewed to evaluate the effects of the reactor coolant system water environment on the CUF. Specifically, under Commitment 43, Entergy will review the IPEC design basis ASME Code Class 1 fatigue evaluations to determine whether the NUREG/CR-6260 locations that have been evaluated for the effects of the reactor coolant environment on fatigue usage are the limiting locations for the IP2 and IP3 configurations. This review includes ASME Code Class 1 fatigue evaluations for reactor vessel internals. If more limiting locations are identified, the most limiting location will be evaluated for the effects of the reactor coolant environment on fatigue usage.

References

1. Letter from Fred Dacimo, Entergy, to NRC dated July 14, 2010,

Subject:

Amendment 9 to License Renewal Application (LRA) - Reactor Vessel Internals Program Indian Point Nuclear Generating Unit Nos. 2 & 3, Docket Nos. 50-247 and 50-286 License Nos. DPR-26 and DPR-64 (ADAMS Accession No. ML102010102)

2. Letter from Robert Nelson, NRC, to Neil Wilmshurst, EPRI dated December 16, 2011;

Subject:

Revision 1 of the Final Safety Evaluation of EPRI Report, Materials Reliability Program Report 1016596 (MRP-227), Revision 0, "Pressurized Water Reactor (PWR)

Internals Inspection and Evaluation Guidelines" (TAC No. ME0680) (ADAMS Accession No.

ML11308A770)

3. Reactor Internals Acceptance Criteria Methodology and Data Requirements, WCAP-17096-NP, Rev. 2, Westinghouse Non-Proprietary Class 3 Report, December 2009, ADAMS Accession No. ML1014601570
4. Materials Reliability Program: Inspection Standard for PWR Internals (MRP-228) 1016609 Final Report, July 2009 Electric Power Research Institute, Palo Alto, CA (EPRI Product No.

1016609) (ADAMS Accession No. ML092120573)

5. Indian Point Energy Center Revised Reactor Vessel Internals Inspection Plan Compliant with MRP-227-A. Attachment 2 to Entergy Letter NL-12-037, Letter from Fred Dacimo to NRC dated February 17, 2012,

Subject:

License Renewal Application - Revised Reactor Vessel Internals Program and Inspection Plan Compliant with MRP-227-A, Indian Point Nuclear Generating Unit Nos. 2 and 3, Docket Nos. 50-247 and 50-286-License Nos. DPR-26 and DPR-64 (ADAMS Accession No. ML 1206A312)

6. MRP-191 Revision 0, "Materials Reliability Program: Screening, Categorization and Ranking of Reactor Internals of Westinghouse and Combustion Engineering PWR Designs," ADAMS Accession No. ML091910130

NL-12-089 Attachment 1 Page 19 of 19

7. NUREG-1930, Volume 2, "Safety Evaluation Report Related to The License Renewal of Indian Point Nuclear Generating Unit Nos. 2 and 3, Dockets No. 50-247 and 50-286, November 30, 2009 (ADAMS Accession No. ML093170671)

ATTACHMENT 2 TO NL-12-089 LICENSE RENEWAL APPLICATION IPEC LIST OF REGULATORY COMMITMENTS Rev. 18 ENTERGY NUCLEAR OPERATIONS, INC.

INDIAN POINT NUCLEAR GENERATING UNIT NOS. 2 & 3 DOCKET NOS. 50-247 AND 50-286

NL-12-089 Attachment 2 Page 1 of 18 List of Regulatory Commitments Rev. 18 The following table identifies those actions committed to by Entergy in this document.

Changes are shown as strikethroughs for deletions and underlines for additions.

  1. COMMITMENT IMPLEMENTATION SOURCE RELATED SCHEDULE LRASECTION I AUDIT ITEM IP2: NL-07-039 A.2.1.1 1 Enhance the Aboveground Steel Tanks Program for September 28, A.3.1.1 IP2 and IP3 to perform thickness measurements of 2013 B.1.1 the bottom surfaces of the condensate storage tanks, city water tank, and fire water tanks once during the IP3:

first ten years of the period of extended operation.

December 12, Enhance the Aboveground Steel Tanks Program for ~015 IP2 and IP3 to require trending of thickness measurements when material loss is detected.

IP2: NL-07-039 A.2.1.2 2 Enhance the Bolting Integrity Program for IP2 and IP3 September 28, A.3.1.2 to clarify that actual yield strength is used in selecting 2013 B.1.2 materials for low susceptibility to SCC and clarify the prohibition on use of lubricants containing MoS2 for IP3: NL-07-153 Audit Items bolting.

December 12, 201,241, The Bolting Integrity Program manages loss of ~015 270 preload and loss of material for all external bolting.

NL-12-089 Attachment 2 Page 2 of 18

  1. COMMITMENT IMPLEMENTATION SOURCE RELATED SCHEDULE LRASECTION I AUDIT ITEM IP2: NL-07-039 A.2.1.5 3 Implement the Buried Piping and Tanks Inspection September 28, A.3.1.5 Program for IP2 and IP3 as described in LRA Section 2013 B.1.6 B.1.6.

NL-07-153 Audit Item This new program will be implemented consistent with IP3: 173 the corresponding program described in NUREG- December 12, 1801 Section XI.M34, Buried Piping and Tanks 2015 Inspection.

Include in the Buried Piping and Tanks Inspection NL-09-106 Program described in LRA Section B.1.6 a risk assessment of in-scope buried piping and tanks that NL-09-111 includes consideration of the impacts of buried piping or tank leakage and of conditions affecting the risk for corrosion. Classify pipe segments and tanks as having a high, medium or low impact of leakage based on the safety class, the hazard posed by fluid contained in the piping and the impact of leakage on reliable plant operation. Determine corrosion risk through consideration of piping or tank material, soil resistivity, drainage, the presence of cathodic protection and the type of coating. Establish inspection priority and frequency for periodic inspections of the in-scope piping and tanks based on the results of the risk assessment. Perform inspections using inspection techniques with NL-11-101 demonstrated effectiveness.

NL-12-089 Attachment 2 Page 3 of 18

  1. COMMITMENT IMPLEMENTATION SOURCE RELATED SCHEDULE LRASECTION I AUDIT ITEM IP2: NL-07-039 A.2.1.8 4 Enhance the Diesel Fuel Monitoring Program to September 28, A.3.1.8 include cleaning and inspection of the IP2 GT-1 gas 2013 S.1.9 turbine fuel oil storage tanks, IP2 and IP3 EDG fuel oil NL-07-153 Audit items day tanks, IP2 SSO/Appendix R diesel generator fuel IP3: 128, 129, oil day tank, and IP3 Appendix R fuel oil storage tank December 12, 132, and day tank once every ten years.

2015 NL-08-057 491,492, Enhance the Diesel Fuel Monitoring Program to 510 include quarterly sampling and analysis of the IP2 SSO/Appendix R diesel generator fuel oil day tank, IP2 security diesel fuel oil storage tank, IP2 security diesel fuel oil day tank, and IP3 Appendix R fuel oil storage tank. Particulates, water and sediment checks will be performed on the samples. Filterable solids acceptance criterion will be less than or equal to 10mg/1. Water and sediment acceptance criterion will be less than or equal to 0.05%.

Enhance the Diesel Fuel Monitoring Program to include thickness measurement of the bottom of the following tanks once every ten years. IP2: EDG fuel oil storage tanks, EDG fuel oil day tanks, SSO/Appendix R diesel generator fuel oil day tank, GT-1 gas turbine fuel oil storage tanks, and diesel fire pump fuel oil storage tank; IP3: EDG fuel oil day tanks, EDG fuel oil storage tanks, Appendix R fuel oil storage tank, and diesel fire pump fuel oil storage tank.

Enhance the Diesel Fuel Monitoring Program to change the analysis for water and particulates to a quarterly frequency for the following tanks. IP2: GT-1 gas turbine fuel oil storage tanks and diesel fire pump fuel oil storage tank; IP3: Appendix R fuel oil day tank and diesel fire pump fuel oil storage tank.

Enhance the Diesel Fuel Monitoring Program to specify acceptance criteria for thickness measurements of the fuel oil storage tanks within the scope of the program.

Enhance the Diesel Fuel Monitoring Program to direct samples be taken and include direction to remove water when detected.

Revise applicable procedures to direct sampling of the onsite portable fuel oil contents prior to transferring the contents to the storage tanks.

Enhance the Diesel Fuel Monitoring Program to direct the addition of chemicals including biocide when the presence of biological activity is confirmed.

NL-12-089 Attachment 2 Page 4 of 18

  1. COMMITMENT IMPLEMENTATION SOURCE RELATED SCHEDULE LRASECTION I AUDIT ITEM IP2: NL-07-039 A.2.1.10 5 Enhance the External Surfaces Monitoring Program September 28, A.3.1.10 for IP2 and IP3 to include periodic inspections of 2013 8.1.11 systems in scope and subject to aging management review for license renewal in accordance with 10 CFR IP3:

54.4(a)(1) and (a)(3). Inspections shall include areas December 12, surrounding the subject systems to identify hazards to 2015 those systems. Inspections of nearby systems that could impact the subject systems 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).

IP2: NL-07-039 A.2.1.11 6 Enhance the Fatigue Monitoring Program for IP2 to September 28, A.3.1.11 monitor steady state cycles and feedwater cycles or

~013 8.1.12, perform an evaluation to determine monitoring is not NL-07-153 Audit Item required. Review the number of allowed events and 164 resolve discrepancies between reference documents and monitoring procedures.

Enhance the Fatigue Monitoring Program for IP3 to IP3:

include all the transients identified. Assure all fatigue December 12, analysis transients are included with the lowest ~015 limiting numbers. Update the number of design transients accumulated to date.

IP2: NL-07-039 A.2.1.12 7 Enhance the Fire Protection Program to inspect September 28, A.3.1.12 external surfaces of the IP3 RCP oil collection

~013 8.1.13 systems for loss of material each refueling cycle.

Enhance the Fire Protection Program to explicitly IP3:

state that the IP2 and IP3 diesel fire pump engine December 12, sub-systems (including the fuel supply line) shall be ~015 observed while the pump is running. Acceptance criteria will be revised to verify that the diesel engine does not exhibit signs of degradation while running; such as fuel oil, lube oil, coolar.t, or exhaust gas leakage.

Enhance the Fire Protection Program to specify that the IP2 and IP3 diesel fire pump engine carbon steel exhaust components are inspected for evidence of corrosion and cracking at least once each operating cycle.

Enhance the Fire Protection Program for IP3 to visually inspect the cable spreading room, 480V switchgear room, and EDG room CO 2 fire suppression system for signs of degradation, such as corrosion and mechanical damage at least once every six months.

NL-12-089 Attachment 2 Page 5 of 18

  1. COMMITMENT IMPLEMENTATION SOURCE RELATED SCHEDULE LRASECTION I AUDIT ITEM IP2: NL-07-039 A.2.1.13 8 Enhance the Fire Water Program to include inspection September 28, A.3.1.13 of IP2 and IP3 hose reels for evidence of corrosion.

~013 B.1.14 Acceptance criteria will be revised to verify no NL-07-153 Audit Items unacceptable signs of degradation.

IP3: 105, 106 Enhance the Fire Water Program to replace all or test December 12, NL-08-014 a sample of IP2 and IP3 sprinkler heads required for ~015 10 CFR 50.48 using guidance of NFPA 25 (2002 edition), Section 5.3.1.1.1 before the end of the 50-year sprinkler head service life and at 10-year intervals thereafter during the extended period of operation to ensure that signs of degradation, such as corrosion, are detected in a timely manner.

Enhance the Fire Water Program to perform wall thickness evaluations of IP2 and IP3 fire protection piping on system 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 at intervals thereafter 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.

Enhance the Fire Water Program to inspect the internal surface of foam based fire suppression tanks.

Acceptance criteria will be enhanced to verify no significant corrosion.

-"-

NL-12-089 Attachment 2 Page 6 of 18

  1. COMMITMENT IMPLEMENTATION SOURCE RELATED SCHEDULE LRASECTION I AUDIT ITEM IP2: NL-07-039 A.2.1.15 9 Enhance the Flux Thimble Tube Inspection Program September 28, A.3.1.15 for IP2 and IP3 to implement comparisons to wear 2013 8.1.16 rates identified in WCAP-12866. Include provisions to compare data to the previous performances and IP3:

perform evaluations regarding change to test December 12, frequency and scope.

2015 Enhance the Flux Thimble Tube Inspection Program for IP2 and IP3 to specify the acceptance criteria as outlined in WCAP-12866 or other plant-specific values based on evaluation of previous test results.

Enhance the Flux Thimble Tube Inspection Program for IP2 and IP3 to direct evaluation and performance of corrective actions based on tubes that exceed or are projected to exceed the acceptance criteria. Also stipulate that flux thimble tubes that cannot be inspected over the tube length and cannot be shown by analysis to be satisfactory for continued service, must be removed from service to ensure the integrity of the reactor coolant system pressure boundary.

NL-12-089 Attachment 2 Page 7 of 18

  1. COMMITMENT IMPLEMENTATION SOURCE RELATED SCHEDULE LRASECTION I AUDIT ITEM IP2: NL-07-039 A.2.1.16 10 Enhance the Heat Exchanger Monitoring Program for September 28, A.3.1.16 IP2 and IP3 to include the following heat exchangers 2013 B.1.17, in the scope of the program.

NL-07-153 Audit Item

  • Safety injection pump lube oil heat exchangers IP3: 52 December 12,
  • RHR heat exchangers 2015
  • RHR pump seal coolers
  • Non-regenerative heat exchangers
  • Charging pump seal water heat exchangers
  • Charging pump fluid drive coolers
  • Charging pump crankcase oil coolers
  • Spent fuel pit heat exchangers
  • Waste gas compressor heat exchangers
  • SBD/Appendix R diesel jacket water heat A exchanger (I P2 only)

Enhance the Heat Exchanger Monitoring Program for IP2 and IP3 to perform visual inspection on heat exchangers where non-destructive examination, such as eddy current inspection, is not possible due to heat exchanger design limitations.

Enhance the Heat Exchanger Monitoring Program for IP2 and IP3 to include consideration of material-environment combinations when determining sample population of heat exchangers.

Enhance the Heat Exchanger Monitoring Program for IP2 and IP3 to establish minimum tube wall thickness for the new heat exchangers identified in the scope of the program. Establish acceptance criteria for heat exchangers visually inspected to include no indication of tube erosion, vibration wear, corrosion, pitting, NL-09-018 fouling, or scaling.

NL-09-056 11 Deleted NL-11-101

NL-12-089 Attachment 2 Page 8 of 18

  1. COMMITMENT IMPLEMENTATION SOURCE RELATED SCHEDULE LRASECTION I AUDIT ITEM IP2: NL-07-039 A.2.1.18 12 Enhance the Masonry Wall Program for IP2 and IP3 September 28, A.3.1.18 to specify that the IP1 intake structure is included in 2013 8.1.19 the program.

IP3:

December 12, 2015 Enhance the Metal-Enclosed 8us Inspection Program IP2: NL-07-039 A.2.1.19 13 to add IP2 480V bus associated with substation A to September 28, A.3.1.19 the scope of bus inspected. 2013 8.1.20 NL-07-153 Audit Items Enhance the Metal-Enclosed Bus Inspection Program IP3: 124, for IP2 and IP3 to visually inspect the external surface December 12, NL-08-057 133,519 of MEB enclosure assemblies for loss of material at 2015 least once every 10 years. The first inspection will occur prior to the period of extended operation and the acceptance criterion will be no significant loss of material.

Enhance the Metal-Enclosed Bus Inspection Program to add acceptance criteria for MEB internal visual inspections to include the absence of indications of dust accumulation on the bus bar, on the insulators, and in the duct, in addition to the absence of indications of moisture intrusion into the duct.

Enhance the Metal-Enclosed Bus Inspection Program for IP2 and IP3 to inspect bolted connections at least once every five years if performed visually or at least once every ten years using quantitative measurements such as thermography or contact resistance measurements. The first inspection will occur prior to the period of extended operation.

The plant will process a change to applicable site procedure to remove the raference to "re-torquing" connections for phase bus maintenance and bolted connection maintenance.

IP2: NL-07-039 A.2.1.21 14 Implement the Non-EO Bolted Cable Connections September 28, A.3.1.21 Program for IP2 and IP3 as described in LRA Section 2013 8.1.22 8.1.22.

IP3:

December 12, 12015

NL-12-089 Attachment 2 Page 9 of 18

  1. COMMITMENT IMPLEMENTATION SOURCE RELATED SCHEDULE LRASECTION I AUDIT ITEM IP2: NL-07-039 A.2.1.22 15 Implement the Non-EQ Inaccessible Medium-Voltage September 28, A.3.1.22 Cable Program for IP2 and IP3 as described in LRA 2013 B.l.23 Section B.l.23.

NL-07-153 Audit item This new program will be implemented consistent with IP3: 173 the corresponding program described in NUREG- December 12, NL-ll-032 1801 Section XI.E3, Inaccessible Medium-Voltage ~015 Cables Not Subject To 10 CFR 50.49 Environmental NL-ll-096 Qualification Requirements.

NL-ll-l01 IP2: NL-07-039 A.2.1.23 16 Implement the Non-EQ Instrumentation Circuits Test September 28, A.3.1.23 Review Program for IP2 and IP3 as described in LRA 2013 B.l.24 Section B.l.24.

NL-07-153 Audit item This new program will be implemented consistent with IP3: 173 the corresponding program described in NUREG- December 12, 1801 Section XI. E2, Electrical Cables and 2015 Connections Not Subject to 10 CFR 50.49 Environmental Qualification Requirements Used in Instrumentation Circuits.

IP2: NL-07-039 A.2.1.24 17 Implement the Non-EQ Insulated Cables and September 28, A.3.1.24 Connections Program for IP2 and IP3 as described in 2013 B.l.25 LRA Section B.l.25.

NL-07-153 Audit item This new program will be implemented consistent with IP3: 173 the corresponding program described in NUREG- December 12, 1801 Section XI.El, Electrical Cables and 2015 Connections Not SL'bject to 10 CFR 50.49 Environmental Qualification Requirements.

IP2: NL-07-039 A.2.1.25 18 Enhance the Oil Analysis Program for IP2 to sample September 28, A.3.1.25 and analyze lubricating oil used in the SBO/Appendix 2013 NL-ll-l0l B.l.26 R diesel generator consistent with the oil analysis for other site diesel generators.

IP3:

Enhance the Oil Analysis Program for IP2 and IP3 to December 12, sample and analyze generator seal oil and turbine 2015 hydraulic control oil.

Enhance the Oil Analysis Program for IP2 and IP3 to formalize preliminary oil screening for water and particulates and laboratory analyses including defined acceptance criteria for all components included in the scope of this program. The program will specify corrective actions in the event acceptance criteria are not met.

Enhance the Oil Analysis Program for IP2 and IP3 to formalize trending of preliminary oil screening results as well as data provided from independent laboratories.

NL-12-089 Attachment 2 Page 10 of 18

  1. COMMITMENT IMPLEMENTATION SOURCE RELATED SCHEDULE LRASECTION I AUDIT ITEM IP2: NL-07-039 A.2.1.26 19 Implement the One-Time Inspection Program for IP2 September 28, A.3.1.26 and IP3 as described in LRA Section B.1.27.

2013 B.1.27 This new program will be implemented consistent with NL-07-153 Audit item the corresponding program described in NUREG- IP3: 173 1801,Section XI.M32, One-Time Inspection .. December 12,

~015 IP2: NL-07-039 A.2.1.27 20 Implement the One-Time Inspection - Small Bore September 28, A.3.1.27 Piping Program for IP2 and IP3 as described in LRA

~013 B.1.28 Section B.1.28.

NL-07-153 Audit item This new program will be implemented consistent with IP3: 173 the corresponding program described in NUREG- December 12, 1801,Section XI.M35, One-Time Inspection of ASME ~015 Code Class I Small-Bore Piping.

IP2: NL-07-039 A.2.1.28 21 Enhance the Periodic Surveillance and Preventive September 28, A.3.1.28 Maintenance Program for IP2 and IP3 as necessary 2013 B.1.29 to assure that the effects of aging will be managed such that applicable components will continue to IP3:

perform their intended functions consistent with the December 12, current licensing basis through the period of extended 2015 operation.

IP2: NL-07-039 A.2.1.31 22 Enhance the Reactor Vessel Surveillance Program for September 28, A.3.1.31 IP2 and IP3 revising the specimen capsule withdrawal 2013 B.1.32 schedules to draw and test a standby capsule to cover the peak reactor vessel fluence expected IP3:

through the end of the period of extended operation.

December 12, Enhance the Reactor Vessel Surveillance Program for 2015 IP2 and IP3 to require that tested and untested specimens from all capsules pulled from the reactor vessel are maintained in storage.

IP2: NL-07-039 A.2.1.32 23 Implement the Selective Leaching Program for IP2 September 28, A.3.1.32 and IP3 as described in LRA Section B.1.33.

2013 B.1.33 This new program will be implemented consistent with NL-07-153 Audit item the corresponding program described in NUREG- IP3: 173 1801,Section XI.M33 Selective Leaching of Materials. December 12, g015 IP2: NL-07-039 A.2.1.34 24 Enhance the Steam Generator Integrity Program for September 28, A.3.1.34 IP2 and IP3 to require that the results of the condition 2013 B.1.35 monitoring assessment are compared to the operational assessment performed for the prior IP3:

operating cycle with differences evaluated.

December 12, 2015

NL-12-089 Attachment 2 Page 11 of 18

  1. COMMITMENT IMPLEMENTATION SOURCE RELATED SCHEDULE LRA SECTION I AUDIT ITEM Enhance the Structures Monitoring Program to IP2: NL-07-039 A.2.1.35 25 explicitly specify that the following structures are September 28, A.3.1.35 included in the program. 2013 8.1.36
  • Appendix R diesel generator foundation (I P3) NL-07-153
  • Appendix R diesel generator fuel oil tank vault IP3: Audit items (IP3) December 12, 86,87,88,
  • Appendix R diesel generator switchgear and 2015 NL-08-057 417 enclosure (IP3)
  • city water storage tank foundation
  • condensate storage tanks foundation (IP3)
  • containment access facility and annex (IP3)
  • discharge canal (IP2I3)
  • fire pumphouse (I P2)
  • fire protection pumphouse (I P3)
  • fire water storage tank foundations (IP2/3)
  • gas turbine 1 fuel storage tank foundation
  • maintenance and outage building-elevated passageway (I P2)
  • new station security building (IP2)
  • nuclear service building (I P1 )
  • primary water storage tank foundation (IP3)
  • refueling water storage tank foundation (IP3)
  • security access and office building (IP3)
  • superheater stack
  • transformerlswitchyard support structures (IP2)
  • waste holdup tank pits (IP2/3)

Enhance the Structures Monitoring Program for IP2 and IP3 to clarify that in addition to structural steel and concrete, the following commodities (including their anchorages) are inspected for each structure as applicable.

  • cable trays and supports
  • concrete portion of reactor vessel supports
  • conduits and supports
  • cranes, rails and girders
  • equipment pads and foundations
  • fire proofing (pyrocrete)
  • jib cranes
  • manholes and duct banks
  • manways, hatches and hatch covers
  • monorails

NL-12-089 Attachment 2 Page 12 of 18

  1. COMMITMENT IMPLEMENTATION SOURCE RELATED SCHEDULE LRASECTION I AUDIT ITEM
  • new fuel storage racks
  • sumps, sump screens, strainers and flow barriers Enhance the Structures Monitoring Program for IP2 and IP3 to inspect inaccessible concrete areas that are exposed by excavation for any reason. IP2 and IP3 will also inspect inaccessible concrete areas in environments where observed conditions in accessible areas exposed to the same environment indicate that significant concrete degradation is occurring.

Enhance the Structures Monitoring Program for IP2 and IP3 to perform inspections of elastomers (seals, gaskets, seismic joint filler, and roof elastomers) to identify cracking and change in material properties and for inspection of aluminum vents and louvers to identify loss of material.

Enhance the Structures Monitoring Program for IP2 and IP3 to perform an engineering evaluation of NL-08-127 Audit Item groundwater samples to assess aggressiveness of 360 groundwater to concrete on a periodic basis (at least once every five years). IPEG will obtain samples from at least 5 wells that are representative of the ground water surrounding below-grade site structures and perform an engineering evaluation of the results from those samples for sulfates, pH and chlorides.

Additionally, to assess potential indications of spent fuel pool leakage, IPEG will sample for tritium in groundwater wells in close proximity to the IP2 spent fuel pool at least once every 3 months.

Enhance the Structures Monitoring Program for IP2 and IP3 to perform inspection of normally submerged concrete portions of the intake structures at least once every 5 years. Inspect the baffling/grating partition and support platform of the IP3 intake structure at least once every 5 years.

Enhance the Structures Monitoring Program for IP2 and IP3 to perform inspection of the degraded areas Audit Item of the water control structure once per 3 years rather 358 than the normal frequency of once per 5 years during the PEO.

NL-12-089 Attachment 2 Page 13 of 18

  1. COMMITMENT IMPLEMENTATION SOURCE RELATED SCHEDULE LRASECTION I AUDIT ITEM Enhance the Structures Monitoring Program to include more detailed quantitative acceptance criteria NL-11-032 for inspections of concrete structures in accordance with ACI 349.3R, "Evaluation of Existing Nuclear Safety-Related Concrete Structures" prior to the period of extended operation. NL-11-101 IP2: NL-07-039 A.2.1.36 26 Implement the Thermal Aging Embrittlement of Cast September 28, A.3.1.36 Austenitic Stainless Steel (CASS) Program for IP2

~013 B.1.37 and IP3 as described in LRA Section B.1.37.

NL-07-153 Audit item This new program will be implemented consistent with IP3: 173 the corresponding program described in NUREG- December 12, 1801,Section XI.M12, Thermal Aging Embrittlement ~015 of Cast Austenitic Stainless Steel (CASS) Program.

IP2: NL-07-039 A.2.1.37 27 Implement the Thermal Aging and Neutron Irradiation September 28, A.3.1.37 Embrittlement of Cast Austenitic Stainless Steel (CASS) Program for IP2 and IP3 as described in LRA ~013 B.1.38 NL-07-153 Audit item Section B.1.38.

IP3: 173 This new program will be implemented consistent with December 12, the corresponding program described in NUREG- ~015 1801 Section XI.M13, Thermal Aging and Neutron Embrittlement of Cast Austenitic Stainless Steel (CASS) Program.

IP2: NL-07-039 A.2.1.39 28 Enhance the Water Chemistry Control- Closed September 28, A.3.1.39 Cooling Water Program to maintain water chemistry of 2013 B.1.40 the IP2 SBO/Appendix R diesel generator cooling NL-08-057 Audit item system per EPRI guidelines.

IP3: 509 Enhance the Water Chemistry Control - Closed December 12, Cooling Water Program to maintain the IP2 and IP3 2015 security generator and fire protection diesel cooling water pH and glycol within limits specified by EPRI guidelines.

IP2: NL-07-039 A.2.1.40 29 Enhance the Water Chemistry Control- Primary and September 28, B.1.41 Secondary Program for IP2 to test sulfates monthly in 2013 the RWST with a limit of <150 ppb.

IP2: NL-07-039 A.2.1.41 30 For aging management of the reactor vessel internals, September 28, A.3.1.41 IPEC will (1) partiCipate in the industry programs for 2011 investigating and managing aging effects on reactor internals; (2) evaluate and implement the results of IP3:

the industry programs as applicable to the reactor December 12, internals; and (3) upon completion of these programs, 2013 but not less than 24 months before entering 'the period of extended operation, submit an inspection plan for reactor internals to the NRC for review and approval. Coml2 lete NL-11-107

NL-12-089 Attachment 2 Page 14 of 18

  1. COMMITMENT IMPLEMENTATION SOURCE RELATED SCHEDULE LRASECTION I AUDIT ITEM IP2: NL-07-039 A.2.2.1.2 31 Additional P-T curves will be submitted as required September 28, A.3.2.1.2 per 10 CFR 50, Appendix G prior to the period of

~013 4.2.3 extended operation as part of the Reactor Vessel Surveillance Program.

IP3:

December 12,

~015 As required by 10 CFR 50.61 (b)(4) , IP3 will submit a IP3: NL-07-039 A.3.2.1.4 32 plant-specific safety analysis for plate 82803-3 to the December 12, 4.2.5 NRC three years prior to reaching the RT PTS ~015 NL-08-127 screening criterion. Alternatively, the site may choose to implement the revised PTS rule when approved.

IP2: NL-07-039 A.2.2.2.3 33 At least 2 years prior to entering the period of September 28, A.3.2.2.3 extended operation, for the locations identified in LRA Table 4.3-13 (IP2) and LRA Table 4.3-14 (IP3), under ~011 4.3.3 NL-07-153 Audit item the Fatigue Monitoring Program, IP2 and IP3 will IP3: 146 implement one or more of the following:

December 12, NL-08-021 (1) Consistent with the Fatigue Monitoring Program, ~013 Detection of Aging Effects, update the fatigue usage calculations using refined fatigue analyses to determine valid CUFs less than 1.0 when accounting Complete NL-l0-082 for the effects of reactor water environment. This includes applying the appropriate Fen factors to valid CUFs determined in accordance with one of the following:

1. For locations in LRA Table 4.3-13 (IP2) and LRA Table 4.3-14 (IP3), with existing fatigue analysis valid for the period of extended operation, use the existing eUF.
2. Additional plant-specific locations with a valid eUF may be evaluated. In particular, the pressurizer lower shell will be reviewed to ensure the surge nozzle remains the limiting component.
3. Representative eUF values from other plants, adjusted to or enveloping the IPEe plant specific external loads may be used if demonstrated applicable to IPEe.
4. An analysis using an NRC-approved version of the ASME code or NRC-approved alternative (e.g., NRC-approved code case) may be performed to determine a valid CUF.

(2) Consistent with the Fatigue Monitoring Program, Corrective Actions, repair or replace the affected locations before exceeding a CUF of 1.0.

NL-12-089 Attachment 2 Page 15 of 18

  1. COMMITMENT IMPLEMENTATION SOURCE RELATED SCHEDULE LRASECTION I AUDIT ITEM April 30, 2008 NL-07-078 2.1.1.3.5 34 IP2 SSO / Appendix R diesel generator will be installed and operational by April 30, 2008. This Complete NL-08-074 committed change to the facility meets the requirements of 10 CFR 50.59(c)(1) and, therefore, a NL-11-101 license amendment pursuant to 10 CFR 50.90 is not required.

IP2: NL-08-127 Audit Item 35 Perform a one-time inspection of representative September 28, 27 sample area of IP2 containment liner affected by the

~013 1973 event behind the insulation, prior to entering the period of extended operation, to assure liner degradation is not occurring in this area.

NL-11-101 Perform a one-time inspection of representative IP3:

sample area of the IP3 containment steel liner at the December 12, juncture with the concrete floor slab, prior to entering 2015 the period of extended operation, to assure liner degradation is not occurring in this area.

NL-09-018 Any degradation will be evaluated for updating of the containment liner analyses as needed.

IP2: NL-08-127 Audit Item 36 Perform a one-time inspection and evaluation of a September 28, NL-11-101 359 sample of potentially affected IP2 refueling cavity 2013 concrete prior to the period of extended operation.

The sample will be obtained by core boring the refueling cavity wall in an area that is susceptible to exposure to borated water leakage. The inspection will include an assessment of embedded reinforcing steel.

Additional core bore samples wi!1 be taken, if the NL-09-056 leakage is not stopped, prior to the end of the first ten years of the period of extended operation.

NL-09-079 A sample of leakage fluid will be analyzed to determine the composition of the fluid. If additional core samples are taken prior to the end of the first ten years of the period 0'1' extended operation, a sample of leakage fluid will be analyzed.

IP2: NL-08-127 Audit Item 37 Enhance the Containment Inservice Inspection (CII-September 28, 361 IWL) Program to include inspections of the

~013 containment using enhanced characterization of degradation (Le., quantifying the dimensions of noted IP3:

indications through the use of optical aids) during the December 12, period of extended operation. The enhancement

~015 includes obtaining critical dimensional data of degradation where possible through direct measurement or the use of scaling technologies for photographs, and the use of consistent vantage points for visual inspections.

NL-12-089 Attachment 2 Page 16 of 18

  1. COMMITMENT IMPLEMENTATION SOURCE RELATED SCHEDULE LRASECTION I AUDIT ITEM IP2: NL-08-143 4.2.1 38 For Reactor Vessel Fluence, should future core September 28, loading patterns invalidate the basis for the projected 12013 values of RTpts or CvUSE, updated calculations will be provided to the NRC.

IP3:

December 12, 12015 NL-09-079 39 Deleted IP2: NL-09-106 8.1.6 40 Evalu~te plant ~pecific and appropriate industry September 28, 8.1.22 operating expenence and incorporate lessons learned 12013 8.1.23 in establi~hing appropriate monitoring and inspection 8.1.24 frequencies to assess aging effects for the new aging IP3: 8.1.25 managemen t programs. Documentation of the o~erating ~xperience evaluated for each new program December 12, 8.1.27 8.1.28 will ,be available on site for NRC review prior to the 12015 8.1.33 penod of extended operation.

8.1.37 8.1.38 IPEC will inspect steam generators for both units to IP2:

NL-11-032 N/A 41 assess the condition of the divider plate assembly, ~fter the The examination technique used will be capable of beginning of the detecting PWSCC in the steam generator divider plate PEO and prior to

~ssem~ly. T~e IP2 steam generator divider plate September 28, Inspectlo~s will be completed within the first ten years 12023 NL-11-074 of the penod of extended operation (PEO). The IP3

' IP3: NL-11-090 st earn generator divider plate inspections will be completed within the first refueling outage following Prior to the end the beginning of the PEO. pf the first NL-11-101 refueling outage ollowing the beginning of the PEO,

NL-12-089 Attachment 2 Page 17 of 18

  1. COMMITMENT IMPLEMENTATION SOURCE RELATED SCHEDULE LRASECTION I AUDIT ITEM NL-11-032 N/A 42 IPEC will develop a plan for each unit to address the potential for cracking of the primary to secondary pressure boundary due to PWSCC of tube-to-tubesheet welds using one of the following two options.

Option 1 (AnalysiS)

IPEC will perform an analytical evaluation of the IP2: NL-11-074 steam generator tube-to-tubesheet welds in order to Prior to March establish a technical basis for either determining that the tubesheet cladding and welds are not susceptible ~024 NL-11-090 IP3: Prior to the to PWSCC, or redefining the pressure boundary in end of the first NL-11-096 which the tube-to-tubesheet weld is no longer refueling outage included and, therefore, is not required for reactor

~ollowing the coolant pressure boundary function. The redefinition beginning of the of the reactor coolant pressure boundary must be PEa.

approved by the NRC as a license amendment request.

Option 2 (Inspection) IP2:

Between March IPEC will perform a one-time inspection of a 2020 and March representative number of tube-to-tubesheet welds in ~024 each steam generator to determine if PWSCC cracking is present. If weld cracking is identified: IP3: Prior to the

a. The condition will be resolved through repair end of the first or engineering evaluation to justify continued refueling outage service, as appropriate, and ~ollowing the beginning of the
b. An ongoing monitoring program will be PEa.

established to perform routine tube-to-tubesheet weld inspections for the remaining life of the steam generators.

IP2: NL-11-032 4.3.3 43 IPEC will review design basis ASME Code Class 1 Prior to fatigue evaluations to determine whether the September 28, NUREG/CR-6260 locations that have been evaluated 12013 for the effects of the reactor coolant environment on NL-11-101 fatigue usage are the limiting locations for the IP2 and IP3: Prior to IP3 configurations. If more limiting locations are December 12, identified, the most limiting location will be evaluated 12015 for the effects of the reactor coolant environment on fatigue usage.

IPEC will use the NUREG/CR-6909 methodology in the evaluation of the limiting locations consisting of nickel alloy, if any.

NL-12-089 Attachment 2 Page 18 of 18

  1. COMMITMENT IMPLEMENTATION SOURCE RELATED SCHEDULE LRASECTION I AUDIT ITEM IP2: NL-11-032 N/A 44 IPEG will include written explanation and justification Prior to of any user intervention in future evaluations using the September 28, NL-11-101 WESTEMS "Design GUF" module.

~013 IP3: Prior to December 12,

~015 IP2: NL-11-032 N/A 45 IPEG will not use the NB-3600 option of the Prior to WESTEMS program in future design calculations until September 28, NL-11-101 the issues identified during the NRG review of the

~013 program have been resolved.

IP3: Prior to December 12, 2015 IP2: NL-11-032 N/A 46 Include in the IP2 lSI Program that IPEG will perform Prior to twenty-five volumetric weld metal inspections of September 28, NL-11-074 socket welds during each 10-year lSI interval 2013 scheduled as specified by IWB-2412 of the ASME Section XI Gode during the period of extended operation.

In lieu of volumetric examinations, destructive examinations may be performed, where one destructive examination may be substituted for two volumetric examinations.

47 IPEG will gerform and submit anal~ses that ~ NL-12-089 N/A Prior to demonstrate that the lower suggort column bodies will September 28 maintain their functionalitv durina the geriod of extended ogeration considering the gossible loss of ~

fracture toughness due to thermal and irradiation IP3: Prior to embrittlement. The anal~ses will be consistent with December 12.

th§ IP2/1P3 licensing basis.

gQ1§.

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