NL-08-143, Additional Information Regarding License Renewal Application - Reactor Vessel Fluence Clarification

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Additional Information Regarding License Renewal Application - Reactor Vessel Fluence Clarification
ML082760402
Person / Time
Site: Indian Point  Entergy icon.png
Issue date: 09/24/2008
From: Dacimo F
Entergy Nuclear Northeast, Entergy Nuclear Operations
To:
Document Control Desk, Office of Nuclear Reactor Regulation
References
NL-08-143
Download: ML082760402 (23)
v • d • e


Text

Entergy Nuclear Northeast Indian Point Energy Center 450 Broadway, GSB P.O. Box 249 Buchanan, NY 10511-0249 Tel (914) 788-2055 Fred R. Dacimo Vice President License Renewal September 24, 2008 Indian Point Units 2 & 3 Docket Nos. 50-247 & 50-286 NL-08-143 U.S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20555-0001

SUBJECT:

Additional Information Regarding License Renewal Application -

Reactor Vessel Fluence Clarification

Dear Sir or Madam:

Entergy Nuclear Operations, Inc is providing, in Attachments 1, and 2, a reactor vessel fluence clarification, and revision 6 of the IPEC commitment list, pertaining to the License Renewal Application for Indian Point 2 and Indian Point 3. The additional information provided in this transmittal provides clarifications and additional information to previously submitted information in response to staff and audit questions. consists of a revision to the list of regulatory commitments providing one additional commitment associated with the reactor vessel fluence clarification. If you have any questions or require additional information, please contact Mr. R. Walpole, Manager, Licensing at (914) 734-6710.

I declare under penalty of perjury that the foregoing is true and correct. Executed on 9 Sinc ey, F R. Dacimo Vice President License Renewal

NL-08-143 Docket Nos. 50-247 & 50-286 Page 2 of 2 Attachments: 1. Reactor Vessel Fluence Clarification

2. IPEC Commitment List Revision 6 cc: Mr. Bo M. Pham, NRC Environmental Project Manager Ms. Kimberly Green, NRC Safety Project Manager Mr. John P. Boska, NRC NRR Senior Project Manager Mr. Samuel J. Collins, Regional Administrator, NRC Region I Mr. Sherwin E. Turk, NRC Office of General Counsel, Special Counsel IPEC NRC Senior Resident Inspectors Office Mr. Robert Callender, Vice President for Programs, NYSERDA Mr. Paul Eddy, New York State Dept. of Public Service

ATTACHMENT 1 TO NL-08-143 REACTOR VESSEL FLUENCE CLARIFICATION REGARDING LICENSE RENEWAL APPLICATION ENTERGY NUCLEAR OPERATIONS, INC INDIAN POINT NUCLEAR GENERATING UNIT NOS. 2 and 3 DOCKETS 50-247 and 50-286

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

REACTOR VESSEL FLUENCE CLARIFICATION Reactor Vessel Fluence In Section II F of 10 CFR 50 Appendix G, the beltline region of the reactor vessel is defined as "The region of the reactor vessel (shell material including welds, heat affected zones, and plates or forgings) that directly surrounds the effective height of the active core and adjacent regions of the reactor vessel that are predicted to experience sufficient radiation damage to be considered in the selection of the most limiting material with regard to radiation damage."

Tables 4.2-1 through 4.2-6 of the LRA, provide information on components in the beltline for IP2 and IP3. Additional reactor pressure vessel components are exposed to projected neutron fluences greater than 1.OE1 7 n/cm 2 . At the request of the NRC staff, additional information is provided on these reactor vessel components. Though not limiting materials and thus, not part of the beltline, these components are evaluated for radiation induced material damage.

The maximum neutron fluences at various axial locations for the Indian Point Unit 2 reactor pressure vessel were calculated using an NRC approved methodology (WCAP-15557-RO, "Qualification of the Westinghouse Pressure Vessel Neutron Fluence Evaluation Methodology")

that meets the requirements of Regulatory Guide 1.190, "Calculational and Dosimetry Methods for Determining Pressure Vessel Neutron Fluence," March 2001.

The IP2 48 EFPY clad/base metal interface fluence at each axial location is as follows.

Table 1 Component IP2 Maximum Fluence (n/cm 2)

Outlet Nozzles to Nozzle Shell Welds (lowest extent) < 1.OOE17 Inlet Nozzles to Nozzle Shell Welds (lowest extent) < 1.00E17 Nozzle Shell Plates 2.26E17 Nozzle Shell Longitudinal Welds 1.95E17 Nozzle Shell to Intermediate Shell Circumferential 2.88E17 Weld Each IPEC reactor pressure vessel has the following dimensions relative to the active fuel stack.

Table 2 Component Axial Location' (cm)

Outlet Nozzles to Nozzle Shell Welds (lowest extent) 272.02 Inlet Nozzles to Nozzle Shell Welds (lowest extent) 266.94 Nozzle Shell Plates 237.81 to 485.93 Nozzle Shell Longitudinal Welds 237.81 to 485.93 Nozzle Shell to Intermediate Shell Circumferential 234.47 to 237.81 Weld Intermediate Shell Plates 2 -38.66 to 234.47

'Axial elevation 0.0 is the midplane of the active fuel stack.

2 Intermediate shell plates are evaluated in LRA Tables 4.2-1 through 4.2-6.

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

REACTOR VESSEL FLUENCE CLARIFICATION IP3 has implemented flux reduction measures resulting in lower projected peak fluences at 48 EFPY. Since the IP2 and IP3 vessel geometries are the same, IP3 maximum fluences are estimated using IP2 fluences as follows.

IP2 48 EFPY peak fluence = 1.906E1 9 (LRA Section 4.2.1)

IP3 48 EFPY peak fluence = 1.560E1 9 (LRA Section 4.2.1)

% fluence difference for IP3 = (1.906E19- 1.560E19)/1.906E19*100 = 18.2% less Reducing each fluence in Table 1 by 18.2% yields IP3 48 EFPY clad/base metal interface fluences at each axial location as shown below in Table 3.

Table 3 Component IP3 Maximum Fluence (n/cm 2)

Outlet Nozzles to Nozzle Shell Welds (lowest extent) < 1.OOE17 Inlet Nozzles to Nozzle Shell Welds (lowest extent) < 1.00E1 7 Nozzle Shell Plates 1.85E17 Nozzle Shell Longitudinal Welds 1.60E17 Nozzle Shell to Intermediate Shell Circumferential Weld 2.36E17 Determination of Charpy upper-shelf energy (CvUSE) is described in LRA Section 4.2.2.

Additional information for IPEC reactor vessel components projected to exceed 1.00E17 n/cm 2 is provided in Tables 4 and 5 below.

Determination of the reference temperature for pressurized thermal shock (RTPTS) is described in LRA Section 4.2.5. Additional information for IPEC reactor vessel components projected to exceed 1.00El 7 n/cm 2 is provided in Tables 6 and 7 below.

The projected values for CvUSE and RTPTS shown in Tables 4 through 7 clearly demonstrate that these components are well within the respective screening criteria established by 10 CFR 50 Appendix G and 10 CFR 50.61.

Should future fuel loading patterns invalidate the basis for the projected values of RTpts or CvUSE, updated calculations will be provided to the NRC.

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

REACTOR VESSEL FLUENCE CLARIFICATION Table 4 IP2 Upper Shelf Energy Data for 48 Effective Full-Power Years (EFPY)

Fluence Fluence Un- 48 Reactor Vessel  % Drop EFPY RG 1.99 Material Material Vessel %Cu Location (Beltline Ident Type Heat # CladIBM 1/4T irradiated in USE USE at Position Identification) 48 EFPY 48EFPY USE 1/4 T Nozzle Shell Plates B2001-1 A302BM B4679 4 2.26E17 1.35E17 0.201 693 10.5 61.8 1.2 Nozzle Shell Plates B2001-2 A302BM B4701 4 2.26E17 1.35E17 0.141 63.53 8.3 58.2 1.2 Nozzle Shell Plates B2001-3 A302BM B9870 4 2.26E17 1.35E17 0.191 693 10.1 62.0 1.2 Nozzle Shell 1-042 Linde W52142 1.95E17 1.16E17 0.2135 1215 18.5 98.6 2.2 Longitudinal Welds A/B/C 1092 Nozzle Shell to 8-042 Linde W52142 2.88E17 1.72E17 0.2135 1215 20.3 96.4 2.2 Intermediate Shell 1092 Circumferential Weld 1 UFSAR 2

Table 4.2-7 UFSAR Table 4.2-2 3

UFSAR Table 4.2-8 4

UFSAR Table 4.2-6 5

RVID2 (Heat #W5214, Linde 1092, IP2 intermediate axial welds)

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

REACTOR VESSEL FLUENCE CLARIFICATION Table 5 IP3 Upper Shelf Energy Data for 48 Effective Full-Power Years (EFPY)

Fluence Fluence Un- 48 Reactor Vessel Material Material Vessel  % Drop EFPY RG 1.99 Location (Beltline Ident Type Heat # Clad/BM 1/4T %Cu irradiated in USE USE at Position Identification) 48 EFPY 48EFPY USE 1/4 T Nozzle Shell Plates B2801-1 A302BM B53911 1.85E17 1.10E17 0.211 621 10.3 55.6 1.2 Nozzle Shell Plates B2801-2 A302BM B53941 1.85E17 1.10E17 0.201 651 10.0 58.5 1.2 1

Nozzle Shell Plates B2801-3 A302BM A0516 1.85E17 1.10E17 0.221 851 10.7 75.9 1.2 Nozzle Shell 1-042 Linde W5214 1 1.60E17 9.51 E16 0.2132 1212 17.7 99.6 2.2 Longitudinal Welds A/B/C 1092 Nozzle Shell to 8-042 Linde 272041 2.36E17 1.40E17 0.2033 943 12.5 -82.3 1.2 Intermediate Shell 1092 Circumferential Weld 1 BF0204, Letter from William J Cahill to NRC, Indian Point 3 Reactor Vessel Surveillance Program, March 8,1978 2 RVID2 (Heat #W5214, Linde 1092, IP2 intermediate axial welds) 3 RVID2 (Heat #27204, Linde 1092, Diablo Canyon Unit 1 lower shell axial welds)

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

REACTOR VESSEL FLUENCE CLARIFICATION Table 6 IP2 Pressurized Thermal Shock for 48 Effective Full-Power Years (EFPY)

Fluence Un- 48 Reactor Vessel Material Material Heat Vessel Un- 48 Method

%Cu %NiC~aIBM FF Chemistry irradiated ARTNDT Margin EFPY R Location (Beltline MaeilMtra et %Cu %Ni Clad/BM FF RG Identification) Ident Type Number (1019 Factor RTNDT (°F) (°F) RTpTs 1.99 n/cm 2) (°F) (°F)

Nozzle Shell B2001-1 A302BM B4679 0.20 0.501 0.0226 0.185 137.0 242 25.4 25.4' 74.8 1.1 Plates Nozzle Shell B2001-2 A302BM B4701 0.14 0.431 0.0226 0.185 92.4 182 17.1 17.15 52.3 1.1 Plates Nozzle Shell B2001-3 A302BM B9870 0.19 0.501 0.0226 0.185 131.0 252 24.3 24.3' 73.6 1.1 Plates Nozzle Shell 1-042 Linde W5214 0.213 1.0073 0.0195 0.169 251.84 -56' 42.6 40.1' 26.8 2.1 Longitudinal A/B/C 1092 Welds Nozzle Shell to 8-042 Linde W5214 0.213 1.0073 0.0288 0.214 251.84 -563 54.0 43.46 41.4 2.1 Intermediate 1092 Shell Circumferential Weld UFSAR Table 4.2-7 2 UFSAR Table 4.2-8 3 RVID2 (Heat #W5214, Linde 1092, IP2 intermediate axial welds) 4 NL-08-014, ML080250027, Letter from Fred Dacimo to NRC, Clarifications to Reactor Vessel Surveillance Program and Neutron Embrittlement Time-Limited Aging Analyses and Audit Item #105; and Revision to License Renewal Regulatory Commitment List, January 18,2008 6 GL = 0, orA = ARTNDT

/2 UL = 17, O'A= 1/2 (ARTNDT / 2)

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

REACTOR VESSEL FLUENCE CLARIFICATION Table 7 IP3 Pressurized Thermal Shock for 48 Effective Full-Power Years (EFPY)

Fluence Un- 48 Recator Vseli Material Material Heat Vessel Chemistry irradiated ARTNDT Margin EFPY RG Locationiatione Ident Type Number %N 019 Factor RTNDT (*F) (°F) RTPTS 1.99 Identification) (101(F9(F 19 n/cm2 ) (°F) (°F)

Nozzle Shell B2801-1 A302BM B5391 0.21 0.481 0.0185 0.164 139.4 341 22.8 22.85 79.7 1.1 Plates Nozzle Shell B2801-2 A302BM B5394 0.20 0.501 0.0185 0.164 137.0 441 22.5 22.55 88.9 1.1 Plates Nozzle Shell B2801-3 A302BM A0516 0.22 0.541 0.0185 0.164 152.9 31 25.1 25.15 53.1 1.1 Plates Nozzle Shell 1-042 Linde W5214 0.213 1.012' 0.0160 0.149 251.83 -562 37.6 38.86 20.4 2.1 Longitudinal A/B/C 1092 Welds Nozzle Shell to 8-042 Linde 27204 0.203 1.024 0.0236 0.190 226.8 -56e 43.2 54.97 42.1 1.1 Intermediate 1092 Shell Circumferential Weld 1 BF0204, Letter from William J Cahill to NRC, Indian Point 3 Reactor Vessel Surveillance Program, March 8, 1978 2 RVID2 (Heat #W5214, Linde 1092, IP2 intermediate axial welds) 3 NL-08-014, ML080250027, Letter from Fred Dacimo to NRC, Clarifications to Reactor Vessel Surveillance Program and Neutron Embrittlement Time-Limited Aging Analyses and Audit Item #105; and Revision to License Renewal Regulatory Commitment List, January 18,2008 4 RVID2 (Heat #27204, Linde 1092, Diablo Canyon Unit 1 lower shell axial welds) 5O"L = 0, OrA = ARTNDT

/2 6 C = 17, oA = 1/2 (ARTNDT 7

/ 2)

C0= 17, oA = ARTNDT/ 2

ATTACHMENT 2 TO NL-08-143 IPEC COMMITMENT LIST REVISION 6 REGARDING LICENSE RENEWAL APPLICATION ENTERGY NUCLEAR OPERATIONS, INC INDIAN POINT NUCLEAR GENERATING UNIT NOS. 2 and 3 DOCKETS 50-247 and 50-286

List of Regulatory Commitments Rev. 6 The following table identifies those actions committed to by Entergy in this document.

Changes are shown as strikethroughs for deleti*R and underlines for additions.

  1. COMMITMENT IMPLEMENTATION SOURCE RELATED SCHEDULE LRA SECTION

/ AUDIT ITEM 1 Enhance the Aboveground Steel Tanks Program for IP2: 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, 013 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 IP2: 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 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 1 preload and loss of material for all external bolting.

3 Implement the Buried Piping and Tanks Inspection IP2: 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.

  1. COMMITMENT IMPLEMENTATION SOURCE RELATED SCHEDULE LRA SECTION I I 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 B.1.9 turbine fuel oil storage tanks, IP2 and IP3 EDG fuel oil NL-07-153 Audit items day tanks, IP2 SBO/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 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 I I

COMMITMENT IMPLEMENTATION SOURCE RELATED SCHEDULE LRA SECTION

/ AUDIT ITEM 5 Enhance the External Surfaces Monitoring Program SP2: 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 review for license renewal in accordance with 10 CFR IP3:

54.4(a)(1) and (a)(3). Inspections shall include areas surrounding the subject systems to identify hazards to De r1 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 SP2: NL-07-039 A.2.1.11 monitor steady state cycles and feedwater cycles or Speb 28 1. 11 perform an evaluation to determine monitoring is not 013 Audt1te required. Review the number of allowed events and i 15 resolve discrepancies between reference documents 164 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 September 28, A.3.1.12 external surfaces of the IP3 RCP oil collection systems for loss of material each refueling cycle. 013 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.

  1. COMMITMENT IMPLEMENTATION SOURCE RELATED SCHEDULE LRA SECTION

/ AUDIT ITEM Enhance the Fire Water Program to include inspection IP2: NL-07-039 A.2.1.13 8

September 28, A.3.1.13 of IP2 and IP3 hose reels for evidence of corrosion.

2013 B11 Acceptance criteria will be revised to verify no NL-07-153 Audit Items unacceptable signs of degradation. lP3: 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 2015 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.

9 Enhance the Flux Thimble Tube Inspection Program SP2: NL-07-039 A.2.1.15 for IP2 and IP3 to implement comparisons to wear September 28, A.3.1.15 rates identified in WCAP-12866. Include provisions to 013 B.1.16 compare data to the previous performances and perform evaluations regarding change to test DP e1 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.

  1. COMMITMENT IMPLEMENTATION SOURCE RELATED SCHEDULE LRA SECTION

/AUDIT ITEM 10 Enhance the Heat Exchanger Monitoring Program for IP2: NL-07-039 A.2.1.16 IP2 and IP3 to include the following heat exchangers September 28, A.3.1.16 in the scope of the program. 2013 B.1.17, 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
  • SBO/Appendix R diesel jacket water heat exchanger (1P2 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 unacceptable signs of degradation.

11 Enhance the ISI Program for IP2 and IP3 to provide IP2: NL-07-039 A.2.1.17 periodic visual inspections to confirm the absence of September 28, A.3.1.17 aging effects for lubrite sliding supports used in the 2013 NL-07-153 B.1.18 Audit item steam generator and reactor coolant pump support IP3: 59 systems. December 12, 12015

  1. COMMITMENT IMPLEMENTATION SOURCE RELATED SCHEDULE LRA SECTION I AUDIT ITEM IP2: NL-07-039 A.2.1.18 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 the program. 2013 B.1.19 IP3:

December 12, 2015 Enhance the Metal-Enclosed Bus 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 B.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 reference to "re-torquing" connections for phase bus maintenance and bolted connection maintenance.

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 IP3:

December 12, 12015 1 1

COMMITMENT IMPLEMENTATION SOURCE RELATED SCHEDULE LRA SECTION

/ AUDIT ITEM IP2: NL-07-039 A.2.1 .22 A.2.1.22 15 Implement the Non-EQ Inaccessible Medium-Voltage embe 28, IP2 and IP3 as described in LRA September 28, A.3.1.22 Cable B.1.23. for SectionProgram 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.

16 Implement the Non-EQ Instrumentation Circuits Test 1P2: NL-07-039 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 015 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 013 B.1.26 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.

COMMITMENT IMPLEMENTATION SOURCE RELATED SCHEDULE LRA SECTION

/ AUDIT ITEM 19 Implement the One-Time Inspection Program for IP2 IP2: NL-07-039 A.2.1.26 and IP3 as described in LRA Section B.1.27. September 2013 28, A.3.1.26 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 IP2: 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 current licensing basis through the period of extended 2015 operation.

22 Enhance the Reactor Vessel Surveillance Program for P2: 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 P3:

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 IP2: 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, 2_015 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 013 B.1.35 operational assessment performed for the prior IP3:

operating cycle with differences evaluated. December 12, 015

COMMITMENT IMPLEMENTATION SOURCE RELATED SCHEDULE LRA SECTION

_ 1_1 / 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 B.1.36 NL-07-153

  • Appendix R diesel generator foundation (IP3)

IP3: Audit items

  • Appendix R diesel generator fuel oil tank vault December 12, 86, 87, 88, (IP3) 2015 NL-08-057 417

" 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)
  • 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 (IP2)
  • 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 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 1 .5. .5.

COMMITMENT IMPLEMENTATION SOURCE I RELATED SCHEDULE LRA SECTION

_/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 NL-08-127 Audit Item and IP3 to perform an engineering evaluation of 360 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 Audit Item and IP3 to perform inspection of the degraded areas 358 of the water control structure once per 3 years rather than the normal frequency of once per 5 years during the PEO.

  1. COMMITMENT IMPLEMENTATION SOURCE RELATED SCHEDULE LRA SECTION

/ AUDIT ITEM IP2: NL-07-039 A.2.1.36 26 Implement the Thermal Aging Embrittlement of Cast A.3.1.36 Austenitic Stainless Steel (CASS) Program for IP2 September 28,.1.3 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 2015 1 of Cast Austenitic Stainless Steel (CASS) Program.

Implement the Thermal Aging and Neutron Irradiation IP2: NL-07-039 A.2.1.37 27 Embrittlement of Cast Austenitic Stainless Steel September 28, A.3.1.37 2013B. 1.38 and IP3 as described in LRA 013 (CASS) Program for IP2 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- 2015 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 Sptb 28, A.3.1.39 Cooling Water Program to maintain water chemistry of September 28, A.3.1.39 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 015 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 IP2: NL-07-039 A.2.1.40 September 28, B.1.41 Secondary Program for IP2 to test sulfates monthly in the RWST with a limit of <150 ppb. 013 For aging management of the reactor vessel internals, IP2: NL-07-039 A.2.1.41 30 IPEC will (1) participate in the industry programs for September 28, A.3.1.41 investigating and managing aging effects on reactor 011 internals; (2) evaluate and implement the results of lP3:

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.

IP2: NL-07-039 A.2.2.1.2 A.2.2.1.2 31 Additional P-T curves will be submitted as required N per 10 CFR 50, Appendix G prior to the period of September 28,.2.

extended operation as part of the Reactor Vessel Surveillance Program. IP3:

December 12, 12015 1

  1. COMMITMENT IMPLEMENTATION SOURCE RELATED SCHEDULE LRA SECTION

/ AUDIT ITEM 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.

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 2011 4.3.3 Table 4.3-13 (IP2) and LRA Table 4.3-14 (IP3), under 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, 2013 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 ifdemonstrated 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.

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 50.59(c)(1) and, therefore, a license amendment pursuant to 10 CFR 50.90 is not required.

  1. COMMITMENT IMPLEMENTATION SOURCE RELATED SCHEDULE LRA SECTION

/ AUDIT ITEM 35 Perform a one-time inspection of representative SP2: NL-08-127 Audit Item sample area of IP2 containment liner affected by the September 28, 013 1973 event behind the insulation, prior to entering the 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.

IP2: NL-08-127 Audit 359 Item 36 Perform a one-time Inspection and evaluation of a Sptb 28, 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.

37I-~ P2: NL-08-127 Audit 361Item 37 Enhance the Containment Inservice Inspection (CII- September 28, IWL) Program to include inspections of the 2013 containment using enhanced characterization of 013 degradation (i.e., quantifying the dimensions of noted indications through the use of optical aids) during the D e r1 period of extended operation. The enhancement De 2015 r1 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.

IP2: NL-08-143 4.2.1 38 For Reactor Vessel Fluence, should future core September 28 Ioadinq patterns invalidate the basis for the proiected 2013 values of RTpts or CvUSE, updated calculations will be provided to the NRC. IP3:

December 12, 2015

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