ML13186A179

IR 05000247-13-009; 05/6/2013 to 05/23/2013; Indian Point Nuclear Generating Unit 2; License Renewal Team Inspection

ML13186A179
Person / Time
Site:	Indian Point
Issue date:	07/05/2013
From:	James Trapp Engineering Region 1 Branch 1
To:	Ventosa J Entergy Nuclear Operations
References
IR-13-009
Download: ML13186A179 (43)

See also: IR 05000247/2013009

Text

UNITED STATES

NUCLEAR REGULATORY COMMISSION

REGION I

2100 RENAISSANCE BOULEVARD, SUITE 100

KING OF PRUSSIA, PENNSYLVANIA 19406-2713

July 5, 2013

Mr. John Ventosa

Site Vice President

Entergy Nuclear Operations, Inc.

Indian Point Energy Center

450 Broadway, GSB

Buchanan, NY 10511-0249

SUBJECT: INDIAN POINT NUCLEAR GENERATING UNIT 2 - NRC LICENSE RENEWAL

TEAM INSPECTION REPORT 05000247/2013009

Dear Mr. Ventosa:

On May 23, 2013, the U.S. Nuclear Regulatory Commission (NRC) completed a team

inspection at your Indian Point Nuclear Generating Unit 2. The enclosed inspection report

documents the inspection results, which were discussed on May 23, 2013 with Mr. Donald

Mayer and other members of your staff.

The inspectors examined activities conducted by your staff to complete commitments Entergy

made as part of your application for a renewed facility operating license. The inspectors also

reviewed selected procedures and records, observed activities, and interviewed personnel.

No findings were identified during this inspection. The team concluded that Entergy had made

sufficient progress to complete our review of 30 commitments during this inspection. Eleven of

the commitments reviewed during this inspection were determined to merit additional

assessment during our planned follow-up license renewal inspection scheduled for September

2013.

In accordance with 10 CFR 2.390 of the NRCs Rules of Practice, a copy of this letter, its

enclosure, and your response (if any) will be available electronically for public inspection in the

NRC Public Document Room or from the Publicly Available Records (PARS) component of

NRCs Agencywide Document Access and Management System (ADAMS). ADAMS is

accessible from the NRC website at http://www.nrc.gov/reading-rm/adams.html (the Public

Electronic Reading Room).

Sincerely,

/RA/

James M. Trapp, Chief

Engineering Branch 1

Division of Reactor Safety

Docket No. 50-247

License No. DPR-26

ML13186A179

Non-Sensitive Publicly Available

SUNSI Review

Sensitive Non-Publicly Available

OFFICE RI/DRS RI/DRP RI/DRS

NAME GMeyer/MM SRutenkroger JTrapp

DATE 7/3/13 7/3/13 7/5/13

J. Ventosa 2

Enclosure:

Inspection Report 05000247/2013009

w/Attachment: Supplementary Information

cc w/encl: Distribution via ListServ

J. Ventosa 3

Distribution w/encl: (via E-mail)

W. Dean, RA

D. Lew, DRA

D. Roberts, DRP

A. Burritt, DRP

C. Miller, DRS

J. Rogge, DRS

S. Rutenkroger, DRP

T. Setzer, DRP

S. McCarver, DRP

L. McKown, DRP

S. Stewart, DRP, SRI

K. Dunham, DRP, RI

A. Patel, DRP, RI

D. Hochmuth, DRP, AA

V. Campbell, RI OEDO

RidsNrrPMIndianPoint Resource

RidsNrrDorlLpl1-1 Resource

ROPreport Resource

U.S. NUCLEAR REGULATORY COMMISSION

REGION I

Docket No.: 50-247

License No.: DPR-26

Report No.: 05000247/2013009

Applicant: Entergy Nuclear Northeast (Entergy)

Facility: Indian Point Energy Center Unit 2

Location: 450 Broadway

Buchanan, NY 10511-0249

Dates: May 6-10 and 20-23, 2013

Inspectors: G. W. Meyer, Senior Reactor Inspector, Team Leader

E. H. Gray, Senior Reactor Inspector

W. C. Holston, Senior Mechanical Engineer

M. C. Modes, Senior Reactor Inspector

J. E. Richmond, Senior Reactor Inspector

M. P. Patel, Operations Engineer

S. K. Chaudhary, Reactor Inspector

E. M. Keighley, Project Engineer

C. H. Ng, Mechanical Engineer

Approved By: James M. Trapp, Chief

Engineering Branch 1

Division of Reactor Safety

i Enclosure

SUMMARY OF FINDINGS

IR 05000247/2013009; 05/6/2013 - 05/23/2013; Indian Point Nuclear Generating Unit 2; License

Renewal Team Inspection.

This report covers an announced two week inspection, using the guidance provided in NRC

inspection procedure Temporary Instruction 2516/001, Review of License Renewal Activities,

of activities conducted by Entergy to complete commitments made to the NRC as a part of the

Indian Point Energy Center, Unit 2, application for a renewed operating license. The

commitments reviewed during this inspection are recorded in Supplement 1 to NUREG-1930,

Safety Evaluation Report Related to the License Renewal of Indian Point Generating Units

Numbers 2 and 3, Attachment 1, dated August 2011, and in other related correspondence.

The inspection also reviewed enhancements made to selected aging programs.

Cornerstones: Initiating Events, Mitigating Systems, and Barrier Integrity

No findings were identified. On a sampling basis, the team concluded that Entergy had made

sufficient progress to complete our review of 30 commitments during this inspection. Eleven of

the commitments reviewed during this inspection were determined to merit additional

assessment during our planned follow-up license renewal inspection scheduled for September

2013.

ii Enclosure

REPORT DETAILS

4. OTHER ACTIVITIES

4OA5 Review of License Renewal Activities (TI 2516/001)

.1 Background

The expiration date of the operating license for Indian Point Unit 2 is midnight on

September 28, 2013. Indian Point Unit 2 meets the criteria in Title 10 of the Code of

Federal Regulations (10 CFR) 2.109(b), Effect of timely renewal application, and will

likely operate beyond the current operating license expiration date. Due to the

Commissions decision to revise the Waste Confidence Decision and Rule and because

of the ongoing Atomic Safety and Licensing Board hearings, the Commission is not

expected to issue a renewed license for Indian Point Unit 2 before the expiration date of

the original license. Therefore, Indian Point is expected to continue operations under the

timely renewal provisions of 10 CFR 2.109(b).

On May 1, 2013, Entergy sent a letter to the Nuclear Regulatory Commission (NRC)

(ML13142A203) describing two actions Entergy plans to complete prior to entering the

period of extended operation (PEO). The first action is that Entergy will submit a letter to

the NRC confirming implementation of the Unit 2 license renewal commitments. The

second Entergy action is to submit a letter to the NRC confirming that the Unit 2 Updated

Final Safety Analysis Report has been updated to include the Unit 2 aging management

programs making them part of the licensing basis by September 28, 2013.

The team used NRC Inspection Manual Temporary Instruction 2516/001 to conduct this

inspection. The Temporary Instruction was written specifically for plants like Indian Point

Unit 2, where the holders of an operating license meet the criteria of 10 CFR 2.109, for

timely renewal, but a final decision by the NRC on the license renewal application is not

expected prior to the period of extended operation. The inspection objectives and

requirements of the Temporary Instruction are to report the status of license renewal

commitment implementation, the status of aging management program implementation,

and to verify the description of programs and activities for managing the effects of aging

are consistent with the Updated Final Safety Analysis Report.

The NRC planned to conduct this two week announced team inspection to assess the

resolution of commitments made by the applicant as part of the license renewal process.

Additionally, the NRC had planned to conduct an additional limited scope one week

inspection in September to address issues meriting additional follow-up based on the

results of this inspection and to review any new issues or commitments.

On a sampling basis, the team concluded that Entergy had made sufficient progress to

complete our review of 30 commitments during this inspection. Eleven of the

commitments reviewed during this inspection were determined to merit additional

assessment during our planned follow-up inspection scheduled for September 2013.

Enclosure

2

The NRC review of four commitments (28, 29, 34 and 36) is documented in NRC

Inspection Report 05000247/2012008 (ML12110A315). Three commitments (11, 32,

and 39), listed in the Safety Evaluation Report, were determined not to be applicable to

Unit 2 and were not reviewed during this inspection.

Sample Selection Process

Temporary Instruction 2516/001 requires that the inspectors select a sample of

completed commitments, license conditions, and aging management programs for

review during the inspection. The reviewed commitments and enhanced aging

management programs were selected based on several attributes including: risk

significance; the results of previous license renewal audits and inspections of aging

management programs; the complexity in implementing a commitment; and the extent to

which the baseline inspection programs will inspect attributes of the commitment or

aging management program.

The commitments reviewed during this inspection are recorded in Supplement 1 to

NUREG-1930, Safety Evaluation Report Related to the License Renewal of Indian Point

Generating Units Numbers 2 and 3, Attachment 1, dated August 2011, Entergy letter to

the NRC (NL-12-174), dated November 29, 2012 (ML12341A180) and in other related

correspondence. For each commitment selected for review, the inspectors reviewed

supporting documents including completed surveillances, conducted interviews,

performed visual inspection of structures and components, and observed selected

activities described below to verify the licensee completed the necessary actions to

comply with the commitments.

The inspectors selectively verified the licensee implemented the aging management

programs, included in the staffs license renewal safety evaluation report, in accordance

with 10 CFR Part 54, Requirements for the Renewal of Operating Licenses for Nuclear

Power Plants. The inspectors verified a selected sample of licensee corrective actions

that were the result of license renewal activities.

The following commitments and enhanced programs were reviewed:

.2 Commitment Reviews

.2.1 Commitment 1: Enhance the Aboveground Steel Tanks Program to perform thickness

measurements of the bottom surfaces of the condensate storage tanks, city water tank,

and fire water tanks once during the first 10 years of the period of extended operation.

Enhance the Aboveground Steel Tanks Program for Indian Point Unit 2 (IP2) and Indian

Point Unit 3 (IP3) to require trending of thickness measurements when material loss is

detected.

a. Inspection Scope

The inspectors observed the external conditions of each of the aboveground tanks in the

license renewal scope during a plant walk down. Entergy had scheduled procedures

and activities to measure the tank bottom thickness and trend thickness changes

Enclosure

3

indicative of degradation. The inspectors reviewed the planned, periodic visual

examinations under EN-DC-178, System Walkdowns, and 2-PI-SA002, Atmospheric

Tanks, External Inspection, for the aboveground water storage tanks. The inspectors

noted that documentation of the condition of coating integrity of external storage tank

walls was specified in EN-DC- 178, but was not addressed in 2-PI-SA002. Condition

Report (CR) CR-IP2-2013-01989 was issued to update procedure 2-PI-SA002 regarding

the condition of coatings.

Findings and Observations

No findings were identified.

.2.2 Commitment 2: Enhance the Bolting Integrity Program to clarify that actual yield

strength is used in selecting materials for low susceptibility to stress crack corrosion

(SCC) and clarify the prohibition on use of lubricants containing MoS2 for bolting. The

Bolting Integrity Program manages loss of preload and loss of material for all external

bolting.

a. Inspection Scope

In NRC Inspection Report 05000247/2012008, the inspectors reviewed the

implementation of the Bolting Integrity Program, but noted that a general statement on

loss of preload and loss of material for external bolting in the commitment had not been

included in the site procedure. The inspectors reviewed the Entergy corporate

procedure for torqueing applications that had superseded the site procedure previously

reviewed. The corporate procedure included statements which addressed the general

statement on external bolting.

Findings and Observations

No findings were identified.

.2.3 Commitment 3: Implement the Buried Piping and Tanks Inspection Program as

described in License Renewal Application (LRA) Section B.1.6. Risk assess buried in-

scope pipe segments and tanks based on the impact of leakage and conditions affecting

the risk for corrosion; classify the pipe segments and tanks as having a high, medium, or

low impact of leakage; establish inspection priority and frequency based on the results of

the risk assessment; and perform inspections using inspection techniques with

demonstrated effectiveness.

a. Inspection Scope

The inspectors conducted a walk down of an excavation which exposed three in-scope

segments of buried piping. Piping coatings were generally in good condition. The

inspectors confirmed that the corporate procedures included criteria for assessing buried

in-scope piping segments and tanks based on the impact of leakage and conditions

affecting risk for corrosion. The inspectors also confirmed that the site procedure,

SEP-UIP-IPEC, Underground Components Inspection Plan, Appendix A, Piping

Enclosure

4

Inspection Information, and Appendix B, Tank Inspection Information, contained a listing

of in-scope piping segments and tanks, each classified as high, medium, or low based

on the impact of leakage. Further, the inspectors reviewed 20 inspection reports, which

Entergy had stated would be completed prior to the period of extended operation. The

inspection technique was excavated direct visual examinations with subsequent

ultrasonic thickness measurements where coating degradation was noted. The

inspections consisted of an acceptable mix of opportunistic and planned inspections with

the majority conducted on piping segments classified as high risk. All of the inspections

provided valued insights into the condition of coatings and backfill quality. Ultrasonic

thickness measurements in locations of coating degradation demonstrated that minimal

or no corrosion of the base metal had occurred.

Findings and Observations

No findings were identified.

.2.4 Commitment 4: Enhance the Diesel Fuel Monitoring Program to include cleaning and

inspection of additional fuel oil tanks, include quarterly sampling and analysis of

additional tanks, include periodic thickness measurements with acceptance criteria of

the bottom surfaces of in-scope fuel oil tanks, change the analysis for water and

particulates to a quarterly frequency for some tanks, and address water removal and

biocide treatment.

a. Inspection Scope

The inspectors reviewed the commitment implementation plan, and program and

implementing procedures, and discussed this commitment with applicable plant staff.

The Diesel Fuel Monitoring Program is an existing program that was enhanced to meet

the commitments. The inspectors reviewed revised diesel fuel handling procedures,

diesel fuel sampling procedures, and chemical addition procedures. Also, the inspectors

reviewed inspection records for the No. 2 fuel oil storage tank, and work orders for

cleaning and inspecting additional tanks.

Findings and Observations

No findings were identified.

.2.5 Commitment 5: Enhance the External Surfaces Monitoring Program to include periodic

inspections of systems in scope and subject to aging management review for license

renewal in accordance with 10 CFR 54.4(a)(1) and (a)(3). Inspections shall include

areas surrounding the subject systems to identify hazards to those systems. Inspections

of nearby systems that could impact the subject systems will include structure, systems,

and components (SSC) that are in scope and subject to aging management review for

license renewal in accordance with 10 CFR 54.4(a)(2).

Enclosure

5

a. Inspection Scope

The inspectors reviewed the commitment implementation plan and program procedures,

and discussed this commitment with applicable plant staff and license renewal

personnel. The inspector noted that EN-DC-178, System Walkdowns, Revision 5

addressed the enhanced inspection scope during walkdowns to include attention

extended to nearby systems that could present a hazard or affect the walked down

system. The inspectors reviewed the site Engineering Standard ENN-MS-S-004-IPEC,

which documented the system categories and their corresponding level of inspection,

including direction to accomplish the enhanced scope of system walkdown and the

surrounding areas. The inspectors noted that the city water tank category classification

in Attachment 7.1 of ENN-MS-S-004-IPEC was not consistent between Unit 2 and

Unit 3. Entergy issued Condition Report CR-IP2-2013-01756 to correct this and

improved the classification in Revision 2 of ENN-MS-S-004-IPEC.

Findings and Observations

No findings were identified.

.2.6 Commitment 6: Enhance the Fatigue Monitoring Program to monitor steady state cycles

and feedwater cycles or perform an evaluation to determine monitoring is not required.

Review the number of allowed events and resolve discrepancies between reference

documents and monitoring procedures.

a. Inspection Scope

The inspectors reviewed the commitment implementation plan and discussed this

commitment with applicable plant staff and license renewal personnel. The inspectors

noted that Entergy had awarded contracts to perform the calculations that will determine

whether monitoring of steady state cycles and feedwater cycles is required. Entergy

expected that the calculations would be completed prior to the period of extended

operation. The inspectors also noted that Entergy planned to revise procedure

2-PT-2Y015, Thermal Cycle Monitoring Program, if the calculations demonstrate that a

change in the number of allowable steady state cycles and feedwater cycles is identified.

Findings and Observations

No findings were identified; however, the inspectors determined that additional

inspection was merited, including review of the results of the calculations and any

changes to the Thermal Cycle Monitoring Program procedure.

.2.7 Commitment 7: Enhance the Fire Protection Program to explicitly state that the diesel

fire pump engine sub-systems (including the fuel supply line) shall be 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 diesel fire

pump engine carbon steel exhaust components are inspected for evidence of corrosion

and cracking at least once each operating cycle.

Enclosure

6

a. Inspection Scope

The inspectors reviewed the diesel fire pump testing and maintenance procedures to

verify that the surveillance and maintenance procedures had been revised to include the

enhanced visual inspections, and had appropriate acceptance criteria for those

inspections. The inspectors walked down the diesel fire pump to independently assess

material conditions of the fire pump and diesel engine, and the feasibility of the revised

procedures.

Findings and Observations

No findings were identified.

.2.8 Commitment 8: Enhance the Fire Water Program to include inspection of hose reels for

evidence of corrosion, replace all or test a sample of sprinkler heads, to perform wall

thickness evaluations of fire protection piping, and inspect the internal surfaces of

foam-based fire suppression tanks.

a. Inspection Scope

The inspectors reviewed the fire hose reel inspection procedures to verify that the

procedures had been revised to include the enhanced visual inspections, and had

appropriate acceptance criteria for those inspections. The inspectors walked down a

sample of hose reels in safety-related areas to evaluate the material condition of the

hose reels.

The inspectors reviewed work orders to replace all of the fire water system sprinkler

heads required for 10 CFR 50.48 prior to 50 years in service. The inspectors walked

down a sample of sprinkler heads in safety-related areas to independently assess the

material condition of the sprinkler heads.

The inspectors reviewed IP-RPT-12-LRD02, Fire Water Piping Wall Thickness

Evaluation, the ultrasonic test (UT) examination data records, and the associated

structural assessments of minimum wall thickness and corrosion rate determinations.

The inspectors compared the UT data results to the established minimum wall thickness

criteria for the selected piping locations to verify adequate pressure boundary and

structural integrity of the fire water piping system. The inspectors also evaluated

Entergy's determination that all UT test locations would be greater than the minimum

required wall thickness values at the end of the period of extended operation, based

upon worst case test results and conservative estimates of corrosion rates.

In addition, the inspectors evaluated the locations Entergy selected for UT examination

of fire water piping to verify the locations were sufficiently diverse and represented an

adequate sample population to ensure the test results were indicative of the piping

system as a whole. The inspectors walked down all UT test locations and other portions

of the fire water system to independently assess the material condition of the fire water

piping.

Enclosure

7

The inspectors reviewed work orders to visually inspect the internal surfaces of foam

based fire suppression tanks for signs of significant corrosion. The inspectors walked

down the four foam tanks to independently assess the material condition of the tanks. In

addition, the inspectors reviewed the visual inspection results for opportunistic internal

inspections of two of the four tanks which had been performed in 2001 and 2008.

Findings and Observations

No findings were identified.

.2.9 Commitment 9: Enhance the Flux Thimble Tube Inspection Program to implement

comparisons to wear rates identified in WCAP-12866, perform evaluations regarding

changes to test frequency and scope, specify the acceptance criteria as outlined in

WCAP-12866 or other plant-specific values based on evaluation of previous test results,

and perform corrective actions based on tubes that exceed or are projected to exceed

the acceptance criteria.

a. Inspection Scope

The inspectors reviewed the commitment implementation plan, revised inspection

procedures, and discussed this commitment with applicable plant staff and license

renewal personnel. An inspection procedure had been developed using the inspection

results and methodology provided in WCAP-12866 and included wear rate comparisons,

appropriate acceptance criteria, and corrective actions for exceeding the acceptance

criteria. The inspectors reviewed the eddy current test (ECT) reports for the flux thimble

tube inspections conducted at Unit 2 in March 2012 and completed at Unit 3 during the

2009 and 2011 outages. The ECT reports indicated insignificant flux thimble tube

degradation. The ECT reinspections were planned in 8 years and had been included in

the plant scheduling process.

Findings and Observations

No findings were identified.

.2.10 Commitment 10: Enhance the Heat Exchanger Monitoring Program to include

22 specific heat exchangers within the program scope and provide program inspections,

including non-destructive inspection methods, considerations for sampling, and

acceptance criteria.

a. Inspection Scope

The inspectors reviewed corporate and site procedures, heat exchanger program

database, and work order planning documents that addressed inspection, sampling, and

acceptance criteria. The inspectors verified that the additional heat exchangers had

been added to the program and the inspection methods, sampling and acceptance

criteria were reasonable and in accordance with the commitment.

Enclosure

8

Findings and Observations

No findings were identified.

.2.11 Commitment 12: Enhance the Masonry Wall Program to specify that the IP1 intake

structure is included in the program.

a. Inspection Scope

The inspectors reviewed the commitment implementation plan and revised procedures,

and discussed this commitment with applicable plant staff and license renewal

personnel. The inspectors verified that Entergy had revised EN-DC-150, Structural

Monitoring Program, Attachment 9.15, in Revision 4 to explicitly include the masonry

walls/structures in the intake structure of Unit 1.

Findings and Observations

No findings were identified.

.2.12 Commitment 13: Enhance the Metal-Enclosed Bus (MEB) Inspection Program to add a

480V bus, visually inspect the external surface of MEB enclosure assemblies, include

acceptance criteria, inspect bolted connections, and remove reference to re-torquing

connections from the applicable site procedure.

a. Inspection Scope

The inspectors reviewed the licensee implementation plan and the associated completed

work orders. The inspectors discussed this commitment with applicable plant staff and

license renewal personnel. The inspectors reviewed the procedures associated with the

MEB Inspection Program to manage the aging effects on electrical bus and bus

connections, bus enclosure assemblies, and the bus insulation and insulators with

non-segregated phase bus. The inspectors reviewed procedures to verify that the bus

enclosure assemblies are inspected for cracks, corrosion, foreign debris, excessive dust

buildup, and evidence of water intrusion. The inspectors reviewed drawings, reviewed

completed work orders, and performed walkdown inspections to evaluate the capability

of the program to manage aging effects.

The inspectors identified that Entergy had not included all accessible portions of the

MEB within the scope of the maintenance inspection program, in that the sections of the

emergency diesel generator (EDG) 480 volt MEB in the electrical tunnel had not been

visually inspected and was not included in the scope of the maintenance procedure

which performed the MEB inspections and tests. The inspectors noted that quantitative

measures, such as insulation resistance and connection resistance tests, had been

performed for the associated bus duct sections. Entergy initiated CR-IP2-2013-01786 to

revise site procedures and conduct visual inspections of those additional sections of the

bus ducts prior to the PEO.

Enclosure

9

Findings and Observations

No findings were identified; however, the inspectors determined that additional

inspection was merited regarding the revised visual inspection procedures and results of

the inspection.

.2.13 Commitment 14: Implement the Non Environmentally Qualified (EQ) Bolted Cable

Connections Program as described in LRA Section B.1.22.

a. Inspection Scope

The inspectors reviewed the commitment implementation plan and the associated

completed work orders. The Non-EQ Bolted Cable Connections Program is a new

program credited with managing the aging effects in bolted cable connections by a

one-time inspection of a representative sample of in-scope connections. The inspectors

reviewed the results of the sample of in-scope connections along with visual inspection

and testing methods to assess the program and its capability to manage aging effects.

The inspectors noted that there was no evidence of visual degradation, loosening,

discoloration, cracking or corrosion for any of the connections in the sample population

and all as-found connection resistance values were within the acceptance criteria. The

results indicated that there was no loosening of bolted electrical cable connections due

to thermal cycling, ohmic heating, electrical transients, vibration, chemical

contamination, corrosion, or oxidation. Inspectors noted that thermography was

performed periodically through the preventive and predictive maintenance programs.

Though loosening of bolted connection was not expected, this practice along with the

condition reporting system was expected to identify any adverse trends that could

develop.

Findings and Observations

No findings were identified.

.2.14 Commitment 15: Implement Non-EQ Inaccessible Medium-Voltage Cable Program as

described in LRA Section B.1.23. This new program will be implemented consistent with

the corresponding program described in NUREG-1801,Section XI.E3, Inaccessible

Medium-Voltage Cables Not Subject to 10 CFR 50.49 Environmental Qualification

Requirements.

a. Inspection Scope

The inspectors reviewed the commitment implementation plan, program procedures, and

cable testing procedures. The inspectors reviewed the test results associated with

in-scope medium-voltage cables and low-voltage power cables to provide an indication

of the condition of the conductor insulation, and associated corrective action documents.

The inspectors also sampled twelve completed work orders from the inspection program

that includes inspections for water accumulation in manholes at least once every year.

Enclosure

10

Findings and Observations

No findings were identified.

.2.15 Commitment 16: Implement the Non-EQ Instrumentation Circuits Test Review Program

as described in LRA Section B.1.24. This new program will be implemented consistent

with the corresponding program described in NUREG-1801,Section XI.E2, Electrical

Cables and Connections Not Subject to 10 CFR 50.49 Environmental Qualification

Requirements.

a. Inspection Scope

The inspectors reviewed the test results of neutron flux monitoring instrumentation

cables, interviewed plant personnel, and reviewed program documentation to assess the

capability of the program to manage aging effects. The inspectors noted that the initial

reviews of calibration test results for high range-radiation monitoring cables were not yet

performed. However, the reviews were ongoing and were planned to be completed prior

the period of extended operation. The inspectors reviewed the preventive maintenance

task performing the periodic review of the cable system testing and the calibration

surveillance results of neutron flux and radiation monitoring cables. The inspectors also

reviewed the test methodology and procedures to determine appropriate acceptance

criteria were included.

Findings and Observations

No findings were identified.

.2.16 Commitment 17: Implement the Non-EQ Insulated Cables and Connections Program as

described in LRA Section B.1.25. This new program will be implemented consistent with

the corresponding program described in NUREG-1801,Section XI.E1, Electrical Cables

and Connections not Subject to 10 CFR 50.49 Environmental Qualification

Requirements.

a. Inspection Scope

The program manages the aging effects of cables and connections exposed to adverse

localized environments by visually inspecting accessible insulated cables and

connections. The inspectors reviewed Entergy's inspection results, documented in

IP-RPT-10-LRD15, Cable and Connection Inspection Summary Report, a representative

sample of walkdown data sheets (e.g., field observation notes), and selected CRs which

had been initiated as a result of the walkdowns to evaluate and correct potential

deficiencies. In addition, the inspectors walked down cables and connections in the

electrical cable tunnel to independently assess the material conditions and to validate

Entergy's observations.

Findings and Observations

No findings were identified.

Enclosure

11

.2.17 Commitment 18: Enhance the Oil Analysis Program to include the IP2 SBO/Appendix R,

diesel generator, generator seal oil and turbine hydraulic control oil, formalize

preliminary oil screening for water and particulates and laboratory analyses, and

formalize trending of preliminary oil screening results.

a. Inspection Scope

The inspectors reviewed Entergys corporate and Indian Point site specific procedures

for the oil analysis program. The oil analysis program is an existing program that

maintains oil systems free of contaminants to preserve an environment that is not

conducive to loss of material, cracking, or fouling. As part of the license renewal

application this process was formalized through the new procedures and a trending

program, which was planned to be fully implemented by the period of extended

operation. Also, the inspectors reviewed the corrective action documents from the past

5 years associated with oil analysis sampling.

The inspectors noted that SEP-LUB-IPC-002, IPEC Oil Analysis Program, Revision 0

addressed the equipment included in the preliminary oil screening for water and

particulates, but was not clear regarding the boiler feed pump being scoped into the

program. Based on this observation, Entergy revised the procedure to address the

inspectors concern. The inspectors reviewed Revision 1 of the procedure which

included clear, specific guidance, and resolved the concern.

Findings and Observations

No findings were identified.

.2.18 Commitment 19: Implement the One-Time Inspection Program as described in LRA Section B.1.27. This new program will be implemented consistent with the

corresponding program described in NUREG-1801, Section XIM32, One-Time

Inspection.

a. Inspection Scope

The inspectors reviewed Entergys corporate procedure for one-time inspections and

discussed this commitment with applicable plant staff and license renewal personnel.

The intent of the One-Time Inspection Program is to confirm that other existing aging

management programs have been effective. The program also performs one-time

inspections of other specific components. The inspectors reviewed the Entergy letter

submitting Amendment 13 to the LRA, which revised the sampling plan to the sampling

specified in NUREG 1801, Generic Aging Lessons Learned (GALL), Revision 2, and the

inspection tracking matrix, which implemented the revised sampling plan. The

inspectors noted that the program involved over 400 inspections, approximately

300 inspections to cover the existing aging management programs for water chemistry,

fuel oil, and lubrication oil, and an additional 120 inspections on components specified in

the LRA. Entergy had completed slightly over half of the planned inspections. The

inspectors selected 20 inspections and reviewed the inspection records.

Enclosure

12

Findings and Observations

No findings were identified; however, the inspectors determined that additional NRC

inspection was merited to review the inspections remaining; any further actions needed,

and program conclusions.

.2.19 Commitment 20: Enhance the One Time Inspection Program - Small Bore Piping

Program as described in LRA Section B.1.28. This new program will be implemented

consistent with the corresponding program described in NUREG-1801,Section XI.M35,

One-Time Inspection of American Society of Mechanical Engineers (ASME) Code

Class I Small Bore Piping.

a. Inspection Scope

The program includes butt-welded piping less than 4-inch nominal pipe size that are

susceptible to cracking. Samples are selected based on susceptibility to thermal

stratification or turbulent penetration as provided in Electric Power Research

Institute (EPRI) Report 1000701, Interim Thermal Fatigue Management Guideline

(MRP-24), January 2001. The program is intended to determine if the aging effect of

stress induced corrosion cracking is occurring in small bore piping when the license

renewal applicant has not found this aging affect in larger diameter piping.

Entergy had previously implemented a risk-informed inservice inspection program that

included 195 risk-significant small bore butt welds in addition to the larger diameter butt

welds chosen in the context of ASME Section XI. In order to strictly meet the

commitment requirement to implement a program consistent with NUREG-1801,

Section XI.M35, One-Time Inspection of ASME Code Class 1 Small Bore Piping,

Entergy selected six small bore butt welds, or approximately 3 percent, from the risk-

significant population of 195 which conformed with the guidance in EPRI Report

1000701, Interim Thermal Fatigue Management Guideline (MRP-24).

Findings and Observations

No findings were identified.

.2.20 Commitment 21: Enhance the Periodic Surveillance and Preventive Maintenance

Program as necessary to assure that the effects of aging will be managed such that

applicable components will continue to perform their intended functions consistent with

the current licensing basis through the period of extended operation.

a. Inspection Scope

The inspectors reviewed the commitment implementation plan, work orders, and

program procedures, and discussed this commitment with applicable plant staff. The

program involves repetitive tasks and routine monitoring of plant operations through

visual and other non-destructive examination (NDE) inspection techniques. The

inspectors reviewed sampled work orders for preventive maintenance work performed

on five systems.

Enclosure

13

Findings and Observations

No findings were identified.

.2.21 Commitment 22: Enhance the Reactor Vessel Surveillance Program revising the

specimen capsule withdrawal schedules to draw and test a standby capsule to cover the

peak reactor vessel fluence expected through the end of the period of extended

operation. Enhance the Reactor Vessel Surveillance Program to require that tested and

untested specimens from all capsules pulled from the reactor vessel are maintained in

storage.

a. Inspection Scope

Entergy determined the peak reactor vessel fluence expected through the end of the

period of extended operation. The inspectors reviewed the revised pressure-thermal

curves generated to account for the peak reactor vessel fluence. The inspectors

reviewed the supporting analysis reported in Westinghouse WCAP-16752-NP,

Revision 0, Indian Point Heatup and Cooldown Limit Curves for Normal Operation,

January 2008. The inspectors noted the reactor vessel beltline materials included by

Entergy in the original application did not include all the components meeting the

threshold of greater than 1x1017 n/cm2. This was corrected in subsequent

correspondence with the NRC. Entergy took action to document the specific

components included in the beltline analysis. Entergy had issued LO-LAR-2011-0174

CA 15 to identify capsule withdrawal schedules, and require tested and untested

specimens from all capsules pulled from the reactor vessel are maintained in storage.

Findings and Observations

No findings were identified.

.2.22 Commitment 23: Implement the Selective Leaching Program as described in LRA Section B.1.33. This new program will be implemented consistent with the

corresponding program described in NUREG-1801, Section XIM33 Selective Leaching

of Materials.

a. Inspection Scope

The inspectors reviewed the commitment implementation plan and Entergy corporate

procedure for selective leaching inspections, and discussed this commitment with

license renewal personnel. The program is intended to confirm whether selective

leaching, the removal of constituents from susceptible materials, is occurring. The

inspectors reviewed Entergys letter submitting Amendment 13 to the LRA, which

revised the sampling plan to the sampling specified in GALL, Revision 2, and the

inspection tracking matrix, which implemented the revised sampling plan. The

inspectors noted that the program involved over 60 inspections, which Entergy was in

progress of completing. The inspectors observed the in-plant inspections and material

conditions associated with fire protection valves 698 and 699. The inspectors selected

Enclosure

14

10 inspections of copper alloy materials and 12 inspections of gray cast iron materials,

and reviewed the inspection records.

Findings and Observations

No findings were identified; however, the inspectors determined that additional NRC

inspection was merited to review the inspections remaining, any further actions needed,

and program conclusions.

.2.23 Commitment 24: Enhance the Steam Generator Integrity Program to require that the

results of the condition monitoring assessment are compared to the operational

assessment performed for the prior operating cycle with differences evaluated.

a. Inspection Scope

The inspectors reviewed the commitment implementation plan and program procedures,

and discussed this commitment with applicable plant staff. The inspectors noted that the

IP2 Steam Generator Program, SEP-SG-IP2/3-001, Revision 0, in paragraph 5.3,

provided for a comparison of the current condition monitoring assessment to the

operational assessment performed for the prior operating cycle with an evaluation of the

differences. The inspectors reviewed Entergys corporate procedure EN-DC-317, Steam

Generator Program, Revision 7, noting its inclusion of the appropriate Nuclear Energy

Institute (NEI), EPRI, ASME and NRC references.

Findings and Observations

No findings were identified.

.2.24 Commitment 25: Enhance the Structural Monitoring Program by including additional

structures, inspection of structural commodities and anchors, inspection of inaccessible

concrete areas, inspection of elastomers, engineering evaluation of groundwater

chemistry including tritium, inspection of submerged concrete and components of intake

structure, increased inspection frequency of degraded areas of water control structures,

and more detailed acceptance criteria.

a. Inspection Scope

The inspectors reviewed the commitment implementation plan and revised procedures,

and discussed this commitment with applicable plant staff and license renewal

personnel. The inspectors reviewed the IPEC-specific attachments to the corporate

procedure EN-DC-150, Structural Monitoring Program, documenting the enhancements.

The inspectors verified that Entergy had revised applicable corporate and plant

procedures to include the additional structures, commodities, materials, and components

within the Structural Monitoring Program. Additionally, the procedure had increased the

frequency of inspection of degraded areas of submerged concrete structures to every

3 years.

Enclosure

15

Findings and Observations

No findings were identified.

.2.25 Commitment 26: Implement the Thermal Aging Embrittlement of Cast Austenitic

Stainless Steel (CASS) Program as described in LRA Section B.1.37. This new program

will be implemented consistent with the corresponding program described in

NUREG 1801,Section XI.M12, Thermal Aging Embrittlement of Cast Austenitic

Stainless Steel Program.

a. Inspection Scope

The Thermal Aging Embrittlement of the CASS Program is a new program that manages

the aging effects of loss of fracture toughness due to thermal aging of cast austenitic

stainless steel components for the reactor coolant system (excluding the reactor vessel

internals). Prior to the period of extended operation the program will screen all cast

austenitic stainless steel components to determine which are potentially susceptible to a

loss of fracture toughness. These components will be further evaluated, using a refined

analytical technique, to determine the components susceptibility to reduction in fracture

toughness. Entergy maintains the option of performing a volumetric examination that

conforms to ASME Section XI, Appendix VIII, Supplement 10. This supplement has

been in the course of preparation since Appendix VIII was first added to Section XI

because extensive research has not resulted in a meaningful volumetric examination

technique to date. The inspectors verified that Entergy was gathering information about

component temperature and loads in order to determine the component susceptibility.

In the LRA Entergy stated that this new program will be implemented consistent with the

corresponding program described in NUREG-1801,Section XI.M12, Thermal Aging

Embrittlement of CASS Program. Entergy has chosen to perform a unique fracture

mechanics analysis of these components, which was in progress. The inspector noted

that there may be a question regarding the submittal of the analysis under ASME

requirements, as stipulated in 10 CFR 50.55a.

Findings and Observations

No findings were identified; however, the inspectors determined that additional

inspection was merited regarding the analysis results and the compliance approach

implemented.

.2.26 Commitment 27: Implement the Thermal Aging and Neutron Irradiation Embrittlement of

Cast Austenitic Stainless Steel (CASS) Program as described in LRA Section B.1.38.

This new program will be implemented consistent with the corresponding program

described in NUREG-1801,Section XI.M13, Thermal Aging and Neutron Embrittlement

of Cast Austenitic Stainless Steel program.

Enclosure

16

a. Inspection Scope

The inspectors reviewed the plans for implementation of this commitment. The

programs supporting the identified actions were in the early stage of implementation.

For example, the screening criteria of EPRI Technical Report 1013234, Materials

Reliability Program: Screening Categorization, and Ranking of Reactor Internals

Components for Westinghouse and Combustion Engineering PWR Design, (MRP-191),

listed in Table 3-5, were applied to the Indian Point components listed in Table 5-1 of

EPRI Report 1022863, Materials Reliability Program: Pressurized Water Reactor

Internals Inspection and Evaluation Guidelines (MRP-227-A). However, a site document

had yet to be developed that defined and implemented this program.

Findings and Observations

No findings were identified; however, the inspectors determined that additional

inspection was merited regarding analysis conclusions and program direction.

.2.27 Commitment 30: For aging management of the reactor vessel internals, IPEC will

(1) participate in the industry programs for investigating and managing aging effect on

reactor internals, (2) evaluate and implement the results of the industry programs as

applicable to the reactor internals; and (3) upon completion of these programs, but 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.

a. Inspection Scope

The inspectors reviewed Amendment 9 to the license renewal application, transmitted by

Entergy letter NL-10-063 on July 14, 2010, which modified the application to include an

aging management program for reactor vessels internals based on industry group

generated guidance. This amendment included an aging management review of the

reactor vessel internals within the scope of the renewal rule. The aging management

program was included in the reactor vessel internals program already being

implemented at Indian Point Unit 2.

Findings and Observations

No findings were identified.

.2.28 Commitment 31: Additional P-T Curves will be submitted as required per

10 CFR Part 50, Appendix G, prior to the period of extended operation as part of the

Reactor Vessel Surveillance Program.

a. Inspection Scope

Entergy submitted changes to the Indian Point 2 Technical Specifications proposing

changes to the IP2 vessel heat-up and cool-down curves (P-T Curves) and low

temperature over pressure requirements in letter NL-13-001, dated February 6, 2013.

Enclosure

17

Findings and Observations

No findings were identified.

.2.29 Commitment 33: For the locations identified in LRA Table 4.3-13 (IP2), update the

fatigue usage calculations using refined fatigue analyses to determine if Cumulative

Usage Factors (CUF) remain less than 1.0 when accounting for the effects of reactor

water environment, using valid Fen factors.

a. Inspection Scope

The inspectors reviewed the calculations and discussed this commitment with applicable

plant staff. The inspectors noted that the implementation schedule for completing the

calculations was September 28, 2011. By letter dated August 9, 2010, Entergy issued

Letter NL-10-082 (ML102300504) informing the NRC staff that the calculations had been

completed. These calculations are documented as WCAP 17149-P, Evaluation of

Pressurizer Insurge/Outsurge Transients for Indian Point Unit 2, and WCAP 17199-P,

Environmental Fatigue Evaluation for Indian Point Unit 2. The inspectors reviewed these

calculations and noted that both concluded that cumulative fatigue usage factors

including reactor water environment effects were below the ASME Code allowable value

of 1.0 for transients postulated for 60 years of operation. The inspectors noted that

Entergys action plan included revising the Thermal Cycle Monitoring Program procedure

to reflect changes in the number of projected cycles used in WCAP 17199-P.

Findings and Observations

No findings were identified; however, the inspectors determined that additional

inspection was merited regarding any changes to the Thermal Cycle Monitoring Program

procedure warranted to ensure that it appropriately reflects the input values used by

WCAP 17199-P.

.2.30 Commitment 35: Perform a one-time inspection of representative sample area of IP2

containment liner affected by the 1973 event behind the insulation, prior to entering the

period of extended period of operation, to assure liner degradation is not occurring in this

area. Any degradation will be evaluated for updating of the containment liner analyses

as needed.

a. Inspection Scope

The inspectors reviewed the Unit 2 one time inspection report, including visual and

ultrasonic examinations, which was completed on March 22, 2012 (Work Order 00282078-01). These examinations were at the 68 foot elevation location between

columns 10 and 9. The report showed that there had not been liner degradation.

Findings and Observations

No findings were identified.

Enclosure

18

.2.31 Commitment 37: Enhance the Containment Inservice Inspection (CIIIWL) Program to

include inspections of the containment using enhanced characterization of degradation

(i.e., quantifying the dimensions of noted indications through the use of optical aids)

during the period of extended operation. The enhancement 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.

a. Inspection Scope

The inspectors reviewed the commitment implementation plan and discussed this

commitment with applicable plant staff and license renewal personnel. Reactor

containment is a seismic Class I, reinforced structure, with a welded steel liner attached

to the inside surface of the concrete shell. For IP2 the steel liner is covered by polyvinyl

chloride insulation in a stainless steel jacket. The liner is anchored to the concrete shell

by stud anchors. In accordance with applicable guidance in ASTM C33-90, Figure 1,

IP2 is located in a severe weathering region and the containment concrete exterior

surface should be monitored for degradation based on freeze-thaw aging. Entergy

inspections have reported spalling on the containment vertical exterior wall; Entergy

attributes this degradation to Cadweld concrete coverage and not to freeze-thaw aging.

This spalling was the subject of an Open Item (3.0.3.3.2-1) in Safety Evaluation Report

NUREG 1930, Volume 2, Safety Evaluation Report Related to the License Renewal of

Indian Point Nuclear Generating Station Unit Nos. 2 and 3 (ADAMS ML093170671).

The staff position in the Safety Evaluation is that ASME IWL inspections performed in

2005 and 2009 using enhanced visual aids showed little additional degradation since the

original detection of spalling in 2000. Because Entergy demonstrated the concrete is

above the 3000 psi design minimum, and Entergy is committed to implementing

ASME IWL for the duration of the extended period of operation, the staff concluded the

spalling is not the consequence of freeze-thaw and if it were to occur it would be

captured under the provisions of an inspection program in compliance with ASME IWL.

By letter dated August 14, 2008, Entergy added Commitment 37 to enhance the

Containment Inservice Inspection Program to include inspection using enhanced

characterization of degradation during the period of extended operation. The

enhancement includes obtaining critical dimensional data of degradation where possible

through direct measurement or the use of scaling technologies for photography.

To verify that enhancements had been incorporated in the structural monitoring program,

the inspectors reviewed revised program procedure EN-DC-1 that included obtaining

critical dimensional data of degradation where possible through direct measurement of

the use of scaling technologies for photography.

The inspectors determined that the concrete inspection of structural members was

covered by the comprehensive structural monitoring program. Also, other documents,

(i.e. the IWL ISI inspection packages for inspection years 2005 and 2009) were reviewed

and compared to verify inclusion of enhanced examination requirements.

Enclosure

19

Additionally, inspectors performed a walk-through inspection of accessible and exposed

outer surfaces of the containment structure to assess the surface condition and any

evidence of concrete distress or deterioration, such as defoliation, spalling, structurally

significant cracks, and any indication of chemical reaction or attack (e.g., alkali-silica

reaction).

The inspectors noted that the acceptance criteria for visual indications of concrete were

included in the procedure only by reference to the American Concrete Institute (ACI)

standard. This approach could introduce error and uncertainty into the inspection

process compared to acceptance criteria being readily available in the procedure.

Entergy issued CR-IP2-2013-02005 to enhance the procedure.

Findings and Observations

No findings were identified.

.2.32 Commitment 38: For Reactor Vessel Fluence, should future core loading patterns,

invalidate the basis for the projected values of RTpts or CvUSE, updated calculations

will be provided to the NRC.

a. Inspection Scope

Entergy has calculated the charpy upper-shelf energy (CvUSE) threshold of

1 x 1017 n/cm2 will be exceeded for a number of reactor vessel components at IP2. The

inspectors reviewed a list of these components in Table 4 in Attachment 1 to Entergy

letter NL-08-143, dated September 24, 2008. As stated in the LRA, Section 4.2.1, the

48 effective full power year, end-of-life, peak fluence for IP2 was calculated to be

1.906 x 1019 n/cm2. As a consequence of this analysis Entergy has implemented flux

reduction measures. In corrective action LO-LAR-2011-0174 CA 29, Entergy initiated

development of a site specific program document to maintain the flux mitigation program

during the extended period of operation.

Findings and Observations

No findings were identified.

.2.33 Commitment 40: Evaluate plant specific and appropriate industry operating experience

and incorporate lessons learned in establishing appropriate monitoring and inspection

frequencies to assess aging effects for the new aging management programs.

Documentation of the operating experience evaluated for each new program will be

available on site for NRC review prior to the period of extended operation.

a. Inspection Scope

Entergy stated that the evaluations to implement this commitment would be performed

following the implementation of the new programs. As such there was insufficient

material to review during the inspection.

Enclosure

20

Findings and Observations

No findings were identified; however, the inspectors determined that additional

inspection was merited regarding review of the evaluations.

.2.34 Commitment 41: IPEC will inspect steam generators for both units to assess the

condition of the divider plate assembly. The examination technique used will be capable

of detecting primary water stress crack corrosion (PWSCC) in the steam generator

divider plate assembly. The IP2 steam generator divider plate inspections will be

completed within the first ten years of the period of extended operation. The IP3 steam

generator divider plate inspections will be completed within the first refueling outage

(RFO) following the beginning of the period of extended operation.

a. Inspection Scope

The inspectors reviewed the commitment implementation plan and discussed this

commitment with informed plant staff. Entergy personnel stated that preparations for

these steam generator inspections are in-progress (the earliest inspection would occur

in 2016). As evidence of preparations for this inspection, Entergy provided an EPRI

report on divider plate cracking presented in June 5-7, 2012, and EPRI Technical Report

3002000411, dated April 2013 on the Flaw Tolerance Evaluation of the Steam Generator

Channel Head, which related to the inspections.

Findings and Observations

No findings were identified.

.2.35 Commitment 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 two options, analysis or inspection.

a. Inspection Scope

The inspectors reviewed the commitment implementation plan and discussed this

commitment with applicable plant staff. While a final inspection plan had not been

established, the preparations were underway. The inspectors reviewed

CR-IP2-2013-01440, Revision 2, which described the ongoing work. The inspectors

noted the commitment schedule for the plan on Unit 3 would be sooner (prior to the end

of the first refueling outage after December 12, 2015) than the plan on Unit 2 (prior to

March 2024). This schedule was based on the replacement of Unit 2 steam generators

in 2000 while the Unit 3 steam generators were replaced in 1989, with steam generator

service years of about 13 and 24 years, respectively, for each unit.

Findings and Observations

No findings were identified.

Enclosure

21

.2.36 Commitment 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.

a. Inspection Scope

The inspectors noted that Entergy has awarded contracts to perform the calculations

that will support closure of this commitment. The inspectors also noted that Entergy and

its vendor have completed initial screening calculations to determine the locations that

may require further analysis.

Findings and Observations

No findings were identified; however, the inspectors determined that additional

inspection was merited regarding review of the results of the calculations and any

changes to the Thermal Cycle Monitoring Program procedure.

.2.37 Commitment 44: Entergy will include written explanation and justification of any user

intervention in future evaluations using the WESTEMS' Design CUF module.

.2.38 Commitment 45: Entergy will not use the ASME Code Section III, NB-3600 option of the

WESTEMS' program in future design calculations until the issues identified during the

NRC review of the program have been resolved.

a. Inspection Scope

The inspectors noted that Entergy has revised procedure 2-PT-2Y015, Thermal Cycle

Monitoring Program, to incorporate the two restrictions described in Commitments 44

and 45. The inspectors also noted that this procedure would be referenced whenever

fatigue calculations would be developed or modified. The inspectors further noted that if

an engineer were to inadvertently not use 2-PT-2Y015, procedures EN-LI-100, Process

Applicability Determination, and EN-AD-101, Procedure Process, the procedures which

control changes, tests and experiments, and procedure changes include a required

review of all NRC commitments. These two procedures (i.e., EN-LI-100, EN-AD-101)

would act as a backup to the thermal cycling monitoring procedure.

Findings and Observations

No findings were identified.

.2.39 Commitment 46: Include in the IP2 ISI Program that IPEC will perform 25 volumetric

weld inspections of socket welds during each 10 year interval scheduled as specified by

IWB-2412 of the ASME Section XI Code during the period of extended operation. In lieu

Enclosure

22

of volumetric examinations, destructive examinations may be performed, where one

destructive examination may be substituted for two volumetric examinations.

a. Inspection Scope

The inspectors reviewed SEP-ISI-IP2-001, Revision 1, IP2 Fourth Ten-Year Interval

Inservice Inspection (ISI)/ Containment Inservice Inspection (CII) Program Plan, dated

June 20, 2012, Section 2.1.27 Examination Category R-A, Risk Informed Piping Welds,

wherein Entergy states: Per ASME B&PV Code Case N-578-1, the only examination

that is required on a socket weld is a VT-2 visual examination each refueling outage.

However per License Renewal Commitment #46 (LO-LAR-2011-0174 CA 65), twenty-

five volumetric weld metal inspections of socket welds should be performed periodically

during each 10 year ISI interval 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.

The IP2 Inservice Inspection Program was revised to include the provision to perform

25 volumetric weld inspections of socket welds during each 10 year interval scheduled

as specified by IWB-2412 of the ASME Section XI Code during the period of extended

operation. The IP2 Inservice Inspection Program was revised to include the option of

substituting one destructive examination for two volumetric examinations.

Findings and Observations

No findings were identified.

.2.40 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 irradiation

embrittlement. The analyses will be consistent with the IP2/IP3 licensing basis.

a. Inspection Scope

The inspectors reviewed the plans for implementation of these commitments. The

programs supporting the identified actions were in the early stage of implementation and

awaiting analysis results. For example the screening criteria of Electric Power Research

Institute Technical Report 1013234, Materials Reliability Program: Screening

Categorization, and Ranking of Reactor Internals Components for Westinghouse and

Combustion Engineering PWR Design, (MRP-191), listed in Table 3-5, were applied to

the Indian Point components listed in Table 5-1 of Electric Power Research Institute

Report 1022863, Materials Reliability Program: Pressurized Water Reactor Internals

Inspection and Evaluation Guidelines (MRP-227-A). A site document had not been

developed that defined and implemented this program. In Entergy letter NL-13-052,

dated May 7, 2013, Entergy requested an extension in the scheduled completion date

for this commitment until March 1, 2015.

Enclosure

23

Findings and Observations

No findings were identified; however, the inspectors determined that additional

inspection was merited regarding the results of the ongoing analysis and implementation

of the program, pending NRC action on the schedule extension.

.2.41 Commitment 48: Entergy will visually inspect in-scope underground piping prior to the

period of extended operation and then on a frequency of at least once every 2 years

during the period of extended operation. Visual inspections will be supplemented with

surface or volumetric non-destructive testing if indications of significant loss of material

are observed. Adverse indications will be entered into the plant corrective action

program for evaluation of extent of condition and for determination of appropriate

corrective actions (e.g., increased inspection frequency, repair, replacement).

a. Inspection Scope

The inspectors reviewed preventive maintenance requests for inspection of three in-

scope underground piping locations. These preventive maintenance requests specified

a 2 year interval and stated that visual inspections will be supplemented with surface or

volumetric non-destructive testing if indications of significant loss of material are

observed. The requests also designate the activities as a commitment for license

renewal. The inspectors noted that if adverse conditions are detected, the corrective

action program is expected to direct the appropriate extent of condition review and

corrective actions. The inspectors also noted that work orders have been issued to

perform the inspections to be conducted prior to the period of extended operation.

Findings and Observations

No findings were identified. The inspectors determined that additional inspection was

merited regarding review of the results of the underground piping inspections.

Program Review

Boric Acid Corrosion Control, Existing Aging Management Program (AMP)

a. Inspection Scope

The Boric Acid Corrosion Prevention Program is an existing program that relies on

implementation of recommendations of NRC Generic Letter 88-05 to monitor the

condition of components on which borated reactor water may leak. The program detects

boric acid leakage by periodic visual inspection of systems containing borated water for

deposits of boric acid crystals and the presence of moisture; and by inspection of

adjacent structures, components, and supports for evidence of leakage. During plant

operation accessible portions of the plant are monitored for boric acid leakage and

during plant refuel outages the inspections for boric acid leakage are extended to areas

of the plant usually inaccessible during plant operation. The program includes

provisions for evaluation when leakage is discovered by other activities. Program

improvements have been made as suggested in NRC Regulatory Issue

Enclosure

24

Summary 2003-013. The Boric Acid Corrosion Prevention Program was enhanced to

include recommendations of the Westinghouse Owner's Group WCAP-15988-NP

"Generic Guidance to Best Practice 88-05 Boric Acid Inspection Program," EPRI

Technical Report 1000975 "Boric Acid Corrosion Guidebook," and NRC Bulletin 2003-02

"Leakage from Reactor Coolant Pressure Vessel Lower Head Penetrations and Reactor

Coolant Pressure Boundary Integrity. The Boric Acid Corrosion Prevention Program is

consistent with the program described in NUREG-1801,Section XI.M10, Boric Acid

Corrosion.

Findings and Observations

No findings were identified.

Time Limited Aging Analysis Review

a. Inspection Scope

Time-limited aging analyses (TLAA) are plant-specific safety analyses that are based on

an explicitly assumed 40-year plant life as defined in 10 CFR 54.3. Time-limited aging

analyses are dispositioned in pursuant to 10 CFR 54.21(c)(1). Entergy must

demonstrate that either: (1) the TLAAs will remain valid for the period of extended

operation, as required by 10 CFR 54.21(c)(1)(i); or (2) the TLAAs have been projected to

the end of the period of extended operation, as required by 10 CFR 54.21(c)(1)(ii); or

(3) that the effects of aging on intended functions will be adequately managed for the

period of extended operation, as required by 10 CFR 54.21(c)(1)(iii). The inspectors

identified one neutron fluence TLAA as well as evaluations associated with

environmentally-assisted fatigue that Entergy had dispositioned in accordance with

10 CFR 54.21(c)(1)(iii) and had associated with license renewal commitments.

The inspectors determined that Entergy had committed (Commitment 38) to update the

neutron fluence TLAA calculations should there be changes in the fuel loadings that are

not bounded by current analytical assumptions. The inspectors evaluation of the status

of Commitment 38 is documented above.

The inspectors determined that Entergy had made four commitments related to the

evaluations of environmentally-assisted fatigue. Entergy committed (Commitment 33) to

update the fatigue usage calculations for those locations identified in NUREG/CR-6260

using refined fatigue analyses to determine valid cumulative usage factors (CUF) less

than 1.0 when accounting for the effects of reactor water environment. Entergy also

committed (Commitment 43) to 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. Entergy committed (Commitment

44) to include written explanation and justification of any user intervention in future

evaluations using the WESTEMS Design CUF module. Entergy also committed

(Commitment 45) that it will not use the NB-3600 option of the WESTEMS program in

future design calculations until the issues identified during the NRC review of the

Enclosure

25

program have been resolved. The inspectors evaluations of the status of Commitments

33, 43, 44, and 45 are documented above.

Findings and Observations

No findings were identified.

4OA6 Meetings, Including Exit

On May 23, 2013, the inspectors presented the inspection results to Mr. Donald Mayer,

acting Site Vice President, and other members of the Entergy staff. The inspectors

verified that no proprietary information was retained by the inspectors or documented in

this report. The exit meeting was attended by James Trapp, Chief, Engineering

Branch 1.

ATTACHMENT: SUPPLEMENTARY INFORMATION

Enclosure

A-1

SUPPLEMENTARY INFORMATION

KEY POINTS OF CONTACT

Entergy Personnel

J. Ventosa, Site Vice President

N. Azevedo, Code Programs Supervisor

C. Caputo, License Renewal Team

T. Chan, Mechanical Systems Supervisor

P. Conroy, Nuclear Safety Assurance Director

J. Curry, License Renewal Project Manager

G. Dahl, Licensing Engineer

R. Dolanksy, ISI Program Manager

R. Drake, Civil Design Engineering Supervisor

J. Flagg, Selective Leaching Inspector

P. Guglielmino, Implementation Team Manager

S. Manzione, Components Engineering Supervisor

D. Mayer, Unit 1 Director

T. McCaffrey, Design Engineering Manager

T. Orlando, License Renewal Team

D. Pennino, Senior Program Engineer

J. Quirk, Selective Leaching Coordinator

M. Tesoriero, Programs and Components Manager

M. Troy, Plant Programs Supervisor

R. Walpole, Licensing Manager

M. Woodby, Engineering Director

LIST OF ITEMS OPENED, CLOSED, DISCUSSED, AND UPDATED

Open

The inspectors determined that the following 11 commitments merited further inspection:

6 Fatigue cycles analysis

13 Metal enclosed bus inspection

19 One-time inspection

23 Selective leaching inspection

26 Embrittlement of CASS analysis

27 Embrittlement of CASS analysis

33 Fatigue monitoring

40 Operating experience for new programs

43 Fatigue monitoring analysis

47 Reactor vessel lower support analysis

48 Underground piping inspection

Attachment

A-2

Closed

The remaining 30 commitments reviewed were being or had been appropriately implemented.

LIST OF ACRONYMS

ACI American Concrete Institute

ADAMS Agencywide Documents Access Management System

AMP Aging Management Program

ASME American Society of Mechanical Engineers

BACC Boric Acid Corrosion Control

CAP Corrective Action Program

CASS Cast Austenitic Stainless Steel

CFR Code of Federal Regulations

CIIIWL Containment Isolation Inspection

CR Condition Report

CRDM Control Rod Drive Mechanism

EC Engineering Change

ECT Eddy Current Examination

EDG Emergency Diesel Generator

ENTERGY Entergy Nuclear Northeast

EPRI Electric Power Research Institute

EQ Environmentally Qualified

FSAR Final Safety Analysis Report

GALL Generic Aging Lessons Learned

IMC Inspection Manual Chapter

IP Inspection Procedure

IPEC Indian Point Energy Center

IR Inspection Report

ISI Inservice Inspection

LER Licensee Event Report

LRA License Renewal Application

MEB Metal-Enclosed Bus

NCV Non-Cited Violation

NDE Nondestructive Examination

NEI Nuclear Energy Institute

NRC Nuclear Regulatory Commission

PEO Period of Extended Operation

PM Preventive Maintenance

PWSCC Primary Water Stress Crack Corrosion

RCS Reactor Coolant System

RFO Refueling Outage

Attachment

A-3

SCC Stress Crack Corrosion

SG Steam Generator

SSC Structure, System, and Component

TLAA Time-Limited Aging Analyses

UFSAR Updated Final Safety Evaluation Report

UT Ultrasonic Test

VT Visual Examination

WO Work Order

LIST OF DOCUMENTS REVIEWED

Commitment 1

LO-LAR-2011-0174 CA 43

CR IP2-2013-01989

327152-Revision 2, Building and Structures Identification Plan

A216386-Revision 2, Fire Water Storage Tank

AA-88, Revision 0, City Water Storage Tank, Graver

EN-DC-178, Revision 5, System Walkdowns

2-PI-SA002, Revision 7 Atmospheric Tanks, External Inspection

Commitment 2

IP-RPT-11-LRD03, Review of the Bolting Integrity AMP for License Renewal Implementation,

Revision 0

EN-MA-145, Revision 0, Maintenance Standard for Torquing Applications

LO-LAR-2011-00174, CA-68

Commitment 3

EN-DC-343, Underground Piping and Tanks Inspection and Monitoring Program, Revision 8

SEP-UIP-IPEC, Underground Components Inspection Plan, Revision 1

CEP-UPT-0100, Underground Piping and Tanks Inspection and Monitoring, Revision 2

Buried Piping and Tanks General Visual Inspection Report, 11/12/2008, Condensate Storage

Tank to Auxiliary Feedwater Pump Suction Line 1505 and Condensate Storage Tank

Recirculation Line 1509 - Upper and Lower Excavations

CR-IP2-2008-04754, Coating Degradation Condensate Storage Tank Lines

Buried Piping and Tanks General Visual Inspection Report, 4/21/2009, Condensate Storage

Tank Recirculation Line 1509 -Outside of Auxiliary Feedwater Pump Room

Buried Piping and Tanks General Visual Inspection Report, 11/28/2011, Circulating Water

Line - 26 Circulating Water Pump Discharge to 23 Main Condenser

Buried Piping and Tanks General Visual Inspection Report, 10/21/2009, City Water Line

Inspections - 16-Inch line from City Water Storage Tank

CR-IP2-2013-00131, Coating Degradation City Water Line from City Water Storage Tank

Buried Piping and Tanks General Visual Inspection Report, 9/14/12, City Water Line 1502 to

Auxiliary Feedwater Pumps

Attachment

A-4

Buried Piping and Tanks General Visual Inspection Report, 12/13/12, City Water Line 1502 to

Auxiliary Feedwater Pumps

Buried Piping and Tanks General Visual Inspection Report, 9/14/12, 8-Inch High Pressure Fire

Protection Line in 22 Moat Area at Electrical Tunnel Penetration and in 22 Moat Area at

North Wall

CR-IP2-2013-05324, Coating Degradation 8-Inch High Pressure Fire Protection Line in 22 Moat

Area at North Wall

Buried Piping and Tanks General Visual Inspection Report, 12/13/12, 6-Inch High Pressure Fire

Protection Line to Hydrant 26

Buried Piping and Tanks General Visual Inspection Report, 8/29/12, 8-Inch Service Water Line

463 SE Return Line from the EDGs in 22 Moat Area at North Wall

CR-IP2-2013-05324, Coating Degradation Service Water Line 463 SE Return Line from the

EDGs in 22 Moat Area at North Wall

Buried Piping and Tanks General Visual Inspection Report, 11/22/11, 24-Inch Main Service

Water Line 408 and Line 409 at Existing Access Port on West Side of Turbine Building

CR-IP2-2012-06248, Coating Degradation 24-Inch Main Service Water Line 408 at Existing

Access Port on West Side of Turbine Building - Intradose of Elbow on Line 408

Buried Piping and Tanks General Visual Inspection Report, 12/13/12, 24-Inch Main Service

Water Line 405 Return to Discharge Canal at 22 Moat Area and Line 408 and Line 409

Supply Header at 22 Moat Area

CR-IP2-2013-00131, Coating Degradation 24-Inch Main Service Water Line 405 Return to

Discharge Canal at 22 Moat Area, Line 408 Supply Header at 22 Moat Area, and

1.5-Inch Weld Channel Piping to Penetration

Buried Piping and Tanks General Visual Inspection Report, 12/13/12, 1.5-Inch Weld Channel

Piping to Penetration

Buried Piping and Tanks General Visual Inspection Report, 10/10/12, 8-Inch HP Fire Protection

Line and 8-Inch City Water Line 1502 in the IP2 Transformer Yard

Commitment 4

LO-LAR-2011-00174

A.2.1.8 Diesel Fuel Monitoring Program

B.1.9 Diesel Fuel Monitoring Program

3-SOP-EL-009, Filling the Diesel Fuel Oil Storage Tanks, Revision 22

0-CY-1500, Chemistry Sampling Locations, Revision 23

0-CY-1560, Sampling and Adding Chemicals to Diesel Fuel Oil Storage Tanks, Revision 5

0-CY-1810, Diesel Fuel Oil Monitoring, Revision 14

0-CY-1810, Diesel Fuel Oil Monitoring, Revision 15

0-CY-3318, Water and Sediment in Fuel Oil, Revision 4

3-CY-2615, Adding Chemicals to Auxiliary Systems, Revision 1

0-GNR-402-ELC, Emergency Diesel Generator Main Fuel Oil Tank 10-Year

Maintenance, Revision 3

2-SOP-29.20, Fuel Oil Transfer Using the Trailer, Revision 8

IP-RPT-11-LRD10, Review of the Diesel Fuel Monitoring Aging Management Program

For License Renewal Implementation, Revision 0

Report on the 2012 Inspection of the Entergy Nuclear Operations Indian Point Station

No. 2 Fuel Oil Storage Tank GT2/3 FOT, November 27, 2012

Attachment

A-5

00347381, Fuel Oil Storage Tank Bottom Thickness UT

00349623, Fuel Oil Storage Tank Open, Clean & Inspect

Commitment 5

Condition Report CR-IP2-2013-01756 Revision 2 of ENN-MS-S-004

EN-DC-178, Revision 5, System Walkdowns

ENN-MS-S-004-IPEC, Rev 2 that documents the system categories

EN-DC-159, Revision 6, System Monitoring Program

Commitment 6, 33, 43, 44, and 45

2-PT-2Y015, Revision 3, Thermal Cycle Monitoring Program

IP-RPT-11-LRD13, Revision 0, Review of the Fatigue Monitoring Aging Management Program

for License Renewal Implementation

EN-LI-100, Revision 13, Process Applicability Determination

EN-AD-101, Revision 16, Procedure Process

WCAP-17199-P, July 2010, Environmental Fatigue Evaluation for Indian Point Unit 2

WCAP-17149-P, July 2010, Evaluation of Pressurizer Insurge/Outsurge Transients for Indian

Point Unit 2

Entergy Letter dated August 9, 2010 (NL-10-82), License Renewal Application - Completion of

Commitment #33 Regarding the Fatigue Monitoring Program Indian Point Nuclear

Generating Unit Nos. 2 and 3 [ML102300504]

Commitment 7

2-ENG-003-FIR, Detroit Diesel V-71, Emergency Fire Pump Diesel PM, Revision 5

2-PT-M040, Diesel Fire Pump, Revision 30

IP-RPT-11-LRD14, Review of the Fire Protection Aging Management Program for License

Renewal Implementation, Revision 2

SAO-703, Fire Protection Impairment Criteria and Surveillance, Revision 32

Commitment 8

2-PT-A017QA, Fire Hose Stations Inspections, Revision 8

A138057, City Water Supply Pipeline, Revision 18

CR-IP2-2004-01864, pin hole leak in fire water pipe

CR-IP2-2011-05889, Three pin hole leaks in fire water piping

IP2-UT-11-051/52/53, IP2-UT-12-016 thru 24, IP2-UT-12-026, and IP2-UT-12-028, Ultrasonic

Test Reports for Fire Protection Piping, performed between 12/11 and 7/12

IP-RPT-11-LRD15, Review of the Fire Water System Aging Management Program for License

Renewal Implementation, Revision 0

IP-RPT-12-LRD02, Fire Water Piping Wall Thickness Evaluation for License Renewal,

Revision 0

SAO-703, Fire Protection Impairment Criteria and Surveillance, Revision 32

SE-86-59, Specification for Fire Standpipe Systems and City Water Piping, Revision 0

Work Order 134345, Main Turbine Lube Oil Fire Protection Foam Tank Refill, performed 6/12/08

Work Order 339750, 10-year Fire Water Piping UT Inspections

Attachment

A-6

Work Order NP-01-22451, Main Feed Pump Lube Oil Fire Protection Foam Tank Drain & Refill,

performed 8/01/01

Work Orders 334193, 334196, 334198, and 334200, 4-year Visual Inspection of Foam Tank

Internal Surfaces for Significant Corrosion

Work Orders 335678, 335680, 335684, and 335686, 50-year Replacement of Sprinkler Heads

Commitment 9

Corrective Action document LO-LAR-2011-00174, CA 06

A206913-1, Reactor Vessel Inspection Identification DWG, for U2

A209564-1, Reactor Vessel bottom mounted instrumentation, for U2

Mistras Procedure 583-ET-008, Revision 1 for Eddy Current Inspection of Incore Thimble Tubes

IP-Calc-07-00038 dated 2/15/2007 on Reinspection frequency for IP3 Thimble Tubes

Mistras Eddy Current test results for Unit 2 and Unit 3 Thimble tubes dated 3/16/09, 3/18/10,

and 3/9/12 (U2)

Commitment 10

IP-RPT-11-LRD18, Revision 0, Review of the Heat Exchanger Performance and Condition

Monitoring Program

EN-DC-316, Revision 5, Heat Exchanger Performance and Condition Monitoring

SEP-HX-IP-001, Revision 1, IPEC Heat Exchanger/Eddy Current Program

Commitment 10 Implementation Matrix, May 4, 2013

IPEC Heat Exchanger and Eddy Current Inspection Program Data

MWO 332520-01

MWO 349349-01

PMRQ 30855-01

PMRQ 31465-02

Commitment 12, 25, and 37

EN-DC-150, Rev. 4, Structural monitoring Program

Specific IPEC inspection requirements, Attachment to EN-DC-150, Structural Monitoring

Program

Entergy Letter dated August 14, 2008, Commitment 37

Safety Evaluation Report Nureg 1930, Volume 2,

ASME Code,Section XI, Sub Sec. IWL

ASME IWL inspections performed in 2005 and 2009 using enhanced visual aids

ASTM C33-90, Guidance for Freeze-Thaw Monitoring

ER No. IP-RPT-11-00002, Revision 0, January 10, 2011, Assessment of Concrete Aging from

Selected Indian Point Structures

Commitment 13

2-ELC-016-BUS, Inspection, Cleaning and Testing of 480V Buses, Revision 2

CR-IP2-2009-03029, Inspect electrical supports affected by water dripping at the bend in the

electric tunnel. Initiate corrective actions where required.

CR-IP2-2012-01903, Bus 5A surface rust noted on the interior divider panel

Attachment

A-7

Work Order 52293872, Inspection of Bus 5A Switchgear and Station Service Transformer

Work Order 52294517, Inspection of Bus 5A (480 V Switchgear to EDG)

Commitment 14

IP-RPT-11-LRD23, Revision 0, Review of the Non-EQ Bolted Cable Connections Aging

Management

Program for License Renewal Implementation.

IP-RPT-13-LRD01, Non-EQ Bolted Cable Connection Evaluation, Revision 0

Work Orders related to Bolted Cable Connection Inspection Samples:

52249670, 52249670, 52339357, 52293872

Commitment 15

CR-IP2-2012-01307, The C phase Tan Delta values obtained were noticeably higher than the

remaining 2 phases for 24 CWP.

CR-IP2-2013-01480, During License Renewal walkdowns, deficiencies were noted with cables

that were not part of the program.

EN-DC-346, Cable Reliability Program, Revision 5

EN-MA-138, VLF Tan Delta and Withstand Testing of Electrical Power Cables, Revision 1

Work Orders related to periodic preventive maintenance inspection and dewatering of various

manholes: 52477039, 52459080, 52471206, 52449618, 52449619, 52449801,

52431438, 52431439, 52450288, 52431268, 52454018, 52454019

Commitment 16

IP-RPT-11-LRD25, Review of the Non-EQ Instrumentation Circuits Test Review Aging

Management Program for License Renewal Implementation

Report on ECAD Testing at Indian Point Unit 2, Dated November 2004

System Health Report for NI System (1st QT 2013)

Work Order 32099001, 4Y PEO Test Integrity of NI Cables N-31, N-32

Work Order 32099701, 4Y PEO Test Integrity of NI Cables N-35, N-36

Work Order 32100101, 4Y PEO Test Integrity of NI Cables N-41A/B through N-44A/B

Work Order 34926901, 8Y PEO Review of NI Calibration & Test Results

Work Order 51800948, High Range Containment Area Radiation Monitor R26 Calibration Test

(3/11/10)

Work Order 51800949, High Range Containment Area Radiation Monitor R25 Calibration Test

(3/11/10)

Work Order 52246190, High Range Containment Area Radiation Monitor R25 Calibration Test

(3/15/12)

Work Order 52246191, High Range Containment Area Radiation Monitor R26 Calibration Test

(3/11/12)

Attachment

A-8

Commitment 17

CR-IP2-2013-01480 and -01607, Cable walkdown deficiencies identified

Data Walkdown Sheets (e.g., field observation notes) for 21 RHR Pump Room, Primary

Auxiliary Bldg (PAB) 15 foot elevation Piping and Valve Room, PAB Chemical Drain

Tank Room, PAB Filter Room, PAB Large Gas Decay Tank Room, Electrical Cable

Tunnel, Turbine Bldg (TB) Ground Floor - West, and TB Ground Floor - North West,

walkdowns performed between 7/22/10 and 8/03/10

EN-DC-348, Non-EQ Insulated Cables and Connections Inspection, Revision4

IP-RPT-10-LRD15, Cable and Connection Inspection Summary Report, Revision 0

IP-RPT-11-LRD26, Review of the Non-EQ Insulated Cables and Connections Aging

Management Program for License Renewal Implementation, Revision 0

Work Order 348737 and 348751, 8-year Cable & Connection Inspection

Commitment 18

LO-LAR-2011-00174

A.2.1.25 Oil Analysis Program

B.1.26 Oil Analysis Program

EN-DC-335, Nuclear Management Manual, Revision 4

EN-DC-149, Entergy Nuclear Management Manual, Rev. 6

SEP-LUB-IPC-001, IPEC Lubrication Program, Revision 0

SEP-LUB-IPC-002, IPEC Oil Analysis Program, Revision 0

SEP-LUB-IPC-002, IPEC Oil Analysis Program, Revision 1

PM Basis Template, EN - Pump - Horizontal with Couplings, Revision 4

Commitment 19

IP-RPT-11-LRD28, Revision 0, Review of the One-Time Inspection Program

EN-FAP-LR-024, Revision 1, One-Time Inspection

NL-13-046, Amendment 13 to LRA for One-Time Inspection and Selective Leaching Programs,

March 18, 2013

IPEC Unit 2 One-Time Inspection Tracking Matrix, May 3, 2013 and May 21, 2013

20 Inspection reports for one-time inspections

Commitment 20

UT Calibration Examination and Report Sheets:

206723-969A CVC CW Elbow-to-Pipe Component 96 9A

206723-969B CVC Circ-Weld Component 96 9B

206723-963.RI CVC Circ-Weld Component 96 3

206723-964.RI CVC Circ-Weld Component 96 4

206723-962.RI CVC Circ-Weld Component 96 2

206713-793.RI CVC Circ-Weld Component 79 3

Corrective Action LO-LAR-2011-00174 NRC Commitment #20

Commitment Closure Verification Form IP2 A-3230/ LO-LAR-2011-00174 -12

Attachment

A-9

Entergy Letter NL-07-153, Amendment 1 to License Renewal Application (LRA), 12/18/2007

Entergy Letter NL-10-076, Amendment 10 to License Renewal Application (LRA), 7/26/2010

Entergy Letter NL-11-032, Response to Request for Additional Information, 3/28/2011

Entergy Letter NL-11-074, Response to Request for Additional Information, 7/14/2011

LR Request #173

IP-RPT-11-LRD29, Revision 0, Review of the One-Time Inspection - Small Bore Piping

Program for License Renewal Implementation, 1/16/2013

Commitment 21

IP-RPT-11-LRD30, Review of the Periodic Surveillance and Preventive Maintenance

Aging Management Program for License Renewal Implementation, Revision 0

0-PT-M002, Alternate Safe Shutdown Equipment Inventory and Inspection, Revision 8

2-PT-Q033A, 21 Charging Pump, Revision 17

LO-LAR-2011-00174

A.2.1.28 Periodic Surveillance and Preventive Maintenance Program

B.1.29 Periodic Surveillance and Preventive Maintenance

WO 00307819, U2 offsite power feeder 138 kV underground transmission cable

WO 00332413, Unit 2 SBO/Appendix R Diesel Generator

WO 00334380, Station Air System

WO 00324716, Circulation Water System

WO 00334184, Emergency Diesel Generator System

Commitment 22

Corrective Action LO-LAR-2011- 00174, Enhance the Reactor Vessel Surveillance Program,

8/20/2011

Entergy Letter NL-07-140, Reply to Request for Additional Information Regarding License

Renewal Application, November 28, 2007

Entergy Nuclear Management Manual, EN-DC-149 Revision 6, Vendor Document Review

Status, Review of the Reactor Vessel Surveillance Aging Management Program for

License Renewal Implementation, EC38922, 1/2/2013

Westinghouse WCAP-16752-NP, Revision 0, Indian Point Heatup and Cooldown Limit Curves

for Normal Operation, January 2008.

Commitment 23

IP-RPT-11-LRD34, Revision 0, Review of the Selective Leaching Program

EN-FAP-LR-02, Revision 3, Selective Leaching Inspection

NL-13-046, Amendment 13 to LRA for One-Time Inspection and Selective Leaching Programs,

March 18, 2013

IPEC Unit 2 Selective Leaching Inspection Tracking Matrix, May 20, 2013

10 Inspection reports for copper-alloy selective leaching inspections

12 Inspection reports for gray cast iron selective leaching inspections

WO 00326036-01

WO 00326216-01

Attachment

A-10

Commitment 24

Corrective Action document LO-LAR-2011-0174 CA 17

SEP-SG-IP2-001, Revision 0, IP2 Steam Generator Program

SEP-SG-IP3-001, Revision 0, IP3 Steam Generator Program

EN-DC-317, Revision 7, Steam Generator Program

IP-RPT-11-LRD36, Revision 0, Review of the Steam Generator Integrity Aging Management

Program for License Renewal Implementation

Commitment 26

Entergy Letter, NL-09-018, Reply to Request for Additional Information - Miscellaneous Items,

January 27, 2009

Entergy Letter NL-11-101, Clarification for Additional Information (RAI) Aging Management

Programs, August 22, 2011

LR# 173, LR Request, Confirm each AMP will be implemented with ten elements

IP-RPT-11-LRD38, Review the Thermal Aging Embrittlement of CASS Aging Management

Program for License Renewal Implementation, 1/2/2013

NRC Letter, License Renewal Issue No. 98-0030, Thermal Aging Embrittlement of Cast

Austenitic Stainless Steel Components, May 19, 2000

WCAP-10977, Supplement 1, Additional Information in Support of the Technical Justification for

Eliminating Large Primary LOOP Pipe Rupture as the Structural Design Basis for Indian

Point Unit 2, January 1989

Commitments 27, 47

IP-RPT-11-LRD39, Revision), Review of the Thermal Aging & Neutron Embrittlement of CASS

Aging Management Program for License Renewal Implementation, ED41109,

1/23/2013

EPRI 1013234 Materials Reliability Program: Screening, Categorization, and Ranking of

Reactor Internals Components for Westinghouse and Combustion Engineering PWR

Design (MRP-191), November 2006

EPRI 1022863 Materials Reliability Program: Pressurized Water Reactor Internals Inspection

and Evaluation Guidelines (MRP-227-A), December 2011

NRC Letter Request for Additional Information for the Review of the Indian Point Nuclear

Generating Unit Nos. 2 and 3, License Renewal Application, May 15, 2012

Entergy Letter, NL-11-101, Clarification for Request for Additional Information (RAI) Aging

Management Programs, 8/22/2011

Entergy Letter NL-13-052, Reply to Request for Additional Information Regarding the License

Renewal Application, 5/7/2011

LR Request #173 Confirm new programs will be implemented consistent with 10 elements of

NUREG-1801.

IP-RPT-11-LRD39 Review of the Thermal Aging & Neutron Irradiation Embrittlement of CASS

Aging Management Program for License Renewal Implementation, EC41109, 1/2/13

Attachment

A-11

Commitment 30

Entergy Letter NL-10-063, Amendment 9 to License Renewal Application (LRA) - Reactor

Vessel Internals Program, dated 7/14/2010

Entergy Letter NL-11-101, Clarification for Request for Additional Information (RAI), Aging

Management Programs, 08/22/2011

Entergy Letter NL-11-107, License Renewal Application - Completion of Commitment #30

Regarding the Reactor Vessel Internals Inspection Plan, 09/28/2011

Entergy Letter NL-12-037, License Renewal Application - Revised Reactor Vessel Internals

Program and Inspection Plan Compliant with MRP-227-A, 02/17/2012

Entergy Letter NL-12-089, Reply to Request for Additional Information Regarding the License

Renewal Application, 06/14/2012

Entergy Letter NL-12-134, Reply to Request for Additional Information Regarding the License

Renewal Application, 09/28/2012

Entergy Letter NL-12-140, Reply to Request for Additional Information Regarding the License

Renewal Application, 10/17/2012

IP-RPT-11-LRD43, Review of the Reactor Vessel Internals Aging Management Program for

License Renewal Implementation, EC40997, Revision 0, 4/10/2013

Commitment 31

Entergy Letter NL-13-001, Proposed Changes to Indian Point 2 Technical Specifications

Regarding reactor Vessel Heatup and Cooldown Curves and Low Temperature Over

Pressure Requirements. 2/6/2013

Entergy Letter NL-07-140, NRC letter dated October 28, 2007; Requests for Additional

Information for the Review of the Indian Point Nuclear Generating Unit Nos. 2 and 3,

License Renewal Application

Commitment 35

Work order No. 00282078-01 for inspection of representative sample area of the IP2

containment liner affected by the 1973 event behind the insulation

Work order No. 00316062-01 for the Unit 3 one time inspection containment steel liner at the

juncture with the concrete floor slab.

Drawing A202453, Revision 28, Containment building, Elv 68, South Half

Commitment 38

Entergy Letter NL-08-143, Additional Information Regarding License Renewal Application -

Reactor Vessel Fluence Clarification, 9/24/2008

Entergy Letter NL-11-101, Clarification for Request for Additional Information (RAI) Aging

Management Programs, 8/22/2011

IP-RPT-11-LRD33, Review of Reactor Vessel Surveillance Aging Management Program for

License Renewal Implementation, 1/2/2013

Attachment

A-12

Commitment 41

Corrective Action document LO-LAR-2011-0174 CA 58, 59, for commitment closure

IP-RPT-11-LRD36, Revision 0. Review of the Steam Generator Integrity Aging Management

Program for License Renewal Implementation

EPRI report on Divider Plate cracking presented at the SGMP Meeting in June 2012

EPRI Technical Report # 3002000411, dated April 2013 on the Flaw Tolerance Evaluation of

the Steam Generator Channel Head

Commitment 42

LO-LAR-2011-0174 CA 60, 61

Corrective Action document LO-LAR-2011-0174 CA 60, 61, for commitment closure

Condition Report CR-IP2-2013-01440, Revision 2

IP-RPT-11-LRD36, Revision 0. Review of the Steam Generator Integrity Aging Management

Program for License Renewal Implementation

Aging Management SER section 3.1.2.2.17, Cracking due to SCC and PWSCC

Commitment 46

As referenced in the report.

Commitment 48

Work Order PMRQ 00349816-01, 23 Fuel Oil Storage Tank Underground Piping Inspections

Work Order PMRQ 00349802-01, 21 Fuel Oil Storage Tank Underground Piping Inspections

Work Order PMRQ 00349814-01, 22 Fuel Oil Storage Tank Underground Piping Inspections

Work Order 00342492-01, Inspect Underground Piping by the IP2 EDG Building DF-2 Area

Work Order 00342493-01, Inspect Underground Piping by the IP2 EDG Building DF-2-1 Area

Work Order 00342494-01, Inspect Underground Piping by the IP2 EDG Building DF-2-2 Area

2.B.1.5 Boric Acid Corrosion Control, Existing Aging Management Program (AMP)

Corrective Action document LO-LAR-2011-00174, CA 30

SEP-BAC-IPC-001, Revision 0, IP2, IP3 Site Boric Acid Corrosion Control Program

CEP-BAC-IPC-001, Revision 1, Corporate Boric Acid Corrosion Control Program Plan

EN-DC -319, Revision 9, Boric Acid Corrosion Control Program (BACCP)

2-PT-R156, Revision 4, RCS Boric Acid Leakage and Corrosion Inspection (during outages).

2-PT-Q092, Revision 7, Containment Building Inspection (during operation)

EN-DC-178, Revision 5, System Walkdowns

Engineering Report No. IP-RPT-11-LRD06, Revision 0, Review of the Boric Acid Corrosion

Prevention Aging Management Program for License Renewal Implementation

Attachment