NL-11-090, Indian Point, Units 2 & 3, Clarification for Request for Additional Information, Aging Management Programs

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Indian Point, Units 2 & 3, Clarification for Request for Additional Information, Aging Management Programs
ML11215A128
Person / Time
Site: Indian Point  Entergy icon.png
Issue date: 07/27/2011
From: Dacimo F
Entergy Nuclear Northeast
To:
Document Control Desk, Office of Nuclear Reactor Regulation
References
NL-11-090
Download: ML11215A128 (25)
v • d • e


Text

EnteW 0 Enter-py Nuclear Northeast Indian Point Energy Center 450 Broadway, GSB P.O. Box 249 Buchanan, NY 10511-0249 Tel (914) 788-2055 Fred Dacimo Vice President Operations License Renewal NL-1 1-090 July 27, 2011 U.S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20555-0001

SUBJECT:

REFERENCE:

Clarification for Request for Additional Information (RAI)Aging Management Programs Indian Point Nuclear Generating Unit Nos& 2 & 3 Docket Nos. 50-247 and 50-286 License Nos. DPR-26 and DPR-64 1. NRC Letter, "Request for Additional Information for the Review of the Indian Point Nuclear Generating Unit Numbers 2 and 3, License Renewal Application," dated June 15, 2011 2. Entergy letter (NL-1 1-032)," Response to Request for Additional Information (RAI) Aging Management Programs," dated March 28, 2011 3. Entergy letter (NL-1 1-074)," Response to Request for Additional Information (RAI) Aging Management Programs," dated July 14, 2011

Dear Sir or Madam:

Entergy Nuclear Operations, Inc is providing, in Attachment 1, clarifications of the responses in References 2 and 3. Attachment 2 provides the latest list of regulatory commitments including revised commitments contained in this letter.If you have any questions, or require additional information, please contact Mr. Robert Walpole at 914-734-6710.

Docket Nos. 50-247 & 50-286 NL-1 1-090 Page 2 of 2 I deci re nder penalty of perjury that the foregoing is true and correct. Executed on ,--,7 ol .Sincer-ey FRD/cbr

Attachment:

Attachment:

1. Clarification for Request for Additional Information (RAI), Aging Management Programs 2. IPEC List of Regulatory Commitments (Rev. 15)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. John Boska, NRR Senior Project Manager Mr. Paul Eddy, 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-11-090 LICENSE RENEWAL APPLICATION CLARIFICATION FOR REQUEST FOR ADDITIONAL INFORMATION (RAI)AGING MANAGEMENT PROGRAMS ENTERGY NUCLEAR OPERATIONS, INC.INDIAN POINT NUCLEAR GENERATING UNIT NOS. 2 & 3 DOCKET NOS. 50-247 AND 50-286 NL-11-090 Attachment 1 Page 1 of 4 INDIAN POINT NUCLEAR GENERATING UNIT NOS. 2 AND 3 LICENSE RENEWAL APPLICATION CLARIFICATION FOR REQUEST FOR ADDITIONAL INFORMATION (RAI)AGING MANAGEMENT PROGRAMS Changes are shown as strikethroughs for deleftios and underlines for additions.

Clarification for RAI 3.0.3.1.6-1 Part 1 A.2.1.22 Non-EQ Inaccessible Medium-Voltage Cable Program The Non-EQ Inaccessible Medium-Voltage Cable Program is a new program that entails periodic ,Rd-event drien inspections for water collection in cable manholes, and periodic testing of cables. In scope medium-voltage cables (cables with operating voltage from 2kV to 35kV) and low-voltage power cables (400 V to 2 kV)exposed to significant moisture will be tested at least once every six years to provide an indication of the condition of the conductor insulation.

Test frequencies are adjusted based on test results and operating experience.

The frequency of inspections for water accumulation in manholes is established based on plant specific operating experience with cable wetting or submergence in manholes (i.e., the inspection is performed periodically based on water accumulation over time and event driven occurrences, such as heavy rain or flooding).

The frequency will be program in"ludo peioi ,,nspoctions fr .a...ter acc.um.ulation in anho at least once every year (annually).

In add'ition to the periodic inspection, inspection Of e.ent driven occu.rrence, such. ar. heaa'vy rain Or flooding Will be Inspection frequency will be increased as necessary based on evaluation of inspection results.The Non-EQ Inaccessible Medium-Voltage Cable Program will be implemented prior to the period of extended operation.

This new program will be implemented consistent with the corresponding program described in NUREG-1 8001,Section XI.E3, Inaccessible Medium-Voltage Cables Not Subject To 10 CFR 50.49 Environmental Qualification Requirements.

A.3.1.22 Non-EQ Inaccessible Medium-Voltage Cable Program The Non-EQ Inaccessible Medium-Voltage Cable Program is a new program that entails periodic and event driven inspections for water collection in cable manholes, and periodic testing of cables. In scope medium- *voltage cables (cables with operating voltage from 2kV to 35kV) and low-voltage power cables (400 V to 2 kV)exposed to significant moisture will be tested at least once every six years to provide an indication of the condition of the conductor insulation.

Test frequencies are adjusted based on test results and operating experience.

The frequency of inspections for water accumulation in manholes is established based on plant specific operating experience with cable wetting or submergence in manholes (i.e., the inspection is performed periodically based on water accumulation over time and event driven occurrences, such as heavy rain or flooding).

NL-1 1-090 Attachment 1 Page 2 of 4 The frequency will be program include, period. c ,, In.etions foFr water acm. ut.i i n, ..manhole, at least once every year (annually).

In addition to the periodic inspYction-, inspection of et dr-,4iVen occurrences, 6uch aG heavy rain floodinR Will be pe4.Fomed.

Inspection frequency will be increased as necessary based on evaluation of inspection results.The Non-EQ Inaccessible Medium-Voltage Cable Program will be implemented prior to the period of extended operation.

This new program will be implemented consistent with the corresponding program described in NUREG-1 8001,Section XI.E3, Inaccessible Medium-Voltage Cables Not Subject To 10 CFR 50.49 Environmental Qualification Requirements.

Clarification for RAI 3.0.3.1.2-3 A.2.1.5 Buried Piping and Tanks Inspection Program The Buried Piping and Tanks Inspection Program is a new program that includes (a) preventive measures to mitigate corrosion and (b) inspections to manage the effects of corrosion on the pressure-retaining capability of buried carbon steel, gray cast iron, and stainless steel components.

Preventive measures are in accordance with standard industry practice for maintaining external coatings and wrappings.

Buried components are inspected when excavated during maintenance.

If trending within the corrective action. program identifies susceptible locations, the areas with a history of corrosion problems are evaluated for the need for additional inspection, alternate coating, or replacement.

Prf"ior Wt eAntc"ig th of extended operation, plant operating Will be reviewed and multiple inpetions Will be9 completed within the past ten years. Additional periodic inspections.

will be perfo-rlmeda wi.thin the- fir*st ton years of the of IP2 will perform 20 direct visual inspections of buried piping during the 10 year period prior the PEO. IP2 will perform 14 direct visual inspections during each 10-year period of the PEO. Soil samples will be taken prior to the PEO and at least once every 10 years in the PEO. Soil will be tested at a minimum of two locations at least three feet below the surface near in-scope piping to determine representative soil conditions for each system. If test results indicate the soil is corrosive then the number of piping inspections will be increased to 20 during each 10-year period of the PEO.A.3.1.5 Buried Piping and Tanks Inspection Program The Buried Piping and Tanks Inspection Program is a new program that includes (a) preventive measures to mitigate corrosion and (b) inspections to manage the effects of corrosion on the pressure-retaining capability of buried carbon steel, gray cast iron, and stainless steel components.

Preventive measures are in accordance with standard industry practice for maintaining external coatings and wrappings.

Buried components are inspected when excavated during maintenance.

If trending within the corrective action program identifies susceptible locations, the areas with a history of corrosion problems are evaluated for the need for additional inspection, alternate coating, or replacement.

Prior to entering the peried of extended operation, plant operating experience will be reviewed and multiple inspectons will be com~pleted within the past ton years. Additional periodic npcin will be per~formed within the first ten years of the period of extended eperatien.

IP3 will perform 14 direct visual inspections of buried piping during the 10 year period prior the PEO. IP3 will perform 16 direct visual inspections during each 10-year period of the PEO. Soil samples'will be taken prior to the PEO and at least once every 10 years into the PEO. Soil will be tested at a minimum of two locations at least three feet below the surface near in-scope piping to determine representative soil conditions for each NL-11-090 Attachment 1 Page 3 of 4 system. If test results indicate the soil is corrosive then the number of piping inspections will be increased to 22 2-0 during each 10-year period of the PEO.Clarification for RAI B.O.4-1 A.2.1 Aging Management Programs and Activities The integrated plant assessment for license renewal identified aging management programs necessary to provide reasonable assurance that components within the scope of license renewal will continue to perform their intended functions consistent with the current licensing basis (CLB) through the period of extended operation.

This section describes the aging management programs and activities required during the period of extended operation.

All aging management programs will be implemented prior to entering the period of extended operation.

IPEC quality assurance (QA) procedures, review and approval processes, and administrative controls are implemented in accordance with the requirements of 10 CFR 50, Appendix B. The Entergy Quality Assurance Program applies to safety-related structures and components.

Corrective actions and administrative (document) control for both safety-related and nonsafety-related structures and components are accomplished per the existing IPEC corrective action program and document control program and are applicable to all aging management programs and activities that will be required during the period of extended operation.

The confirmation process is part of the corrective action program and includes reviews to assure that proposed actions are adequate, tracking and reporting of open corrective actions, and review of corrective action effectiveness.

Any follow-up inspection required by the confirmation process is documented in accordance with the corrective action program. The corrective action, confirmation process, and administrative controls of the Entergy (10 CFR Part 50, Appendix B) Quality Assurance Program are applicable to all aging management programs and activities required during the period of extended operation.

The Operating Experience Program (OEP) and the Corrective Action Program (CAP) help to assure continued effectiveness of aging management programs through evaluations of operating experience.

The OEP implements the requirements of NRC NUREG-0737, "Clarification of TMI Action Plan Requirements,"Section I.C.5 and evaluates site, Enterqy fleet, and industry operating experience for impact on IPEC. The CAP implements the requirements of 10 CFR 50, Appendix B, Criterion XVI and is used to evaluate and effect appropriate actions in response to operating experience relevant to IPEC that indicates a condition adverse to aualitv or a non-conformance.

NL-1 1-090 Attachment 1 Page 4 of 4 A.3.1 Aging Management Programs and Activities The integrated plant assessment for license renewal identified aging management programs necessary to provide reasonable assurance that components within the scope of license renewal will continue to perform their intended functions consistent with the current licensing basis (CLB) through the period of extended operation.

This section describes the aging management programs and activities required during the period of extended operation.

All aging management programs will be implemented prior to entering the period of extended operation.

IPEC quality assurance (QA) procedures, review and approval processes, and administrative controls are implemented in accordance with the requirements of 10 CFR 50, Appendix B. The Entergy Quality Assurance Program applies to safety-related structures and components.

Corrective actions and administrative (document) control for both safety-related and non safety-related structures and components are accomplished per the existing IPEC corrective action program and document control program and are applicable to all aging management programs and activities that will be required during the period of extended operation.

The confirmation process is part of the corrective action program and includes reviews to assure that proposed actions are adequate, tracking and reporting.of open corrective actions, and review of corrective action effectiveness.

Any follow-up inspection required by the confirmation process is documented in accordance with the corrective action program. The corrective action, confirmation process, and administrative controls of the Entergy (10 CFR Part 50, Appendix B) Quality Assurance Program are applicable to all aging management programs and activities required during the period of extended operation.

The Operating Experience Program (OEP) and the Corrective Action Program (CAP) help to assure continued effectiveness of aging management programs through evaluations of operating experience.

The OEP implements the requirements of NRC NUREG-0737, "Clarification of TMI Action Plan Requirements,"Section I.C.5 and evaluates site, Entergy fleet, and industry operating experience for impact on IPEC. The CAP implements the requirements of 10 CFR 50, Appendix B, Criterion XVI and is used to evaluate and effect appropriate actions in response to operating experience relevant to IPEC that indicates a condition adverse to quality or a non-conformance.

ATTACHMENT 2 TO NL-11-090 LICENSE RENEWAL APPLICATION IPEC LIST OF REGULATORY COMMITMENTS Rev. 15 ENTERGY NUCLEAR OPERATIONS, INC.INDIAN POINT NUCLEAR GENERATING UNIT NOS. 2 & 3 DOCKET NOS. 50-247 AND 50-286 NL-1 1-090 Attachment 2 Page 1 of 17 List of Regulatory Commitments Rev. 15 The following table identifies those actions committed to by Entergy in this document.Changes are shown as strikethroughs for deletiepe and underlines for additions.

  1. COMMITMENT IMPLEMENTATION SOURCE RELATED SCHEDULE LRA SECTION/ AUDIT ITEM Enhance the Aboveground Steel Tanks Program for 1P2: NL-07-039 A.2.1.1 IP2 and IP3 to perform thickness measurements of September 28, A.3.1.1 the bottom surfaces of the condensate storage tanks, 2013 B.1.1 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 2015 IP2 and IP3 to require trending of thickness measurements when material loss is detected.2 Enhance the Bolting Integrity Program for IP2 and IP3 I P2: NL-07-039 A.2.1.2 to clarify that actual yield strength is used in selecting September 28, A.3.1.2 materials for low susceptibility to SCC and clarify the 013 B.1.2 prohibition on use of lubricants containing MoS 2 for IP3: NL-07-153 Audit Items bolting. December 12, 201,241, The Bolting Integrity Program manages loss of 2015 270 preload and loss of material for all external bolting.3 Implement the Buried Piping and Tanks Inspection 1P2: NL-07-039 A.2.1.5 Program for IP2 and IP3 as described in LRA Section September 28, A.3.1.5 B.1.6. 013 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 direct visual inspection.

NL-1 1-090 Attachment 2 Page 2 of 17 COMMITMENT IMPLEMENTATION SOURCE RELATED SCHEDULE LRA SECTION I_ I / AUDIT ITEM 4 Enhance the Diesel Fuel Monitoring Program to include cleaning and inspection of the IP2 GT-1 gas turbine fuel oil storage tanks, IP2 and IP3 EDG fuel oil day tanks, IP2 SBO/Appendix R diesel generator fuel oil day tank, and IP3 Appendix R fuel oil storage tank and day tank once every ten years.Enhance the Diesel Fuel Monitoring Program to include quarterly sampling and analysis of the IP2 SBO/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/l. 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, SBO/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.

I P2: September 28, 2013 I P3: December 12, 2015 NL-07-039 NL-07-153 NL-08-057 A.2.1.8 A.3.1.8 B.1.9 Audit items 128, 129, 132, 491,492, 510 NL-1 1-090 Attachment 2 Page 3 of 17 COMMITMENT IMPLEMENTATION SOURCE RELATED SCHEDULE LRA SECTION/AUDIT ITEM 5 Enhance the External Surfaces Monitoring Program P2: NL-07-039 A.2.1.10 for IP2 and IP3 to include periodic inspections of September 28, A.3.1.10 systems in scope and subject to aging management 013 B.1.11 review for license renewal in accordance with 10 CFR lP3: 54.4(a)(1) and (a)(3). Inspections shall include areas December 12, surrounding the subject systems to identify hazards to 015 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).

6 Enhance the Fatigue Monitoring Program for IP2 to P2: tNL-07-039 A.2.1.11 monitor steady state cycles and feedwater cycles or September 28, B.1.12, perform an evaluation to determine monitoring is not 2013 Audit I 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 2015 limiting numbers. Update the number of design transients accumulated to date.7 Enhance the Fire Protection Program to inspect IP2: NL-07-039 A.2.1.12 external surfaces of the IP3 RCP oil collection September 28, A.3.1.12 systems for loss of material each refueling cycle. 2013 B.1.13 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 2015 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, coolant, 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 C02 fire suppression system for signs of degradation, such as corrosion and mechanical damage at least once every six months.

NL-1 1-090 Attachment 2 Page 4 of 17 COMMITMENT IMPLEMENTATION SOURCE RELATED SCHEDULE LRA SECTION I4I / AUDIT ITEM 8 Enhance the Fire Water Program to include inspection of IP2 and IP3 hose reels for evidence of corrosion.

Acceptance criteria will be revised to verify no unacceptable signs of degradation.

Enhance the Fire Water Program to replace all or test a sample of IP2 and IP3 sprinkler heads required for 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 siqnificant corrosion.

I P2: September 28, 2013 I P3: December 12, 2015 NL-07-039 NL-07-153 NL-08-014 A.2.1.13 A.3.1.13 B.1.14 Audit Items 105, 106 L -I .5. J ____________

NL-1 1-090 Attachment 2 Page 5 of 17 COMMITMENT IMPLEMENTATION SOURCE RELATED SCHEDULE LRA SECTION 1 __ _. __ 1/ AUDIT ITEM 9 Enhance the Flux Thimble Tube Inspection Program for IP2 and IP3 to implement comparisons to wear rates identified in WCAP-12866.

Include provisions to compare data to the previous performances and perform evaluations regarding change to test frequency and scope.Enhance the Flux Thimble Tube Inspection Program for IP2 and IP3 to specify the acceptance criteria as outlined in WCAP-1 2866 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.I P2: September 28, 2013 IP3: December 12, 2015 NL-07-039 A.2.1.15 A.3.1.15 B.1.16 NL-1 1-090 Attachment 2 Page 6 of 17 COMMITMENT IMPLEMENTATION SOURCE RELATED SCHEDULE LRA SECTION I I4I/ AUDIT ITEM 10 Enhance the Heat Exchanger Monitoring Program for IP2 and IP3 to include the following heat exchangers in the scope of the program." Safety injection pump lube oil heat exchangers

  • RHR heat exchangers
  • RHR pump seal coolers" Non-regenerative heat exchangers 0 Charging pump seal water heat exchangers
  • Charging pump fluid drive coolers* Charging pump crankcase oil coolers* Spent fuel pit heat exchangers
  • Secondary system steam generator sample coolers" Waste gas compressor heat exchangers
  • SBO/Appendix R diesel jacket water heat exchanger (IP2 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, fouling, or scaling.I P2: September 28, 2013 I P3: December 12, 2015 NL-07-039 N L-07-153 NL-09-018 A.2.1.16 A.3.1.16 B.1.17, Audit Item 52 11 Delete commitment.

NL-09-056 NL-11-090 Attachment 2 Page 7 of 17 COMMITMENT IMPLEMENTATION SOURCE RELATED SCHEDULE LRA SECTION/ AUDIT ITEM 12 Enhance the Masonry Wall Program for IP2 and IP3 IP2: NL-07-039 A.2.1.18 to specify that the IP1 intake structure is included in September 28, A.3.1.18 the program. 2013 B.1.19 IP3: December 12, 2015 13 Enhance the Metal-Enclosed Bus Inspection Program to add I P2 480V bus associated with substation A to the scope of bus inspected.

Enhance the Metal-Enclosed Bus Inspection Program for IP2 and IP3 to visually inspect the external surface of MEB enclosure assemblies for loss of material at 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 reference to "re-torquing" connections for phase bus maintenance and bolted connection maintenance.

I P2: September 28, 2013 1P3: December 12, 2015 NL-07-039 NL-07-153 NL-08-057 A.2.1.19 A.3.1.19 B.1.20 Audit Items 124, 133, 519 14 Implement the Non-EQ Bolted Cable Connections IP2: NL-07-039 A.2.1.21 Program for IP2 and IP3 as described in LRA Section September 28, A.3.1.21 B.1.22. 2013 B.1.22 I P3: December 12, 12015 NL-1 1-090 Attachment 2 Page 8 of 17# COMMITMENT IMPLEMENTATION SOURCE RELATED SCHEDULE LRA SECTION/ AUDIT ITEM 15 Implement the Non-EQ Inaccessible Medium-Voltage eP2: NL-07-039 A.2.1.22 Cable Program for IP2 and IP3 as described in LRA September 28, A.3.1.22 Section B.1.23. 2013 B. 1.23 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.E3, Inaccessible Medium-Voltage 2015 Cables Not Subject To 10 CFR 50.49 Environmental Qualification Requirements.

IP2: NL-07-039 A.2.1.23 16 Implement the Non-EQ Instrumentation Circuits Test A.2.1.23 Review Program for IP2 and IP3 as described in LRA September 28, A.3.1.23 Section B.1.24. 2013 B. 1.24 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.17 Implement the Non-EQ Insulated Cables and IP2: NL-07-039 A.2.1.24 Connections Program for IP2 and IP3 as described in September 28, A.3.1 24 LRA Section B.1.25. 2013 B.1.25 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.E1, Electrical Cables and 2015 Connections Not Subject to 10 CFR 50.49 Environmental Qualification Requirements.

18 Enhance the Oil Analysis Program for IP2 to sample IP2: NL-07-039 A.2.1.25 and analyze lubricating oil used in the SBO/Appendix September 28, A.3.1.25 R diesel generator consistent with 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-1 1-090 Attachment 2 Page 9 of 17 COMMITMENT IMPLEMENTATION SOURCE RELATED SCHEDULE LRA SECTION/ AUDIT ITEM IP2: NL-07-039 A,2.1,.26 19 Implement the One-Time Inspection Program for IP2 A.2.1.26 and IP3 as described in LRA Section B.1.27. September 28, A.3.1.26 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, 2015 20 Implement the One-Time Inspection

-Small Bore 1P2: NL-07-039 A.2.1.27 Piping Program for IP2 and IP3 as described in LRA September 28, A.3.1.27 Section B.1.28. 2013 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 2015 Code Class I Small-Bore Piping.21 Enhance the Periodic Surveillance and Preventive IP2: NL-07-039 A.2.1.28 Maintenance Program for IP2 and IP3 as necessary September 28, A.3.1.28 to assure that the effects of aging will be managed 013 B.1.29 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.

2015 22 Enhance the Reactor Vessel Surveillance Program for 1P2: NL-07-039 A.2.1.31 IP2 and IP3 revising the specimen capsule withdrawal September 28, A.3.1.31 schedules to draw and test a standby capsule to 013 B.1.32 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.23 Implement the Selective Leaching Program for IP2 1P2: NL-07-039 A.2.1.32 and IP3 as described in LRA Section B.1.33. September 28, A.3.1.32 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, 2015 24 Enhance the Steam Generator Integrity Program for IP2: NL-07-039 A.2.1.34 IP2 and IP3 to require that the results of the condition September 28, A.3.1.34 monitoring assessment are compared to the 2013 B.1.35 operational assessment performed for the prior IP3: operating cycle with differences evaluated.

December 12, 2015 NL-1 1-090 Attachment 2 Page 10 of 17# COMMITMENT IMPLEMENTATION SOURCE RELATED SCHEDULE LRA SECTION/ AUDIT ITEM 25 Enhance the Structures Monitoring Program to explicitly specify that the following structures are included in the program.* Appendix R diesel generator foundation (IP3)* Appendix R diesel generator-fuel oil tank vault (IP3)" Appendix R diesel generator switchgear and enclosure (IP3)* city water storage tank foundation

  • condensate storage tanks foundation (IP3)* containment access facility and annex (IP3)" discharge canal (IP2/3)* emergency lighting poles and foundations (IP2/3)* fire pumphouse (IP2)" fire protection pumphouse (IP3)* 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 (IP1)* primary water storage tank foundation (IP3)* refueling water storage tank foundation (IP3)* security access and office building (IP3)* service water pipe chase (IP2/3)* service water valve pit (IP3)* superheater stack" transformer/switchyard 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)" HVAC duct supports" jib cranes* manholes and duct banks* manways, hatches and hatch covers" monorails I P2: September 28, 2013 IP3: December 12, 2015 NL-07-039 N L-07-153 NL-08-057 A.2.1.35 A.3.1.35 B.1.36 Audit items 86, 87, 88, 417______ a ______________________________________________________

L ________________

L ___________

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NL-11-090 Attachment 2 Page 11 of 17# COMMITMENT IMPLEMENTATION SOURCE RELATED SCHEDULE LRA SECTION I_ I I/ AUDIT ITEM S 0 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 groundwater samples to assess aggressiveness of groundwater to concrete on a periodic basis (at least once every five years). IPEC 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, IPEC 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 of the water control structure once per 3 years rather than the normal frequency of once per 5 years during the PEO.NL-08-127 Audit Item 360 Audit Item 358 NL-1 1-090 Attachment 2 Page 12 of 17 COMMITMENT IMPLEMENTATION SOURCE RELATED SCHEDULE LRA SECTION/ AUDIT ITEM Enhance the Structures Monitoring Program to include more detailed quantitative acceptance criteria NL-1 1-032 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 (PEO).26 Implement the Thermal Aging Embrittlement of Cast IP2: NL-07-039 A.2.1.36 Austenitic Stainless Steel (CASS) Program for IP2 September 28, A.3.1.36 and P3 as described in LRA Section B.1.37. 2013 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 2015 of Cast Austenitic Stainless Steel (CASS) Program.27 Implement the Thermal Aging and Neutron Irradiation IP2: NL-07-039 A.2.1.37 Embrittlement of Cast Austenitic Stainless Steel September 28, A.3.1.37 (CASS) Program for IP2 and IP3 as described in LRA 013 B.1.38 Section B.1.38. NL-07-153 Audit item IP3: 173 This new program will be implemented consistent with December 12, the corresponding program described in NUREG- 2015 1801 Section XI.M13, Thermal Aging and Neutron Embrittlement of Cast Austenitic Stainless Steel (CASS) Program.28 Enhance the Water Chemistry Control -Closed IP2: NL-07-039 A.2.1.39 Cooling Water Program to maintain water chemistry of September 28, A.3.1.39 the IP2 SBO/Appendix R diesel generator cooling 013 B.1 .40 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.

29 Enhance the Water Chemistry Control -Primary and 1P2: NL-07-039 A.2.1.40 Secondary Program for IP2 to test sulfates monthly in September 28, B.1.41 Seconary rogra for013 the RWST with a limit of <150 ppb. 2013 30 ~~I P2: N-739 A.2.1 .41 30 For aging management of the reactor vessel internals, September228, A.3.1.41 IPEC will (1) participate in the industry programs for 2081 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, 013 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.

NL-1 1-090 Attachment 2 Page 13 of 17# COMMITMENT IMPLEMENTATION SOURCE RELATED SCHEDULE LRA SECTION/ AUDIT ITEM 31 Additional P-T curves will be submitted as required 1P2: NL-07-039 A.2.2.1.2 per 10 CFR 50, Appendix G prior to the period of September 28, A.3.2.1.2 extended operation as part of the Reactor Vessel 2013 4.2.3 Surveillance Program. I P3: December 12, 2_015 32 As required by 10 CFR 50.61 (b)(4), IP3 will submit a IP3: NL-07-039 A.3.2.1.4 plant-specific safety analysis for plate B2803-3 to the December 12, 4.2.5 NRC three years prior to reaching the RTPTS 2015 NL-08-127 screening criterion.

Alternatively, the site may choose to implement the revised PTS rule when approved.33 At least 2 years prior to entering the period of extended operation, for the locations identified in LRA Table 4.3-13 (IP2) and LRA Table 4.3-14 (IP3), under the Fatigue Monitoring Program, IP2 and IP3 will implement one or more of the following:

(1) Consistent with the Fatigue Monitoring Program, Detection of Aging Effects, update the fatigue usage calculations using refined fatigue analyses to determine valid CUFs less than 1.0 when accounting 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 CUF.2. Additional plant-specific locations with a valid CUF may be evaluated.

In particular, the pressurizer lower shell will be reviewed to ensure the surge nozzle remains the limiting component.

3. Representative CUF values from other plants, adjusted to or enveloping the IPEC plant specific external loads may be used if demonstrated applicable to IPEC.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.IP2: September 28, 2011 P3: December 12, 2013 Complete NL-07-039 NL-07-153 NL-08-021 NL-10-082 A.2.2.2.3 A.3.2.2.3 4.3.3 Audit item 146 J I NL-1 1-090 Attachment 2 Page 14 of 17# COMMITMENT IMPLEMENTATION SOURCE RELATED SCHEDULE LRA SECTION/ AUDIT ITEM 34 1P2 SBO / Appendix R diesel generator will be April 30, 2008 NL-07-078 2.1.1.3.5 installed and operational by April 30, 2008. This Complete NL-08-074 committed change to the facility meets the requirements of 10 CFR 50.591(1) and, therefore, a 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 SP2: 20, A I sample area of IP2 containment liner affected by the September 28, 27 1973 event behind the insulation, prior to entering the 013 extended period of operation, to assure liner degradation is not occurring in this area.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 extended period of operation, to assure liner degradation is not occurring in this area.Any degradation will be evaluated for updating of the NL-09-018 containment liner analyses as needed.1P2: NL-08-127 Audit Item 36 Perform a one-time Inspection and evaluation of a Sptb 28, 359 sample of potentially affected IP2 refueling cavity September 28, 359 concrete prior to the period of extended operation.

013 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 will 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.

A sample of leakage fluid will be analyzed to NL-09-079 determine the composition of the fluid. If additional core samples are taken prior to the end of the first ten years of the period of extended operation, a sample of leakage fluid will be analyzed.37 Enhance the Containment Inservice Inspection (CII- SP2: NL-08-127 Audit Item IWL) Program to include inspections of the September 28, 361 containment using enhanced characterization of 013 degradation (i.e., quantifying the dimensions of noted lP3: indications through the use of optical aids) during the December 12, period of extended operation.

The enhancement 2015 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-1 1-090 Attachment 2 Page 15 of 17# COMMITMENT IMPLEMENTATION SOURCE RELATED SCHEDULE LRA SECTION/ AUDIT ITEM 1P2: NL-08-143 4.2.1 38 For Reactor Vessel Fluence, should future core I eP tNmber loading patterns invalidate the basis for the projected September 28, values of RTpts or CvUSE, updated calculations will 013 be provided to the NRC. IP3: December 12, 2015 39 Deleted NL-09-079 40 Evaluate plant specific and appropriate industry IP2: NL-09-106 B.1.6 operating experience and incorporate lessons learned September 28, B.1.22 in establishing appropriate monitoring and inspection 013 B.1.23 frequencies to assess aging effects for the new aging IP3: B.1.25 management programs.

Documentation of the De r1 B.1.25 operating experience evaluated for each new program December 12, B.1.27 will be available on site for NRC review prior to the B.1.28 period of extended operation.

B. 1.33 B. 1.37 B.1.38 IP:NL-11-032 N/A 41 IPEC will perform an inspection of steam generators AP2: the for both units to assess the condition of the divider fter the plate assembly.

The examination technique used will beginning of the be capable of detecting PWSCC in the steam PEO and Pprior generator divider plate assemblies.

The IP2 steam to September generator divider plate inspections will be completed 28, 2023 NL- 11-074 within the first ten years of the period of extended NL-1 1-090 operation (PEO). The IP3 steam generator divider Pro totheen Prior to the end plate inspections will be completed within the first of the first refueling outage following the beginning of the PEO.refueling outage following the beginning of the PEO.

NL-1 1-090 Attachment 2 Page 16 of 17 COMMITMENT IMPLEMENTATION SOURCE RELATED SCHEDULE LRA SECTION I1 / AUDIT ITEM 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.Each plan will consist of two options.Option 1 (Analysis)

IPEC will perform an analytical evaluation redefining the pressure boundary in which the tube-to-tubesheet weld is no longer included and, therefore, is not required for reactor coolant pressure boundary function.

The redefinition of the reactor coolant pressure boundary must wi4l-be approved by the NRC submitt as pa#t-ef a license amendment request requiring approval fTero the NRG.Option 2 (Inspection)

IPEC will perform a one-time inspection of a representative number of tube-to-tubesheet welds in each steam generator to determine if PWSCC cracking is present. If weld cracking is identified:

a. The condition will be resolved through repair or engineering evaluation to justify continued service, as appropriate, and b. An ongoing monitoring program will be established to perform routine tube-to-tubesheet weld inspections for the remaining life of the steam generators.

NL-1 1-032 NL-1 1-074 NL-1 1-090 N/A IP2: Prior to March 2024 Septembw 28O,202 IP3: Prior to the end of the first refueling outage following the beginning of the PEO. Deee.I P2: Between March_020 and March 2024 1P3: Prior to the end of the first refueling outage following the beginning of the PEO.43 IPEC will review 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.

If more limiting locations are identified, the most limiting location will be evaluated 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.IP2: Prior to September 28, 2013 IP3: Prior to December 12, 2015 NL-1 1-032 4.3.3 NL-1 1-090 Attachment 2 Page 17 of 17 COMMITMENT IMPLEMENTATION SOURCE RELATED SCHEDULE LRA SECTION/ AUDIT ITEM 44 IPEC will include written explanation and justification ithin 60 days NL-1 1-032 N/A of any user intervention in future evaluations using the f issuance of the renewed WESTEMS "Design CUF" module. pertng operating license.45 IPEC will not use the NB-3600 option of the ithin 60 days NL-1 1-032 N/A 45 IPECf issuance of WESTEMS program in future design calculations until he renewed the renewed the issues identified during the NRC review of the operating program has been resolved, license.r IP2: NL-11-032 N/A 46 Include in the IP2 ISI Program that IPEC will perform Prior to twenty-five volumetric weld metal inspections of socket welds during each 10-year ISI interval September 28, NL-11-074 scheduled as specified by IWB-2412 of the ASME Section XI Code 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.

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