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IR 05000247-08-005; 10/01/2008 - 12/31/2008; Indian Point Nuclear Generating Unit 2; Resident Inspector Quarterly Integrated Inspection Report
	ML090340463
Person / Time
Site:	Indian Point
Issue date:	02/03/2009
From:	Gray M K; Reactor Projects Branch 2
To:	Pollock J E; Entergy Nuclear Operations, Entergy Operations
	Gray, Mel NRC/RGNI/DRP/PB2/610-337-5209
References
	FOIA/PA-2009-0094, FOIA/PA-2010-0209 IR-08-005
	Download: ML090340463 (39)
	v • d • e

February 3, 2009

Mr. Joseph 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 INTEGRATED INSPECTION REPORT 05000247/2008005

Dear Mr. Pollock:

On December 31, 2008, the U.S. Nuclear Regulatory Commission (NRC) completed an inspection at Indian Point Nuclear Generating Unit 2. The enclosed integrated inspection report documents the inspection results, which were discussed on January 9, 2009, with you and other members of your staff.

The inspection examined activities conducted under your license as they relate to safety and compliance with the Commission's rules and regulations, and with the conditions of your license. The inspectors reviewed selected procedures and records, observed activities, and interviewed personnel.

Based on the results of this inspection, no findings of significance were identified.

However, a licensee-identified violation which was determined to be of very low safety significance is listed in this report. The NRC is treating this violation as a non-cited violation (NCV) consistent with Section VI.A.1 of the NRC Enforcement Policy because of the very low safety significance of the violation and because it is entered into your corrective action program. If you contest this non-cited violation, you should provide a response within 30 days of the date of this inspection report, with the basis for your denial, to the Nuclear Regulatory Commission, ATTN.: Document Control Desk, Washington DC 20555-0001; with copies to the Regional Administrator, Region I; the Director, Office of Enforcement, United States Nuclear Regulatory Commission, Washington, DC 20555-0001; and the NRC Resident Inspector at the Indian Point Nuclear Generating Station, Unit 2.

In accordance with Title 10 of the Code of Federal Regulations Part 2.390 of the NRC's "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 of from the Publicly Available Records (PARS) component of the NRC's document system (ADAMS).

ADAMS is accessible from the NRC Web Site at http://www.nrc.gov/reading-rm/adams.html (the Public Electronic Reading Room).

Sincerely,/RA/

Mel Gray, Chief Projects Branch 2 Division of Reactor Projects

Docket No. 50-247 License No. DPR-26

Enclosure:

Inspection Report No. 05000247/2008005 w/

Attachment:

Supplemental Information cc w/encl:

Senior Vice President, Entergy Nuclear Operations Vice President, Operations, Entergy Nuclear Operations Vice President, Oversight, Entergy Nuclear Operations Senior Manager, Nuclear Safety and Licensing, Entergy Nuclear Operations Senior Vice President and COO, Entergy Nuclear Operations Assistant General Counsel, Entergy Nuclear Operations Manager, Licensing, Entergy Nuclear Operations C. Donaldson, Esquire, Assistant Attorney General, New York Department of Law A. Donahue, Mayor, Village of Buchanan J. G. Testa, Mayor, City of Peekskill R. Albanese, Four County Coordinator S. Lousteau, Treasury Department, Entergy Services, Inc. Chairman, Standing Committee on Energy, NYS Assembly Chairman, Standing Committee on Environmental Conservation, NYS Assembly Chairman, Committee on Corporations, Authorities, and Commissions M. Slobodien, Director, Emergency Planning P. Eddy, NYS Department of Public Service Assemblywoman Sandra Galef, NYS Assembly T. Seckerson, County Clerk, Westchester County Board of Legislators A. Spano, Westchester County Executive R. Bondi, Putnam County Executive C. Vanderhoef, Rockland County Executive E. A. Diana, Orange County Executive T. Judson, Central NY Citizens Awareness Network M. Elie, Citizens Awareness Network D. Lochbaum, Nuclear Safety Engineer, Union of Concerned Scientists Public Citizen's Critical Mass Energy Project M. Mariotte, Nuclear Information & Resources Service F. Zalcman, Pace Law School, Energy Project L. Puglisi, Supervisor, Town of Cortlandt Congressman John Hall Congresswoman Nita Lowey Senator Hillary Rodham Clinton Senator Charles Schumer G. Shapiro, Senator Clinton's Staff J. Riccio, Greenpeace P. Musegaas, Riverkeeper, Inc. M. Kaplowitz, Chairman of County Environment & Health Committee A. Reynolds, Environmental Advocates D. Katz, Executive Director, Citizens Awareness Network K. Coplan, Pace Environmental Litigation Clinic M. Jacobs, IPSEC W. Little, Associate Attorney, NYSDEC M. J. Greene, Clearwater, Inc. R. Christman, Manager Training and Development J. Spath, New York State Energy Research, SLO Designee F. Murray, President & CEO, New York State Energy Research A. J. Kremer, New York Affordable Reliable Electricity Alliance (NY AREA)

ADAMS is accessible from the NRC Web Site at http://www.nrc.gov/reading-rm/adams.html (the Public Electronic Reading Room).

Sincerely,/RA/ Mel Gray, Chief Projects Branch 2 Division of Reactor Projects

Docket No. 50-247 License No. DPR-26

Enclosure:

Inspection Report No. 05000247/2008005 w/

Attachment:

Supplemental Information Distribution w/encl:

S. Collins, RA M. Dapas, DRA D. Lew, DRP J. Clifford, DRP Stephen Campbell, RI OEDO R. Nelson, NRR M. Kowal, NRR J. Boska, PM, NRR J. Hughey, NRR S. Hansell, DRS M. Gray, DRP B. Bickett, DRP A. Rosebrook, DRP S. McCarver, DRP G. Malone, DRP, SRI - Indian Point 2 C. Hott, DRP, RI - Indian Point 2 Region I Docket Room (w/concurrences) ROPreport Resources (All IRs)

SUNSI Review Complete: _BB__ (Reviewer's Initial)

ML090340463 DOCUMENT NAME: G:\DRP\BRANCH2\a - Indian Point 2\Inspection Reports\IP2 IR2008-005\IP2 2008005 r5.doc After declaring this document "An Official Agency Record" it will be released to the Public To Receive a copy of this document, indicate in the box: "C" = Copy without attachment/enclosure "E" = Copy with attachment/enclosure "N" = No copy Office RI/DRP RI/DRP RI/DRP Name GMalone/BB for BBickett/BB MGray/MG Date 02/02/09 01/27/09 02/02/09 OFFICAL AGENCY RECORD 1 Enclosure

U.S. Nuclear Regulatory Commission Region I Docket No.: 50-247 License No.: DPR-26

Report No.: 05000247/2008005 Licensee: Entergy Nuclear Northeast (Entergy)

Facility: Indian Point Nuclear Generating Unit 2 Location: 450 Broadway, GSB Buchanan, NY 10511-0249

Dates: October 1, 2008 through December 31, 2008

Inspectors: G. Malone, Senior Resident Inspector, Indian Point 2 C. Hott, Resident Inspector, Indian Point 2 P. Cataldo, Senior Resident Inspector, Indian Point 3 A. Koonce, Resident Inspector, Indian Point 3 J. Noggle, Reactor Inspector, Region I J. Commisky, Reactor Inspector, Region I A. Rosebrook, Senior Project Engineer, Region I R. Fuhrmeister, Senior Project Engineer, Region I D. Silk, Senior Operations Engineer, Region I B. Haagensen, Operations Engineer, Region I Approved By: Mel Gray, Chief Projects Branch 2 Division of Reactor Projects Enclosure

SUMMARY OF FINDINGS

IR 05000247/2008005; 10/01/2008 - 12/31/2008; Indian Point Nuclear Generating Unit 2; Resident Inspector Quarterly Integrated Inspection Report.

This report covered a three-month period of inspection by resident and region based inspectors.

The NRC's program for overseeing safe operation of commercial nuclear power reactors is described in NUREG-1649, "Reactor Oversight Process," Revision 4, dated December 2006.

A. NRC-Identified and Self-Revealing Findings

No findings of significance were identified.

B. Licensee-Identified Violations

A violation of very low safety significance that was identified by Entergy was reviewed by the inspectors. Corrective actions taken or planned by Entergy were entered into Entergy's corrective action program. The violation and its corrective action tracking numbers are listed in Section 4OA7.

REPORT DETAILS

Summary of Plant Status

Indian Point Nuclear Generating Unit 2 began the inspection period operating at 100 percent reactor power. Operators reduced plant power to 85 percent on October 22 to repair an expansion joint on the suction piping of the 22 condensate pump. The plant was returned to full power operation on October 23. Unit 2 operated at or near full power for the remainder of the inspection period.

REACTOR SAFETY

Cornerstones: Initiating Events, Mitigating Systems, and Barrier Integrity

1R01 Adverse Weather Protection

Main article: IP 71111.01

.1 Cold Weather Preparations

a. Inspection Scope

The inspectors reviewed the readiness of risk-significant systems for extreme cold-weather conditions. The inspectors reviewed Entergy's adverse weather procedures, operating experience, corrective action program, Updated Final Safety Analysis Report (UFSAR), Technical Specifications (TS), operating procedures, staffing, and applicable plant documents to determine the types of adverse weather challenges to which the site is susceptible. The following risk-significant systems that were required to be protected from adverse weather conditions were selected and collectively represent one inspection sample:

Primary, refueling, and primary water storage tanks;

Service water intake structure and components; and

Fire water storage tank.

b. Findings

No findings of significance were identified.

.2 External Flooding

a. Inspection Scope

The inspectors reviewed the readiness of barriers to external flooding for the service water intake structure and related equipment. The inspectors reviewed Entergy's adverse weather procedures, abnormal operating procedures, operating experience, Updated Final Safety Analysis Report (UFSAR), and Internal Plant Examination of External Events (IPEEE) to determine susceptibilities to external floods and review the site's methods to mitigate the effects of external flooding. The inspectors walked down the service water pump vault and the strainer vaults to verify the integrity of the structures and components contained within to the effects of flooding. The inspectors 3 Enclosure also verified that barriers and systems used to mitigate flooding were available and in adequate material condition.

b. Findings

No findings of significance were identified.

1R04 Equipment Alignment

Main article: IP 71111.04Q

Partial System Walkdowns

a. Inspection Scope

The inspectors performed partial system walkdowns to verify the operability of redundant or diverse trains and components during periods of system train unavailability, or following periods of maintenance. The inspectors referenced the system procedures, the UFSAR, and system drawings to verify that the alignment of the available train supported its required safety functions. The inspectors also reviewed applicable condition reports (CR) and work orders to ensure that Entergy had identified and properly addressed equipment discrepancies that could potentially impair the capability of the available train, as required by Title 10 of the Code of Federal Regulations (10 CFR) Part 50, Appendix B, Criterion XVI, "Corrective Action." Documents reviewed during this inspection are listed in the Attachment.

The inspectors performed a partial walkdown on the following systems, which represented four inspection samples:

21 residual heat removal (RHR) pump train during 22 RHR pump maintenance;

Appendix R diesel following restoration from planned maintenance;

23 safety injection (SI) pump train during 21 SI pump breaker maintenance; and

22 and 23 emergency diesel generators and 22 auxiliary feed pump during maintenance on 21 emergency diesel generator.

b. Findings

No findings of significance were identified.

1R05 Fire Protection

Main article: IP 71111.05Q

a. Inspection Scope

The inspectors conducted tours of fire areas to assess the material condition and operational status of fire protection features. The inspectors verified, consistent with the applicable administrative procedures, that: combustibles and ignition sources were adequately controlled; passive fire barriers, manual fire-fighting equipment, and suppression and detection equipment were appropriately maintained; and compensatory measures for out-of-service, degraded, or inoperable fire protection equipment were implemented in accordance with Entergy's fire protection program. The inspectors evaluated the fire protection program against the requirements of License Condition 2.K. The documents reviewed during this inspection are listed in the Attachment. This 4 Enclosure inspection represented six inspection samples for fire protection tours, and was conducted in the following areas:

Zone 8, Boric acid transfer pump (BATP) and tank area;

Zone 74A, Electrical penetration area;

Zone 2, Containment spray pump room;

Zone 1, Component cooling water pump room;

Zones 12,13, and 14, 125-Vdc vital battery rooms (batteries 21, 22, and 24); and

Zones 3 and 4, Residual heat removal pump rooms (pumps 21 and 22).

b. Findings

No findings of significance were identified.

1R11 Licensed Operator Requalification Program

.1 Quarterly Review

Main article: IP 71111.11Q

a. Inspection Scope

On August 18, 2008, the inspectors observed licensed operator simulator training to verify that operator performance was adequate, and that evaluators were identifying and documenting crew performance problems. The inspectors evaluated the performance of risk-significant operator actions, including the use of emergency operating procedures. The inspectors assessed the clarity and effectiveness of communications, the implementation of appropriate actions in response to alarms, the performance of timely control board operation and manipulation, and the oversight and direction provided by the control room supervisor. The inspectors also reviewed simulator fidelity with respect to the actual plant. The inspectors evaluated licensed operator training against the requirements of 10 CFR Part 55, "Operator Licenses." The documents reviewed during this inspection are listed in the Attachment. This observation of operator simulator training represented one inspection sample.

b. Findings

No findings of significance were identified.

.2 Biennial Review

Main article: IP 71111.11B

a. Inspection Scope

The following inspection activities were performed using NUREG 1021, Rev. 9, AOperator Licensing Examination Standards for Power Reactors;

@ and NRC Inspection Procedure 71111.11, ALicensed Operator Requalification Program,@ Appendix A AChecklist for Evaluating Facility Testing Material

@ and Appendix B ASuggested Interview Topics.@ The inspectors reviewed recent operating history documentation found in inspection reports, licensee event reports, the licensee

=s corrective action program, and the most recent NRC plant issues matrix (PIM). The inspectors also reviewed specific events 5 Enclosure from Entergy

=s corrective action program which indicated possible training deficiencies, to verify they had been appropriately addressed. The senior resident inspector was also consulted for insights regarding licensed operators

= performance.

The remediation plans for a crew or individual

=s performance weaknesses or enhancements were reviewed by the inspectors to assess the effectiveness of the remedial training. The inspectors interviewed operators, instructors and training/operation

=s management for feedback on their training program and the quality of training received.

The inspectors reviewed simulator performance and fidelity for conformance to the reference plant control room.

A sample of records for requalification training attendance, program feedback, reporting, and medical examinations were reviewed by the inspectors for compliance with license conditions, including NRC regulations.

The inspectors reviewed the operating tests for the weeks of September 29 and October 6, 2008, for content, quality and overlap. Likewise, the 2007 written exam was reviewed for content, quality, and overlap.

The inspectors observed dynamic simulator exams and job performance measures administered during the week of October 6, 2008. These observations included facility evaluations of crew and individual performance during the dynamic simulator exams and individual performance of five JPMs.

On October 20, 2008, the inspectors reviewed the results of the annual operating tests for year 2008 and the written exam for 2007 to determine if pass/fail rates were consistent with the guidance of NUREG-1021, Revision 9, AOperator Licensing Examination Standards for Power Reactors

@ and NRC Manual Chapter 0609, Appendix I, AOperator Requalification Human Performance Significance Determination Process (SDP).@ The review verified the following:

$ Crew failure rate on the dynamic simulator was less than 20%.

(Failure rate was 0.0%)

$ Individual failure rate on the dynamic simulator test was less than or equal to 20%. (Failure rate was 0.0%)

$ Individual failure rate on the walkthrough test (job performance measures) was less than or equal to 20%. (Failure rate was 0.0%)

$ Individual failure rate on the 2007 comprehensive written exam was less than or equal to 20%. (Failure rate was 0.0%)

$ More than 75% of the individuals passed all portions of the exam (100% of the individuals passed all portions of the exam).

b. Findings and Observations

No findings of significance were identified.

1R12 Maintenance Effectiveness

Main article: IP 71111.12Q

a. Inspection Scope

The inspectors reviewed performance-based problems that involved structures, systems, and components (SSCs) to assess the effectiveness of maintenance activities. When applicable, the reviews focused on:

Proper Maintenance Rule scoping in accordance with 10 CFR 50.65;

Characterization of reliability issues;

Changing system and component unavailability;

10 CFR 50.65(a)(1) and (a)(2) classifications;

Identifying and addressing common cause failures;

Trending of system flow and temperature values;

Appropriateness of performance criteria for SSCs classified (a)(2); and

Adequacy of goals and corrective actions for SSCs classified (a)(1).

The inspectors also reviewed system health reports, maintenance backlogs, and Maintenance Rule basis documents. The inspectors evaluated maintenance effectiveness and monitoring activities against the requirements of 10 CFR 50.65.

The documents reviewed during this inspection are listed in the Attachment. The following Maintenance Rule samples were reviewed and represented two inspection samples:

Service water pumps; and

Buried piping inspections of the condensate storage tank supply piping to the auxiliary feedwater system.

b. Findings

No findings of significance were identified.

1R13 Maintenance Risk Assessments and Emergent Work Control

Main article: IP 71111.13

a. Inspection Scope

The inspectors reviewed scheduled and emergent maintenance activities to verify that the appropriate risk assessments were performed prior to removing equipment from service for maintenance or repair. The inspectors verified that risk assessments were performed as required by 10 CFR 50.65(a)(4), and were accurate and complete. When emergent work was performed, the inspectors verified that the plant risk was promptly reassessed and managed. Documents reviewed during this inspection are listed in the Attachment. The following activities represented four inspection samples:

Planned elevated-risk maintenance condition for 23 charging pump motor replacement;

Planned elevated-risk maintenance condition for an endurance run on the 23 emergency diesel generator performed once every 18-months;

Planned elevated-risk maintenance condition during 21 auxiliary boiler feedwater pump breaker outage; and

Planned elevated-risk maintenance condition during 138kv [kilovolt] feeder outage and safety injection system testing.

b. Findings

No findings of significance were identified.

1R15 Operability Evaluations

Main article: IP 71111.15

a. Inspection Scope

The inspectors reviewed operability evaluations to assess the acceptability of the evaluations, the use and control of compensatory measures when applicable, and compliance with Technical Specifications. The inspectors' reviews included verification that operability determinations were performed in accordance with procedure ENN-OP-104, "Operability Determinations." The inspectors assessed the technical adequacy of the evaluations to ensure consistency with the Technical Specifications, UFSAR, and associated design basis documents (DBDs). The documents reviewed are listed in the Attachment. The following operability evaluations were reviewed and represented two inspection samples:

Impact of incorrect component materials on component cooling pump constant level oilers; and

Accumulator leak on nitrogen system supply for power-operated relief valve PCV-455C.

b. Findings

No findings of significance were identified.

1R18 Plant Modifications

Main article: IP 71111.18

a. Inspection Scope

The inspectors reviewed a temporary plant modification package associated with an additional nitrogen supply connected to the air supply system for the 138kV 52/BT4-5 air-operated breaker. The breaker's function is to provide an alternate path for 138kV offsite power to be cross-connected between Indian Point Units 2 and 3. The temporary modification was installed to address a degrading air compressor on the breaker until corrective maintenance is performed. The inspectors verified that the design bases, licensing bases, and performance capability of the system was not negatively impacted by the temporary modification. In addition, the inspectors interviewed plant staff, and reviewed issues that were entered into the corrective action program to determine whether Entergy had been effective in identifying and resolving problems associated with the temporary modification. The documents reviewed are listed in the Attachment.

b. Findings

No findings of significance were identified.

1R19 Post-Maintenance Testing

Main article: IP 71111.19

a. Inspection Scope

The inspectors reviewed post-maintenance test procedures and associated testing activities for selected risk-significant mitigating systems, and assessed whether the effect of maintenance on plant systems was adequately addressed by control room and engineering personnel. The inspectors verified that: test acceptance criteria were clear, demonstrated operational readiness and were consistent with design basis documentation; test instrumentation had current calibrations, and appropriate range and accuracy for the application; and the tests were performed as written, with applicable prerequisites satisfied. Upon completion of the tests, the inspectors verified that equipment was returned to the proper alignment necessary to perform its safety function. Post-maintenance testing was evaluated against the requirements of 10 CFR 50, Appendix B, Criterion XI, "Test Control." The documents reviewed are listed in the Attachment. The following post-maintenance activities were reviewed and represented seven inspection samples:

25 service water pump following bearing repair;

23 charging pump following motor replacement;

21 auxiliary boiler feed pump (ABFP) alternate safe shutdown breaker test;

21 service water pump 480V breaker replacement;

22 ABFP following maintenance on steam supply valve PCV-1139;

21 emergency diesel generator following semi-annual jacket water and lube oil heat exchanger inspections; and

22 containment fan cooler unit following bearing lubrication.

b. Findings

No findings of significance were identified.

1R22 Surveillance Testing

Main article: IP 71111.22

a. Inspection Scope

The inspectors observed performance of portions of surveillance tests and/or reviewed test data for selected risk-significant SSCs to assess whether they satisfied Technical Specifications, UFSAR, Technical Requirements Manual, and Entergy procedure requirements. The inspectors verified that: test acceptance criteria were clear, demonstrated operational readiness, and were consistent with design basis documentation; test instrumentation had accurate calibration, and appropriate range and accuracy for the application; and tests were performed as written, with applicable prerequisites satisfied. Following the tests, the inspectors verified that the equipment was capable of performing the required safety functions. The inspectors evaluated the surveillance tests against the requirements in Technical Specifications. The documents reviewed during this inspection are listed in the Attachment. The following surveillance tests were reviewed and represented six inspection samples:

2-PC-4Y74C, nuclear instruments power range N-43 channel calibration;

2-PT-V59, reactor trip breaker "A" changeout and functional test;

2-PT-Q035B, 22 containment spray in-service test;

2-PC-2Y55, channel calibration of containment sump level indicator LT-941;

2-NF-309, reactor coolant system loop delta-T, T-average, and flow measurement; and

PT-Q13, valve stroke 869B (containment isolation valve).

b. Findings

No findings of significance were identified.

Cornerstone:

Emergency Preparedness (EP)1EP2 Alert and Notification System (ANS) Evaluation

a. Inspection Scope

The inspectors observed a full-volume siren test on October 22, 2008 to verify Entergy's newly installed siren system functioned properly. The inspectors verified that the minimum required number of sirens functioned when actuated. This inspection was conducted in accordance with the baseline inspection program deviation authorized by the NRC Executive Director of Operations (EDO) in a memorandum dated October 31, 2005, and renewed by the EDO in a memorandum dated December 19, 2007.

b. Findings

No findings of significance were identified.

RADIATION SAFETY

Cornerstone:

Occupational Radiation Safety (OS)2OS3 Radiation Monitoring Instrumentation and Protective Equipment

a. Inspection Scope

(71121.03 - 9 samples)

During December 15-19, 2008, the inspectors conducted the following activities to evaluate the operability and accuracy of radiation monitoring instrumentation, and the adequacy of the respiratory protection program for issuing self-contained breathing apparatus (SCBA) to emergency response personnel. Implementation of these programs was reviewed by the inspectors against the criteria contained in 10 CFR 20, applicable industry standards, and Entergy's procedures.

1) The inspectors reviewed the UFSAR to identify area radiation monitors that are installed at Indian Point Units 2 and 3 for the protection of workers, and reviewed the calibration procedure and current calibration records for selected instrumentation, including Unit 2 plant radiation monitors; main steam line 10 Enclosure radiation monitors (R-28, R-29, R-30, R-31), refuel floor area radiation monitor (R-5), containment high-range radiation and noble gas monitors (R-25, R-26), gaseous and particulate containment radiation monitors (R-42, R-41), in-core area radiation monitor (R-7), steam generator blow down radiation monitor (R-49); Unit 3 plant radiation monitors; main steam line radiation monitors (R-62A, R-62B, R-62C, R-62D), refuel floor area radiation monitor (R-5), containment high-range radiation and noble gas monitors (R-25, R-26), gaseous and particulate containment radiation monitors (R-12, R-11), in-core area radiation monitor (R-7), and steam generator blow down radiation monitor (R-19). The inspectors discussed the monitoring system health reports and instrument reliability trends with the system engineer.

2) The inspectors identified various radiation detection instruments used at Indian Point used for job coverage for work in radiologically significant areas, including continuous air monitors and whole body counters. Instruments evaluated were 49 electronic dosimeters, 13 radiation survey instruments, 12 extendable probe survey instruments, 6 neutron radiation survey instrument, 6 continuous air monitors, 4 portal monitors, 7 beta/alpha counters and 2 whole body counters.

3) Current calibration records, applicable calibration procedures, operability, and alarm set points were reviewed by the inspectors for the instruments identified above. In addition, the inspectors reviewed the applicable calibrators utilized for appropriate instrument calibration geometries and National Institute for Science and Technology standard traceability. They included: Shepherd 81-12B beam source calibrators, Shepherd 142-10 panoramic calibrator, Shepherd 149 neutron source calibrator and Shepherd 1000B box source calibrator. The plant source term was reviewed by the inspectors to determine whether calibration sources being used were representative.

4) Radiological incidents involving internal exposures identified by condition reports for 2008 were reviewed by the inspectors. In addition, dosimetry electronic records were queried for any internal exposures >50 mrem committed effective dose equivalent (CEDE). None were identified for further review.

5) The inspectors reviewed condition reports with respect to radiation protection program deficiencies to determine if the deficiencies were appropriately characterized and corrected commensurate with their safety significance.

6) Based on the condition reports reviewed, no repetitive deficiencies were identified for further follow-up.

7) With respect to the RP portable instruments listed in 3) above, the instrument

=s calibration expiration and response check stickers were reviewed by the inspectors. The applicable response check beta-source and instrument sign-out procedures were also reviewed. The inspectors queried radiation protection technicians regarding appropriate instrument selection and observed self verification of instrument operability prior to use.

8) The inspectors sampled emergency plan-specified self contained breathing apparatus (SCBA) equipment and qualified users based on Indian Point Energy Center Emergency Plan documents and included inspection of selected SCBAs 11 Enclosure and air bottle cascade systems located inside or adjacent to both the Unit 2 and Unit 3 main control rooms. The inspectors verified SCBA qualification records for select on-shift reactor operators were current. The inspectors also verified that air used to fill the SCBAs met the Grade D quality criteria of the Compressed Gas Association. The inspectors queried on shift reactor operators to determine the storage location of required spectacles.

9) The inspectors examined selected SCBA units for periodic air cylinder hydrostatic testing and maintenance records. The inspectors also performed a review of approved replacement parts documentation and certification of the repair personnel.

b. Findings

No findings of significance were identified.

OTHER ACTIVITIES

[OA]

4OA1 Performance Indicator Verification

Main article: IP 71151

a. Inspection Scope

The inspectors reviewed performance indicator data for the cornerstones listed below and used Nuclear Energy Institute 99-02, "Regulatory Assessment Performance Indicator Guideline," Revision 5, to verify individual performance indicator accuracy and completeness. The documents reviewed during this inspection are listed in the Attachment.

Mitigating Systems Cornerstone

Heat Removal Systems (MSPI)

Cooling Water Systems (MSPI)

Occupational Radiation Safety Cornerstone

Occupational Exposure Control Effectiveness Public Radiation Safety Cornerstone

RETS/ODCM Radiological Effluent Occurrences

b. Findings

No findings of significance were identified.

12 Enclosure

4OA2 Identification and Resolution of Problems

Main article: IP 71152

.1 Routine Problem Identification & Resolution Program Review

a. Inspection Scope

As required by Inspection Procedure 71152, "Identification and Resolution of Problems," and to identify repetitive equipment failures or specific human performance issues for follow-up, the inspectors performed a daily screening of all items entered into Entergy's corrective action program. The review was accomplished by accessing Entergy's computerized database for condition reports, and attending condition report screening meetings.

In accordance with the baseline inspection modules, the inspectors selected corrective action program items across the Initiating Events, Mitigating Systems, and Barrier Integrity cornerstones for further follow-up and review. The inspectors assessed Entergy's threshold for problem identification, adequacy of the causal analysis, extent of condition reviews, and operability determinations, and timeliness of the associated corrective actions.

b. Findings

No findings of significance were identified.

.2 Semi-Annual Trend Review

Main article: IP 71152

a. Inspection Scope

The inspectors performed a semi-annual review to identify trends that might indicate the existence of a more significant safety issue. The inspectors included in this review, repetitive or closely-related issues that may have been documented by Entergy outside of the corrective action program, such as trend reports, performance indicators, major equipment problem lists, maintenance rule assessments, and maintenance or corrective action program backlogs. The inspectors reviewed Entergy's corrective action program database for the third and fourth quarters of 2008 to assess the total number and significance of condition reports (CRs) written in various subject areas. The inspectors also reviewed Entergy's corrective action, engineering, and maintenance quarterly trend reports for the second and third quarters of 2008 to ensure Entergy was appropriately evaluating and trending adverse conditions.

The inspectors focused on an adverse trend in through-wall leaks identified in service water piping. The inspectors reviewed CRs, causal evaluations, maintenance plans, business plans, and interviewed station personnel to assess whether Entergy identified the adverse trend and developed appropriate corrective actions to address the conditions.

b. Assessment and Observations No findings of significance were identified.

13 Enclosure Entergy identified three leaks in service water system blowdown piping on August 19, 2008 and determined the leaks were pinhole size that resulted in wetting of the pipe surface. Entergy entered the issue into the CAP and performed an immediate operability assessment that concluded the piping was operable and did not impact the pipe's structural integrity. Entergy performed extent-of-condition walkdowns in the service water intake area and discovered additional leaks on service water system blowdown piping welds. Entergy personnel performed volumetric non-destructive testing of the pipes in accordance with their procedures and determined that these additional leaks were minor localized defects that did not impact structural integrity and, therefore, the service water systems they supported remained operable. Entergy performed the actions described in ASME Code Case N-513-2 for the ASME Class III service water piping and established monitoring frequencies and flaw acceptance criteria. Entergy's short term corrective actions included: performing engineering walkdowns of all stainless steel piping in the service water system, establishing daily walkdowns of identified flaws, and performing volumetric inspection on the identified flaws as required by ASME Code. Entergy identified long term actions that include replacement of the stainless steel service water blowdown piping with a more corrosion-resistant material as Entergy personnel determined that the 304 stainless steel blowdown piping is susceptible to pitting corrosion due to the brackish water of the Hudson River. The replacement is planned to be completed prior to the next refueling outage in the spring of 2010.

Additionally, as part of Entergy's extent-of-condition walkdowns, Entergy identified several leaks on stainless steel service water piping servicing radiation monitors for the containment fan coil units. Similar to the service water blowdown piping, Entergy determined the pinhole leaks were on weld material. However, because the leaks appeared on socket welds and the flaws could not be accurately characterized, ASME Code Case N-513-2 was not applicable and Entergy declared the radiation monitors inoperable and repaired the flaws. Entergy determined that the leaks were caused by pitting corrosion in the 300 series stainless steel pipe welds and the brackish water of the Hudson River. Entergy implemented corrective actions that included immediate repair of all leaking welds and development of an Engineering Change Request package that will replace the radiation monitor piping with a highly corrosion resistant material (AL6XN).

On September 16, 2008, the inspectors identified a small through-wall leak on service water piping supplying cooling water to the containment fan-coil units (FCUs). Specifically, the inspectors identified a pinhole leak that resulted in a wetted pipe surface on a weld neck flange for a 2-inch carbon-steel drain line connected to a 10-inch supply header to the 22 FCU. Entergy performed an operability assessment for the containment penetration and supported the evaluation with confirmatory ultrasonic tests and structural calculations. Entergy determined the cause of this failure was the result of improperly coated weld surfaces internal to the pipe that occurred in 2002. Entergy determined the maintenance procedures, at that time, used to prepare the piping prior to welding did not contain adequate instructions for properly preparing a pipe or weld surface prior to the application of the corrosion resistant coating. Entergy developed procedure 0-SYS-409-GEN, "Belzona and Enecon Metal Repair Applications," in 2005 to improve surface preparation and application techniques. Entergy implemented short term actions to monitor the leakage daily, perform 90-day follow-up ultrasonic testing on the leak location, and perform extent-of-condition walkdowns and UT measurements on the corresponding welds of the 21, 23, 24, and 25 FCUs. Entergy's long term corrective actions includes procedure revisions, repair of the weld during the next refueling outage, 14 Enclosure and plans to visually inspect the welds on the other FCUs during the next refueling outage.

The inspectors determined that there was reasonable opportunity for Entergy to identify and correct the 22 FCU leak prior to NRC identification as required per 10 CFR 50, Appendix B, criterion XVI, "Corrective Action;" however, the inspectors determined, based on subsequent testing of the 22 FCU performed by Entergy, that the operability of the 22 FCU and the corresponding containment penetration was not impacted. Therefore, this violation of 10 CFR 50, Appendix B is considered to be of minor significance and not subject to NRC enforcement.

In general and notwithstanding the NRC inspector-identified minor leak, the inspectors determined that Entergy appropriately identified the adverse trend in service water piping corrosion issues in the corrective action program and documented operability assessments for the service water leaks that were supported by a sufficient technical basis. The inspectors determined that Entergy performed appropriate causal evaluations and implemented extent-of-condition reviews to understand the corrosion mechanisms that existed in service water piping and the extent of the issues. The inspectors also determined that Entergy identified and implemented or planned corrective actions commensurate with the requirements of their corrective action program and the ASME Code. Additionally, the inspectors observed that corrective actions included consideration for the safety significance of the issues.

.3 Aggregate Impact of Operator Workarounds

Main article: IP 71152

a. Inspection Scope

The inspectors conducted a review of the aggregate impact of operator burdens and workarounds. The inspectors reviewed Entergy's implementation of procedures OAP-45, "Operator Burden Program," Revision 1. The inspectors conducted control room walkdowns and interviewed plant operators to determine the impact of deficiencies on operator response to plant events.

b. Findings and Observations

No findings of significance were identified. The inspectors verified that operator workarounds and burdens were entered into the corrective action program at an appropriate threshold and that corrective actions were planned or taken commensurate with their safety significance.

.4 Substantive Cross-Cutting Issue Review: Human Performance - Procedure

Adequacy (71152 - 1 sample)

a. Inspection Scope

The inspectors reviewed Entergy's actions to address the Substantive Cross-Cutting Issue (SCCI) in Human Performance related to procedure adequacy. The inspectors' review focused on Entergy's progress in addressing the SCCI since their implementation of a revised action plan in May 2008. The inspectors evaluated Entergy's performance improvement plans and actions using inspection guidance in Inspection Procedure 71152, "Identification and Resolution of Problems." Specifically, the inspectors 15 Enclosure assessed Entergy's progress in resolving the cross-cutting issue by evaluating whether Entergy's internal milestones were being monitored and consistently met and whether adjustments in approach were made when necessary. This inspection focused on the progress made since the PI&R sample inspection conducted in October 2008 (NRC Inspection Report 05000247/2008013 and 05000286/2008011).

The inspectors conducted a review of the applicable condition reports (CRs), corrective action assignments (CAs), focused self-assessments, Quality Assurance group assessments, and causal evaluations for the substantive cross-cutting issue. The inspectors also reviewed Entergy's performance indicators related to their performance improvement plan; reviewed a sample of revised procedures; conducted a series of interviews with station management, procedure writers and reviewers, maintenance technicians, and operators in order to assess the adequacy of the performance plan and effectiveness of corrective actions.

b. Findings and Observations

No findings of significance were identified.

The inspectors determined that Entergy continued to make progress in effectively implementing their corrective action plans that address the substantive cross-cutting issue in Human Performance related to procedure adequacy.

The inspectors concluded that Entergy's corrective action plans were reasonable in scope because they addressed procedures that contributed to the substantive cross-cutting issue. Entergy's corrective action plans included Operations, Electrical and Mechanical Maintenance, and I&C Maintenance procedures. The procedure upgrade project portion of Entergy's corrective action plans focused on risk significant components and actions in operating procedures. The inspectors determined the procedure upgrade project scope appropriately included operating procedures related to initiating events, single point vulnerabilities, and integrated plant operating procedures. The inspectors observed that station training was developed and provided for the individuals involved in the procedure upgrade project and their management. The inspectors also observed that procedure reviews were being conducted for Security, Chemistry, Radiation Protection, and Engineering procedures to improve the quality of procedures in those areas.

The inspectors confirmed previous NRC observations, through interviews with Entergy staff, that the station has shifted the ownership of this project from the support organizations to the line organization. Entergy personnel indicated this organizational alignment has been a significant factor in the increased acceptance and participation from plant workers, and produced a noticeable improvement in revised procedure quality. The inspectors observed that several personnel interviewed commented that the human performance training simulator is an effective tool, and assisted procedure writers with the identification of human performance error traps in existing procedures.

The inspectors concluded that the realignment of the procedure upgrade project resulted in enhanced project accountability and quality output.

With respect to the progress of the procedure upgrade project, Entergy completed Phase I of the project ahead of their internal schedule and started Phase II. Phase I consisted of operations procedures associated with the top three risk significant systems 16 Enclosure for Units 2 and 3. Phase II of the procedure upgrade project included the remaining top 10 plant risk significant systems, integrated plant operating procedures, procedures which involved single point vulnerabilities and initiating events. Current Entergy plans and progress indicate that the Phase II portion of the procedure upgrade project will be completed by June 2009, several months ahead of the corrective action plan schedule. The inspectors reviewed a sample of the revised Phase I and Phase II procedures and determined that significant revisions were made and the results met the quality and procedure standards described in Entergy's action plan.

The inspectors also observed that the Electrical and Mechanical Maintenance procedure upgrade project and the I&C Maintenance procedure development project made progress that was consistent with internal action plan schedules and milestones. The inspectors determined that the projects continue to receive the appropriate level of resources and management review and support to ensure completion of these projects.

The inspectors determined that human error awareness and prevention actions were being implemented by Entergy to address the human performance aspects that contributed to the substantive cross-cutting issue in procedure adequacy. The inspectors determined that implementation of training, specifically the human performance training simulator, was appropriate to reinforce human error prevention techniques being applied in the plant.

The inspectors concluded Entergy developed appropriate monitoring measures and performance indicators to assess corrective action effectiveness. The inspectors observed that Entergy utilized these tools to provide initial feedback on corrective action implementation. For example, the inspectors determined that the performance indicators, related to procedure completion status and procedure feedback process backlog, were an effective tool for monitoring station progress in these areas.

Additionally, the inspectors concluded that self-assessments were an effective tool for corrective action adjustments and for evaluation of internal and external stakeholder recommendations. Entergy has adjusted the corrective action plan and procedure upgrade project scope to adequately incorporate stakeholder recommendations.

5. Substantive Cross-Cutting Issue Review: Problem Identification and Resolution -

Implementation of Corrective Actions (71152 - 1 sample)

a. Inspection Scope

The inspectors reviewed Entergy's action plan to address the Substantive Cross Cutting Issue (SCCI) identified for Unit 2 in the area of Problem Identification and Resolution related to implementation of effective corrective actions. This SCCI was identified in the NRC's 2008 Annual Assessment letter [ADAMS Ref. No. ML080610015] and was continued in the NRC 2008 Mid Cycle Performance Review [ADAMS Ref. No. ML082470316].

The inspectors conducted a review of the applicable condition reports (CRs), corrective action assignments (CAs), focused self-assessments, Quality Assurance group assessments, root cause analyses, common cause analyses, and apparent cause determinations for the substantive cross-cutting issue. The inspectors also reviewed the CRs and corrective actions associated with the four NCVs which contributed to this cross-cutting issue and reviewed a sample of corrective actions for NRC findings in 2007 17 Enclosure and 2008 to determine if a trend existed. The inspectors reviewed Entergy's performance in order to assess the adequacy of the performance plan and effectiveness of corrective actions.

b. Findings and Observations

There were no findings of significance.

The inspectors determined that Entergy continued to make progress in effectively implementing their corrective action plans, specific to the substantive cross-cutting issue in Problem Identification and Resolution related to implementation of corrective actions at Unit 2.

The inspectors observed progress made in developing and implementing a site-wide action plan to address the issue. The inspectors concluded that the performance improvement plan developed by Entergy was appropriately focused and sufficiently broad to address the cross-cutting aspect of implementation of corrective actions. Additionally, Entergy is approaching their corrective actions from a site-wide perspective (Units 2 and 3) and implemented changes in the processes and level of management review to ensure the issue was appropriately addressed for both units. Specific corrective actions identified by Entergy included the following: administrative procedure revisions to change corrective action tracking; revised procedure requirements for corrective action review board (CARB) review of level 2 and higher tier causal evaluations; revised corrective action requirements for post-closure CARB review of cause evaluations completed over the past year to include verification that that effectiveness reviews were scheduled, completed, and reviewed by CARB for all significant conditions adverse to quality and violations of regulatory requirements. The inspectors observed that these changes were implemented and further observed management review and challenge of several causal evaluations and effectiveness reviews.

Entergy developed performance indicators to track and trend the implementation of the corrective actions. The inspectors reviewed the data from the performance indicators and concluded that the performance indicators were effective and an indication that corrective actions were identifying areas for improvement. The inspectors also determined that Entergy conducted focused self assessments and benchmarking surveys as additional measures to verify planned actions were sufficiently effective.

4OA3 Event Followup

Main article: IP 71153

.1 (Closed) Licensee Event Report (LER) 05000247/2008-002-00, Technical Specification Prohibited Condition Due to Exceeding the Allowed Completion Time for an Inoperable Engineered Safety Feature Actuation System Automatic Actuation Logic and Actuation Relay Caused by Improper Relay Wiring

a. Inspection Scope

On March 28, 2008, Entergy identified an improperly wired safety injection (SI) logic relay during troubleshooting of a high resistance contact in the relay. Specifically, Entergy determined that 23 Containment Fan Cooler Unit (FCU) breaker was not wired to receive a closing signal from the SI relay associated with the electric bus that supplies 18 Enclosure its power. The 23 FCU is powered from bus 2A, and is designed to receive a sequenced start relay during an SI from the 2A bus SI relay. However, in this case, Entergy identified that 23 FCU would have received its start signal from the 5A bus SI relay. Therefore, if bus 5A was de-energized during an SI, 23 FCU would not receive an automatic sequenced start signal as designed. In this scenario, 23 FCU would still be available for manual start by the operators. Entergy determined the incorrect wiring configuration was a result of an improperly implemented design change by the original plant installer in 1973. The incorrect wiring was never detected during subsequent testing because all four safety bus SI relays are tested simultaneously during biannual SI blackout testing.

Entergy entered this issue into their corrective action program, corrected the relay wiring configuration, and performed an extent-of-condition review of other SI relays. No additional instances of incorrect wiring were identified. The inspectors reviewed the LER and verified the corrective actions were adequate. The enforcement aspects of this finding are discussed in section 4OA7. This LER is closed.

4OA5 Other Activities

.1 Implementation of Temporary Instruction (TI) 2515/176 - Emergency Diesel Generator Technical Specification Surveillance Requirements Regarding Endurance and Margin Testing

a. Inspection Scope

The objective of TI 2515/176, "Emergency Diesel Generator Technical Specification Surveillance Requirements Regarding Endurance and Margin Testing," is to gather information to assess the adequacy of nuclear power plant emergency diesel generator endurance and margin testing as prescribed in plant-specific technical specifications (TS). The inspectors reviewed emergency diesel generator ratings, design basis event load calculations, surveillance testing requirements, and emergency diesel generator vendor's specifications and gathered information in accordance with TI 2515/176.

The inspector assessment and information gathered while completing this TI was discussed with licensee personnel. This information was forwarded on to the Office of Nuclear Reactor Regulation for further review and evaluation.

b. Findings

No findings of significance were identified.

.2 TI 2515/173, Review of the Implementation of the Industry Ground Water Protection Voluntary Initiative

a. Inspection Scope

An NRC assessment was performed the week of August 11, 2008 of Entergy's implementation of the Nuclear Energy Institute - Voluntary Ground Water Protection Initiative (dated August 2007, ADAMS Ref. No. ML072610036). Entergy evaluated work practices that could lead to leaks and spills, and performed an evaluation of systems, 19 Enclosure structures, and components that contain licensed radioactive material to determine potential leak or spill mechanisms.

Entergy completed a site characterization of geology and hydrology to determine the predominant ground water gradients and potential pathways for ground water migration from on-site locations to off-site locations. An on-site ground water monitoring program was implemented to monitor for potential licensed radioactive leakage into groundwater. The ground water monitoring results are being reported in the annual effluent and/or environmental monitoring report.

(http://www.nrc.gov/reactors/operating/ops-experience/tritium/plant-info.html) Entergy prepared procedures for the decision making process for potential remediation of leaks and spills, including consideration of the long term decommissioning impacts. Records of leaks and spills are being recorded in Entergy's decommissioning files in accordance with 10 CFR 50.75(g).

Entergy identified appropriate local and state officials and conducted briefings on Entergy's ground water protection initiative. Protocols have been established for notification to these local and state officials regarding detection of leaks and spills.

b. Findings and Observations

No findings of significance were identified.

.3 Ground-Water Contamination Review

a. Inspection Scope

The inspectors reviewed plans, procedures, and remediation activities affecting the contaminated ground water condition at Indian Point, relative to NRC regulatory requirements, as authorized by the NRC Executive Director of Operations in a Reactor Oversight Process deviation memorandum dated December 19, 2007 (ADAMS Accession number ML073480290). The inspectors also reviewed Entergy's performance relative to remediation of the principal source of groundwater contamination including observation of the draining and sludge removal of the Unit 1 spent fuel pools, the radioactive waste processing of the fuel pool water and residual sludge materials, and reviewed the radioactive liquid effluent release accounting and dose calculations resulting from these activities. The inspection included onsite inspections on September 18, 2008; October 10, 2008; October 14-15, 2008; and November 17-18, 2008.

b. Findings and Observations

No findings of significance were identified.

Following the removal of Unit 1 spent fuel to dry cask storage, Entergy established special radioactive liquid processing and sampling equipment for conducting the drain down of the Unit 1 spent fuel pools. Between September 15, 2008 and November 7, 2008, approximately 500,000 gallons of water were drained and processed which included pool surface rinse water used during sludge removal activities. The liquid processing equipment was designed to clarify the pool water prior to discharge into the 20 Enclosure Hudson River. The liquid processing system consisted of a series of sequential processing modules which included a filter cartridge, a 25 ft³ mixed (cation and anion) demineralizer resin vessel followed by five 12.5 ft³ supplemental water polishing units consisting of an activated charcoal vessel, a cation demineralizer resin vessel, a mixed demineralizer resin vessel, a cesium-specific filter media vessel, and finally another activated charcoal vessel. The filtered and demineralized water was sampled by an automatic composite sampler for monitoring and analysis prior to the effluent stream release into the discharge canal. Residual sludge from the bottom of the spent fuel pools was mixed with water and sluiced into a 120 ft 3 polyethylene disposal container. Liquids were removed from this solid waste container by periodically pumping down the container through the self-contained dewatering system contained in the disposal container. These liquid wastes were subsequently processed through the same liquid processing system as described above, however, due to the potentially higher radioactive contaminants, the final processed water was redirected to a Unit 1 waste collection tank to allow for additional waste water treatment prior to discharge. The 120 ft 3 disposal container of solid waste was classified as Class B waste and will be stored onsite until an offsite disposal facility becomes available.

The inspectors determined that treated and discharged water was sampled and properly accounted by Entergy to result in less than 1 Curie of radioactivity discharged consisting mostly of tritium, and small amounts of Kr-85 and Cs-137. The resulting public dose associated from this liquid discharge activity was 0.00007 mrem to the whole body and 0.00012 mrem to the highest organ (teen/liver). The inspectors confirmed these values represented small fractions of the liquid discharge limits of 3 mrem/yr whole body and 10 mrem/yr maximum organ dose limits specified in 10 CFR 50, Appendix I.

4OA6 Meetings

Exit Meeting Summary

On January 9, 2008, the inspectors presented the inspection results to Mr. Joseph Pollock and other Entergy staff members, who acknowledged the inspection results presented. Entergy did not identify any material as proprietary.

4OA7 Licensee-Identified Violations

The following violation of very low safety significance (Green) was identified by Entergy and is a violation of NRC requirements which meets the criteria of Section VI of the NRC Enforcement Policy, NUREG-1600, for being dispositioned as a NCV.

Technical Specification (TS) 3.6.6 requires, in part, a minimum of three trains of containment fan cooler units (FCU) to be operable in mode 1. Contrary to this requirement, the required number of FCUs was not operable in mode 1, assuming a single failure of one emergency diesel generator (EDG) to supply power to the 5A bus during a design basis accident, coincident with a loss of offsite power. Specifically, on March 28, 2008, Entergy identified an incorrect wiring configuration that would have prevented the automatic start of the 23 FCU. This condition, coincident with a single failure of an EDG during a design basis accident, coincident with a loss of offsite power, would have prevented the automatic start of at least three FCUs.

This issue was corrected on March 28, 2008 and entered into Entergy's corrective action 21 Enclosure program as IP2-2008-01482. The finding was more than minor because it was associated with the mitigating systems cornerstone and impacted the objective of ensuring the reliability of systems that respond to initiating events to prevent undesirable consequences. The inspectors determined that this finding was of very low safety significance (Green) based on IMC 0609, Attachment 0609.04, "Phase 1 - Initial Screening and Characterization of Findings," because the finding did not represent an actual loss of safety function of the FCUs for greater than their allowed outage time.

ATTACHMENT:

SUPPLEMENTAL INFORMATION

KEY POINTS OF CONTACT

Entergy Personnel

J. Pollock, Site Vice President

A. Vitale, General Manager, Plant Operations

P. Conroy, Director, Nuclear Safety Assurance

A. Williams, Manager, Operations

J.R. Beckman, Manager, Maintenance

T. Orlando, Manager, Engineering

B. Sullivan, Manager, Emergency Planning

S. Verrochi, Manager, System Engineering

R. Walpole, Manager, Licensing

D. Loope, Manager, Radiation Protection

F. Inzirillo, Manager, Quality Assurance

C. English, Superintendent, Unit 1

S. Sandike, Chemistry and Environmental Specialist

T. Stephens, Energy Solutions

R. Turner, Energy Solutions

R. Christman, Training Manager

J. Whitney, Emergency Diesel Generator System Engineer

LIST OF ITEMS OPENED, CLOSED, AND DISCUSSED

Opened and Closed

None.

Closed

05000247/LER-2008-002-00 LER Technical Specification Prohibited Condition Due to Exceeding the Allowed Completion Time for an Inoperable Engineered Safety Feature Actuation System Automatic

Actuation Logic and Actuation Relay Caused by Improper Relay Wiring (Section 4OA3)

Attachment

LIST OF DOCUMENTS REVIEWED

Indian Point Unit 2 Common Documents

Indian Point Unit 2 Control Room Narrative Logs Control Room Standing Orders Indian Point Unit 2 Updated Final Safety Analysis Report (UFSAR)

Section 1R01: Adverse Weather Protection

Procedures

OAP-048, Seasonal Weather Preparation

OAP-008, Severe Weather Preparations 2-COL-11.5, Space Heating and Winterization 2-COL-30.1, Electric Heat Tracing 2-AOP-FLOOD-1, Flooding

Condition Reports

Miscellaneous

Individual Plant Examination of External Events for Indian Point Unit No. 2

Section 1R04: Equipment Alignment

Procedure

2-COL-27.3.1, Diesel Generators

2-PT-Q028A, "21 Residual Heat Removal Pump," Rev. 18 2-SOP-4.2.1, "Residual Heat Removal System," Rev. 61 2-COL-4.2.1, "Residual Heat Removal System," Rev. 26 2-COL-10.1.1, "Safety Injection System," Rev. 32 2-COL-27.6, "Unit 2 Appendix R Diesel Generator," Rev. 0

Drawings

9321-2735

235296

251783

Miscellaneous

ARDG-003-APP-R, Restoration tagout dated 10/21/08

Section 1R05: Fire Protection

Procedures

2PT-2Y017, Penetration Fire Barrier Seal Inspections 2-PT-EM19, Cable Spreading Room Halon Testing

PT-EM28, Fire Dampers Operability

SAO-703, Fire Protection Impairment Criteria and Surveillance

EN-DC-161, Control of Combustibles

Attachment

Condition Reports

Drawings

400401-04, Fire Area/Zone Arrangement at

EL 15'

400404-02, Fire Area/Zone Arrangement at

EL 80' Orders

IP2-03-31785

IP2-05-21166

51645811

Miscellaneous

Indian Point Nuclear Generating Station, Unit 2, Fire Protection Program Plan, Rev. 9 Indian Point Pre-Fire Plans Unit 2 - Nuclear

IP2-RPT-03-00015, "IP2 Fire Hazards Analysis," Rev. 3

Section 1R11: Licensed Operator Requalification Program

Procedures

EN-TQ-201, Systematic Approach to Training Process, Rev 4

IP-SMM

TQ-114, Continuing Training & Requalification Examinations for Licensed Personnel, Rev 7

OAP-032, Operations Training Program, Rev 9

OAP-033, Conduct of Operations Simulator Training, Evaluations, and Debriefs, Rev 4 2-AOP-FW-1, "Loss of Main Feedwater," Rev. 11

2-AOP-SG-1, "Steam Generator Tube Leak," Rev. 10

Miscellaneous

LRQ Sample Plan for 2007 Comprehensive Written Exam 12SG-LOR-AOP014, Instrument/Controller Failures Lesson Plan, Rev 2 12LP-LOR-AOP009, Containment Integrity, RCS Activity, & Air System Malfunction Lesson Plan, Rev 0

Section 1R12: Maintenance Effectiveness

Procedures

EN-DC-203, Maintenance Rule Program

EN-DC-205, Maintenance Rule Monitoring

EN-DC-324, Preventive Maintenance Process 0-SYS-401-Gen, "Application of Protective Coatings," Rev. 1

Condition Reports

Work Orders

00164495

Miscellaneous

NUMARC 93-01, Industry Guideline for Monitoring the Effectiveness of Maintenance at Nuclear Power Plants Service Water System Health Report, 3Q 2008

Attachment Maintenance Rule Basis Document - Service Water

IP2-UT-08-085, UT erosion/corrosion examination line #1505

IP2-UT-08-086, UT erosion/corrosion examination line #1505

IP2-UT-08-087, UT erosion/corrosion examination line #1509

IP2-UT-08-088, UT erosion/corrosion examination line #1509

IP2-UT-08-089, UT erosion/corrosion examination line #1509

Section 1R13: Maintenance Risk Assessments and Emergent Work Control

Procedures

2-PT-R084C, 23 EDG 8 Hour Load Test

IP-SMM-WM-101, On-Line Risk Assessment

Condition Reports

IP2-2008-04812

Work Orders

51570202

00156016

51570202

00156016

Miscellaneous

TS 3.8.1.10 Note 2 Assessment for U2 EDG 8 Hour Runs in Mode 1 Indian Point Daily Status Reports for October 1, 2, and 3, 2008 EOOS Risk Model Operator's Risk Report for Unit 2 on 10/2 and 10/3, 2008

Week 0840 Unit 2 Operator's Risk Report.

Section 1R15: Operability Evaluations

Procedures

3-PMP-003-CCW, Inspection/Repair of the Component Cooling Pump

Drawings

242688

235306

21-2723

Condition Reports

Work Orders

51668324

00149226

Miscellaneous

Vendor manual - Ingersoll Rand "S" Line General Service Pumps

Section 1R18: Plant Modifications

Procedures

EN-DC-136, Temporary Modifications

Attachment

Condition Reports

IP2-2008-04898

Work Orders

00174868

Drawings

Sketch "A"

TM-12305

Miscellaneous

Indian Point Unit 2 Maintenance Rule Document - 138 kVAC Electrical System Vendor manual - 1380-SF-10000 series electrical breaker TMOD No:

EC 12305, Install Nitrogen connection at

BT4-5 air compressor tank.

Section 1R19: Post-Maintenance Testing

Procedures

2-BRK-021-CUB, Westinghouse 480V DB Series Breaker Cubicle Inspection and Cleaning

0-HTX-405-EDG, EDG Lube Oil and Jacket Water Heat Exchanger Maintenance 2-IC-PC-I-P-1139, "Auxiliary Boiler Feed Pump No.22 Steam Supply Controller," Rev. 0

OAP-24, "Operations Testing," Rev. 3

PFM-44, "Generic Inservice Pressure Test Program," Rev. 3 2-BRK-001-ELC, "ITE Type KC, Model G-Air Circuit Breaker," Rev. 0

Condition Reports

IP2-2008-05089

Work Orders

270253

51670696

51606970

00137722

00173188

51644972

51655457

51315478

51672218

Drawings

226033

251231

251232 9321-2017 9321-2125

208088

244016

Miscellaneous

Conoflow Regulators and Controls Instruction and Maintenance Manual, GP50 series

Section 1R22: Surveillance Testing

Procedures

2-PT-Q035B, 22 Containment Spray Pump Test 2-PC-2Y55, Containment Sump Discrete Level Instrumentation 2-ES-1.3, Transfer to Cold Leg Recirculation 2-E-1, Loss of Reactor or Secondary Coolant

2-NF-309, RCS Delta-T, T-Avg and Flow Measurement 2-PT-V59, "Reactor Trip Breaker "A" Changeout and Functional Test," Rev. 4 2-PC-4Y74C, "Nuclear Instruments Power Range N-43," Rev. 1

PT-Q13, "Inservice Valve Tests", Data Sheet 38 - valve 869B, Rev. 21

Attachment

Condition Reports

IP2-2008-04852

IP2-2008-04380

IP2-2008-04450

Orders

51570801

00164350

51298850

Miscellaneous

EC 3714, Replacement of

LT-3300 and

LT-3301 and Addition of PICS input from

LT-939 and

LT-941

IP2-RHR/SIS DBD, Residual Heat Removal and Safety Injection Design Basis Document

Section 1EP2: Alert and Notification System (ANS) Evaluation

Procedures

Command and Control Alert Notification Testing, October 22, 2008

Section 2OS3: Access Control to Radiologically Significant Areas

Procedures

EN-CY-108, Rev. 2, Monitoring of Non-Radioactive Systems

EN-RP-113, Rev. 2, Response to Contaminated Spills / Leaks

EN-RP-303, Rev. 2, Source Check Radiation Protection Instrumentation

EN-RP-306, Rev. 2, Calibration and Operation of the Eberline

PM-7

EN-RP-309, Rev. 1, Operation and Calibration of the Eberline

AMS-3 / 3A Continuous Air

Monitor

EN-RP-501, Rev. 3, Respiratory Protection Program

EN-RP-502, Rev. 4, Inspection and Maintenance of Respiratory Protection Equipment

IP-EP-AD6-20, Rev. 2, Respiratory Protection Monthly Equipment Inventory

IP-EP-AD6-21, Rev. 3, Respiratory Protection Quarterly Equipment Inventory

IP-RP-IC-301, Rev. 1, Calibration of the Eberline

AMS-4 Air Monitoring System Using Windows

IP-SMM-CY-001, Rev. 6, Radioactive Effluents Control Program

RE-ADM-1-22, Rev. 0, Site Soil Characterization

RE-INS-7CC-1, Rev. 12, Calibration of the Eberline

AMS-2 Beta-Gamma Air Monitor

RE-INS-7CC-7/8, Eberline

PING-1A Calibration Record

RE-INS-7CH-3, Rev. 10, Calibration of the Merlin-Gerin

CDM-21 Electronic Dosimeter

Calibrator Using WCDM 2000

RE-INS-7CH-4, Rev. 5, Characterization of the J.L. Shepherd 81-12, 142-10 and 149 Sources

RE-INS-7UH-12, Rev. 10, Beam Source Check Sheet 0-RP-IC-101, Rev. 2, Calibration of Portable Ion Chamber Survey Meters 0-RP-IC-102, Rev. 0, Calibration of the Eberline

ASP-1 with Neutron Detector 0-RP-IC-301, Rev. 1, Calibration of the Eberline

AMS-4 Air Monitoring System Using Windows 0-RP-IC-402, Rev. 1, Calibration and use of the MGP Telepole 0-RP-IC-601, Rev. 0, Calibration of the Tennelec

LB-5100 Alpha-Beta Counting System Using

Eclipse 0-RP-IC-603, Rev. 0, Interchangeable Counting Room Calibration with

HP-300 0-RP-IC-604, Rev. 0, Calibration of the Eberline Model

BC-4 Beta Counter

0-CY-1420, Rev. 2, Radiological Quality Assurance Program 0-CY-1510, Rev. 4, IPEC Storm Drain Sampling 0-CY-1900, Rev. 0, Nuclear Environmental Monitoring Sampling and Analysis Schedule 0-CY-2740, Rev. 1, Liquid Radioactive Effluents Attachment

2-PC-R25, Rev. 15, Main Steam Line Radiation Monitor Detector Calibration (R-28, 29, 30, 31) 2-PC-R38-1, Rev. 3, High Range Containment Area Radiation Monitor (R-25) 2-PC-R38-2, Rev. 2, High Range Containment Area Radiation Monitor (R-25) 2-PC-R38-3, Rev. 3, High Range Containment Area Radiation Monitor (R-26) 2-PC-R38-4, Rev. 2, High Range Containment Area Radiation Monitor (R-26) 2-PC-R15B, Rev. 17, VC Area Radiation Monitor Calibration (R-7)

2-PC-EM4, Rev. 12, Non-VC Area Radiation Monitors Calibration 2-PC-EM30, Rev. 10, Process Radiation Monitor Calibration (R-41, 42) 2-PC-2Y23, Rev. 10, Liquid Radiation Monitor Calibration 3-CY-2325, Rev. 6, Radioactive Sampling Schedule 3-IC-RMP-R-7, Rev. 0, Calibration of Radiation Monitor R-7

3-PC-R40, Rev. 17, Main Steam Line Radiation Monitor Calibration (R-62) 3-PC-OL-48, Rev. 4, Fuel Storage Building Radiation Monitor Calibration (R-5) 3-PC-R46A, Rev. 15, Containment High Range Radiation Monitor Calibration (R-25) 3-PC-R46B, Rev. 14, Containment High Range Radiation Monitor Calibration (R-26) 3-PC-OL-58A, Rev. 2, Process Radiation monitors R11/12 Calibration 3-PC-OL-49A, Rev. 2, Steam Generator Blow down Radiation Monitor Calibration (R-19)

Condition Reports

Miscellaneous

LCOTR # 2-TS-08-0923 IPEC Radiation Monitoring System Top Ten Technical Issues Action Plan, updated 12/17/08

IPEC Radiation Monitoring System Long Range Plan Plan, updated 12/17/08 IPEC Radiation Monitoring System Condition Report Trend Review, updated 12/17/08 RMS Maintenance Improvement Plan, updated 12/17/08 Units 2 and 3 System Health Report for 2008 ER No. 04-2-042, R-41 / 42 Reliability Improvements Engineering Review package Radiation Monitor, Portable Radiation Monitoring Instrumentation, and Calibrator Calibration

Sheets C.A.R.E Authorized Repair Center Certifications DUKE / NUPIS Member Audit Report of General Engineering Laboratories, LLC (GEL) IPEC: Nuclear Energy Institute Groundwater Protection Initiative Self Assessment Checklist, dated July 2008.

Section 4OA1: Performance Indicator Verification

Procedures

EN-EP-201, "Performance Indicators," Rev. 6

EN-LI-114, "Performance Indicator Process," Rev. 3

NEI 99-02, "Regulatory Assessment Performance Indicator Guideline," Rev. 5

Attachment

Section 4OA2: Identification and Resolution of Problems

Procedures

EN-LI-102, Corrective Action Process

EN-LI-119, Apparent Cause Evaluation (ACE) Process

SOP-27.3.1.1, 21 Emergency Diesel Generator Manual Operation

ICPM-0708-1, 13.8 KV L&P bus section 3 partial differential relays (87B2-A/B/C)

3-REF-003-Gen, Reactor Core Refueling

SOV-003-ELC, Inspection and Testing of Target Rock Solenoid Operated Valves

EN-LI-122, Common Cause Evaluation

EN-LI-119, Apparent Cause Evaluation (ACE) Process

EN-LI-102, Corrective Action Process

EN-OP-117, Operations Assessments

3-SOP-NI-001, Excore Nuclear Instrumentation System Operation 2-SOP-ESP-001, Local Equipment Operation and Contingency Actions 3-PT-M079C, 33 EDG Functional Test 2-E-0, "Reactor Trip or Safety Injection," Rev. 0

EN-DC-185, Through-Wall Leaks in ASME Section XI Class 3 Moderate Energy Piping

Condition Reports

IP3-2008-00640 IP3 2008-01285

IP3-2008-01745

IP3-2008-02137

IP3-2008-03013 IP3LO-2008-00004 IP3LO-2008-00111 IP3LO-2008-00143 IP3LO-2008-00172 IP3LO-2008-00178 IP3LO-2008-00179 IP3LO-2008-00180

HQN-2008-00339

LO-WTIPC-2008-00043

Work Orders

00145055

51320416

00174762

51247771

00170717

Miscellaneous

IPEC Engineering Department Quarterly Trend Report 2Q 2008

IPEC Engineering Department Quarterly Trend Report 3Q 2008 IPEC Maintenance Department Quarterly Trend Report 2Q 2008 IPEC Maintenance Department Quarterly Trend Report 3Q 2008 IPEC Corrective Action and Assessment Department Quarterly Trend Report 3Q 2008 NRC

IR 05000247/2008001 & 05000286/2008001 "Annual Assessment Letter - Indian Point Nuclear Generating Units 2 and 3" Dated March 3, 2008 NRC "Mid Cycle Performance Review and Inspection Plan - Indian Point Nuclear Generating Station Units 2 and 3" dated September 2, 2008. NRC Inspection Report 05000247/2008010 "Indian Point Nuclear Generating Station Unit 2- NRC Problem Identification and Resolution Inspection Report" dated July 24, 2008 10

CFR 50.72 ,"Immediate Notification requirements for Operating Nuclear Power Reactors"

Indian Point Energy Center Procedure Adequacy Cross-Cutting Issue Resolution Plan Rev 4 Dated September 9, 2008

Attachment Indian Point Energy Center Procedure Adequacy Cross-Cutting Issue Resolution Plan Revs 0-3 Maintenance Department Procedure Improvement Plan (No date) Human Performance Training Plan and slides "Doer, Reader, Peer Checker, and Pilot" exercise. Human Performance Training Plan and slides "Human Performance for IPEC Personnel" Operations Procedure Upgrade Project Communications plan for Operations personnel. Procedure Adequacy Cross-Cutting Resolution Plan Slideshow dated 10/20/08

Procedure

Adequacy Cross-Cutting Resolution Plan Slideshow update dated 12/5/08 Plant Operating Procedures (POP) Procedure Upgrade Project Plan dated 9/9/08 Plant Operating Procedures (POP) Procedure Upgrade Project Plan Rev 2 dated 10/26/08 Performance Indicators and worksheets for Procedure Workdown Curves, Procedure Feedback Forms, NRC Findings, Equipment Reliability, and Preventive Maintenance Completion.

Indian Point Units 2 and 3 Summary of Findings/ Violations Report dated 12/1/08 Equipment Reliablility Index Performance Indicator Guidance Book Revision 4 and Data CAP Improvement Plan-IPEC Unit 2 Cross Cutting Issue PI&R slide show dated 12/1/08 Human Performance Cross Cutting Resolution Plan Presentation dated 12/2/08 IPEC Open CR Inventory Report run 12/1/08 IPEC CRG Summary Agenda Report for 12/2/08 IPEC CARB Meeting Agenda Report for 12/2/08

ASME Code Case N-513-2, Evaluation Criteria for Temporary Acceptance of Flaws in Moderate Energy Class 2 or 3 Piping Section XI, Division 1

Section 4OA3: Event Followup

Condition Report

IP2-2008-01482

IP2-2008-01537

Work Orders

00145619

Section 4OA5: Other Activities

Completed Surveillance Procedures

2-PT-M021A, Rev. 17, Emergency Diesel Generator 21 Load Test, completed July 14, August 14, and September 8, 2008 2-PT-M021B, Rev. 17, Emergency Diesel Generator 22 Load Test, completed July 17, August 12, and September 10, 2008 2-PT-M021C, Rev. 15, Emergency Diesel Generator 23 Load Test, Completed July 16, August 12, and September 11, 2008 3-PT-M079A, Rev. 36, 31 EDG Functional Test, completed July 8, August 6, and September 4, 2008 3-PT-M079B, Rev. 37, 32 EDG Functional Test, completed July 9, August 6, and September2, 2008 3-PT-M079C, Rev. 36, 33 EDG Functional Test, completed July 11, August 8, and September 3, 2008

Procedures

2-PT-R084A, Rev. 13, 21 EDG 8 Hour Load Test 3-PT-R160A, Rev. 11, 31 EDG Capacity Test

Miscellaneous

EnergySolutions Procedure

FP-FO-WI-001, Rev. 0, Spent Fuel Pool Cleaning at Indian Point Attachment Unit 1 Entergy Procedure 1-RP-RWM-913, Rev. 1, Unit 1 Fuel Handling Building West Pool 24/7 Demineralizer System Entergy Work Order

00123484 10, Modifications to the FHB West Pool Demineralization System

FEX-00039-02, Emergency Diesel Generator Loading Study

IP3-CALC-ED-00207, Rev. 7, 480 V Bus 2A, 3A, 5A, & 6A and EDGs 31, 32 & 33 Accident Loading Indian Point Nuclear Generating Unit No. 2 Updated Final Safety Analysis Report, Chapter 8, Rev. 20 Indian Point Nuclear Generating Unit No. 3, Updated Final Safety Analysis report, Chapter 8, Rev. 02, 2007 Emergency Diesel Generator Design Basis Document for Indian Point Unit 2, Rev. 1 Entergy Letter

NL-07-038, dated March 22, 2007, Proposed changes to Indian Point 2 Technical Specifications Regarding Diesel Generator Endurance Test Surveillance

Entergy Letter

NL-08-139, dated September 29, 2008, Reply to Request for Additional Information Regarding Indian Point Unit 2 Proposed Changes to Technical Specifications Regarding Diesel Generator Endurance Test Surveillance (TAC No.

MD9214) Entergy Letter

NL-08-157, dated October 8, 2008, Supplement to Reply to Request for Additional Information Regarding Indian Point Unit 2 Proposed Changes to Technical Specifications Regarding Diesel Generator Endurance Test Surveillance (TAC No. 9214) Entergy Letter

NL-08-160, dated October 13, 2008, Proposed Exigent License Amendment to Revise Technical Specification Surveillance Requirement 3.8.1.10 Frequency Regarding Diesel Generator Endurance Test NRC Letter dated October 20, 2008, Indian Point Nuclear Generating Unit No. 2 - Issuance of Exigent Amendment Re: Surveillance Interval for Diesel Generator Endurance Test (TAC No. MD9845)

MI-11272C, Engine Maintenance Schedule, Nuclear Standby Engines developed by ALCO Owner's Group and FM/ALCO Indian Point Nuclear Generating Unit No. 2 Technical Specifications, Section 3.8, Electrical Power Systems, through Amendment 255 Indian Point Nuclear Generating Unit No. 2 Technical Specifications Bases, Section 3.8, Electrical Power Systems, Rev. 2 Indian Point Nuclear Generating Unit No. 3 Technical Specifications, Section 3.8, Electrical Power Systems, through Amendment 226 Indian Point Nuclear Generating Unit No. 3 Technical Specifications Bases, Section 3.8, Electrical Power Systems, Rev. 3

Attachment