ML062650059

2006/09/21-IR 05000219-06-007; Amergen Energy Company; 03/13-17/2006 03/27-31/2006; Oyster Creek Generating Station; Inspection of the Scoping of Non-Safety Systems and the Proposed Aging Management Procedures for Application for Renewed Li

ML062650059
Person / Time
Site:	Oyster Creek
Issue date:	09/21/2006
From:	Jackson D E Engineering Region 1 Branch 1
To:	Crane C M AmerGen Energy Co
Jackson D E
References
%dam200612 IR-06-007
Download: ML062650059 (46)

See also: IR 05000219/2006007

Text

September 21, 2006Mr. Christopher M. CranePresident and CEO

AmerGen Energy Company, LLC

200 Exelon Way, KSA 3-E

Kennett Square, PA 19348SUBJECT:OYSTER CREEK GENERATING STATION - NRC LICENSE RENEWALINSPECTION REPORT 05000219/2006007Dear Mr. Crane:

On March 31, 2006, the NRC completed the onsite portion of the inspection of your applicationfor license renewal of your Oyster Creek Generating Station. The inspection continued in ourRegion I office until early September 2006. The enclosed report documents the results of the

inspection, which were discussed on September 13, 2006, with members of your staff in an exit

meeting open for public observation at the Lacey Township Town Hall. The purpose of this inspection was to examine the plant activities and documents thatsupported the application for a renewed license of Oyster Creek Generating Station. Theinspection reviewed the screening and scoping of non-safety related systems, structures, andcomponents, as required in 10 CFR 54.4(a)(2), and determined whether the proposed aging

management programs are capable of reasonably managing the effects of aging. These NRC

inspection activities constitute one of several inputs into the NRC review process for licenserenewal applications.The inspection team concluded screening and scoping of non-safety related systems,structures, and components, was implemented as required in 10 CFR 54.4(a)(2), and the aging

management portion of the license renewal activities were conducted as described in the

License Renewal Application. The inspection results support a conclusion that the proposed

activities will reasonably manage the effects of aging in the systems, structures, andcomponents identified in your application. The inspection concluded the documentationsupporting the application was in an auditable and retrievable form.In accordance with 10 CFR 2.390 of the NRC's "Rules of Practice," a copy of this letter and itsenclosure will be available electronically for public inspection in the NRC Public DocumentRoom or from the Publicly Available Records (PARS) component of NRC's document 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/

Donald E. Jackson, Acting ChiefEngineering Branch 1

Division of Reactor SafetyDocket No.50-219License No.DPR-16

C. Crane2Enclosure: Inspection Report 05000219/2006007cc w/encl:Chief Operating Officer, AmerGenSite Vice President, Oyster Creek Nuclear Generating Station, AmerGen

Plant Manager, Oyster Creek Generating Station, AmerGen

Regulatory Assurance Manager, Oyster Creek, AmerGen

Senior Vice President - Nuclear Services, AmerGen

Vice President - Mid-Atlantic Operations, AmerGen

Vice President - Operations Support, AmerGen

Vice President - Licensing and Regulatory Affairs, AmerGen

Director Licensing, AmerGen

Manager Licensing - Oyster Creek, AmerGen

Vice President, General Counsel and Secretary, AmerGen

T. O'Neill, Associate General Counsel, Exelon Generation CompanyJ. Fewell, Assistant General Counsel, Exelon Nuclear

Correspondence Control Desk, AmerGen

J. Matthews, Esquire, Morgan, Lewis & Bockius LLP

Mayor of Lacey Township

K. Tosch, Chief, Bureau of Nuclear Engineering, NJ Dept of Environmental Protection

R. Shadis, New England Coalition Staff

N. Cohen, Coordinator - Unplug Salem Campaign

W. Costanzo, Technical Advisor - Jersey Shore Nuclear Watch

E. Gbur, Chairwoman - Jersey Shore Nuclear Watch

E. Zobian, Coordinator - Jersey Shore Anti Nuclear Alliance

P. Baldauf, Assistant Director, Radiation Protection and Release Prevention, State of New Jersey

R. Webster, Rutgers Environmental Law Clinic

C. Crane3Distribution w/encl:

(VIA E-MAIL)S. Collins, RAM. Dapas, DRA

R. Bellamy, DRP

M. Ferdas, DRP, Senior Resident Inspector

R. Treadway, DRP, Resident Inspector

J. DeVries, DRP, Resident OA

B. Sosa, RI OEDO

D. Roberts, NRR

E. Miller PM, NRR

T. Valentine, Backup PM (Interim), NRR

D. Ashley, NRR

ROPreports@nrc.gov

Region I Docket Room (with concurrences)

A. Blough, DRS

M. Gamberoni, DRS

D. Jackson, DRS

M. Modes, DRS

M. Young, OGCSUNSI Review Complete: DEJ (Reviewer's Initials

)DOCUMENT NAME: E:\Filenet\ML062650059.wpdAfter 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 copyOFFICERI/DRSRI/DRPRI/DRSNAMEMModes * (MM)RBellamy * (RB)DJackson (DJ)DATE09/19/0609/21/0609/19/06OFFICENAMEDATEOFFICIAL RECORD COPY

EnclosureU. S. NUCLEAR REGULATORY COMMISSIONREGION IDocket No:50-219

License No:DPR-16

Report No:05000219/20006007

Licensee:AmerGen Energy Company, LLC

Facility:Oyster Creek Generating StationLocation:Forked River, New Jersey

Dates:March 13 - 17, 2006 and March 27 - 31, 2006

Inspectors:M. Modes, Team Leader, Division of Reactor Safety (DRS)P. Kaufman, Sr. Reactor Inspector, DRS

G. Meyer, Sr. Reactor Inspector, DRS

S. Chaudhary, Health Physicist, Division of Nuclear Materials Safety(DNMS)T. O'Hara, Reactor Inspector, DRS

J. Lilliendahl, Reactor Inspector, DRSD. Johnson, Reactor Inspector, DRS

D. Werkheiser, Resident Inspector, Division of Reactor Projects (DRP)Approved By:Donald E. Jackson, Acting ChiefEngineering Branch 1

Division of Reactor Safety

iiEnclosureSUMMARY OF FINDINGSIR 05000219/2006007; 03/13/2006 - 03/17/2006, 03/27/2006 - 03/31/2006, Oyster CreekGenerating Station; Inspection of the Scoping of Non-Safety Systems and the Proposed AgingManagement Procedures for the Oyster Creek Generating Station Application for RenewedLicense.This inspection of license renewal activities was performed by eight regional office engineeringinspectors. The inspection was conducted in accordance with NRC Manual Chapter 2516 andNRC Inspection Procedure 71002. This inspection did not identify any "findings" as defined inNRC Manual Chapter 0612. The inspection team concluded screening and scoping of non-safety related systems, structures, and components, were implemented as required in 10 CFR54.4(a)(2), and the aging management portions of the license renewal activities were conducted

as described in the License Renewal Application. The inspection results support a conclusion

that the proposed activities will reasonably manage the effects of aging in the systems,structures, and components identified in your application. The inspection concluded the

documentation supporting the application was in an auditable and retrievable form.

iiiEnclosureTABLE OF CONTENTS

PageSUMMARY OF FINDINGS....................................................ii

4.OTHER ACTIVITIES (OA)...............................................14OA2Other - License Renewal

..........................................1a.Inspection Scope..........................................1

a.1. Scoping of Non Safety-Related Systems, Structures, andComponents

.............................................1a.2. Programs................................................2One-Time Inspection Program................................2

Bolting Integrity...........................................3

Buried Piping Inspection....................................3

Flow-Accelerated Corrosion Program..........................4

Water Chemistry Program...................................4

Closed-Cycle Cooling Water Systems Program...................5

10 CFR Part 50, Appendix J Program

..........................5Fuel Oil Chemistry Program..................................6

Boiling Water Reactor Feedwater Nozzle Program

................6Boiling Water Reactor Stress Corrosion Cracking Program..........7

Periodic Inspection Program.................................8

Wooden Utility Pole Program

.................................9Periodic Testing of Containment Spray Nozzles.................10

Inaccessible Medium-Voltage Cables Not Subject to 10 CFR 50.49Environmental Qualification Requirements................10Electrical Cables and Connections Not Subject to 10 CFR 50.49Environmental Qualification Requirements................11Electrical Cables and Connections Not Subject to 10 CFR 50.49Environmental Qualification Requirements Used in Instrument

Circuits...........................................12Fire Protection Program....................................12

Fire Water System Program.................................13

Periodic Inspection of Ventilation Systems Program..............14

Periodic Inspection - Forked River Combustion Turbine...........14

ASME,Section XI, Subsection IWE Program....................16

Protective Coating Monitoring and Maintenance Program..........16Above-Ground Outdoor Tank Monitoring Program................17ASME Section XI, Subsection IWF...........................17

Masonry Wall Program.....................................18

Structures Monitoring Program...............................19

Inspection of Water Control Structures........................20

Metal Fatigue of Reactor Coolant Pressure Boundary.............21Isolation Condenser System Review..........................21b.Observation.............................................23

c.Overall Findings..........................................2440A6 Meetings, Including Exit..........................................24

ivEnclosureTABLE OF CONTENTS (Cont'd)SUPPLEMENTAL INFORMATION............................................A-1KEY POINTS OF CONTACT...........................................A-1

LIST OF DOCUMENTS REVIEWED.....................................A-2

LIST OF ACRONYMS...............................................A-15

EnclosureReport Details4.OTHER ACTIVITIES (OA)4OA2Other - License Renewal a.Inspection ScopeThis inspection was conducted by NRC Region I and headquarters based inspectors inorder to evaluate the thoroughness and accuracy of the screening and scoping of non-

safety related systems, structures, and components, as required in 10 CFR 54.4(a)(2)and to evaluate whether aging management programs will be capable of managing theidentified aging effect in a appropriate manner.The inspection team selected a number of systems for review, using the NRC acceptedguidance, in order to determine if the methodology applied by the applicant appropriately

captured the non-safety systems affecting the safety functions of a system, component,or structure within the scope of license renewal.The inspection team selected a sample of aging management programs to verify theadequacy of the applicant's documentation and implementation activities. The selected

aging management programs were reviewed to determine whether the proposed aging

management implementing process would adequately manage the effects of aging on

the system.The inspectors reviewed supporting documentation and interviewed applicant personnelto confirm the accuracy of the license renewal application conclusions. For a sample of

plant systems and structures, inspectors performed visual examinations of accessibleportions of the systems to observe aging effects. a.1. Scoping of Non Safety-Related Systems, Structures, and ComponentsTo assess the thoroughness and accuracy of the methods

used to bring systems,structures, and components within scope of the application and to screen non-safety

related systems, structures, and components, as required in 10 CFR 54.4(a)(2), theinspectors reviewed the applicant's program guidance procedures and summaries of

results for Oyster Creek. The inspectors determined the applicant's procedures to be

consistent with the NRC accepted guidance in Sections 3, 4, and 5 of Appendix F toNEI 95-10, Revision 5 (3: non-safety related systems, structures, and componentswithin scope of the current licensing basis, 4: non-safety related systems, structures,and components directly connected to safety-related systems, structures, andcomponents, and 5: non-safety related systems, structures, and components not directlyconnected to safety-related systems, structures, and components). Also, the inspectorsdetermined that the applicant appropriately utilized the guidance in their process fordetermining which systems were within scope.

2EnclosureThe applicant based the scoping and screening results on a technical review andwalkdown of all applicable plant areas by qualified plant personnel. The inspectors

reviewed the set of license renewal drawings, which were color-coded based on the

results. The inspectors interviewed personnel and independently inspected numerous

areas within the plant to confirm that appropriate systems, structures, and componentshad been included within the license renewal scope, that systems, structures, andcomponents excluded from the license renewal scope had an acceptable basis, and that

the boundary for determining scope within the systems, including anchors, wasappropriate. For systems, structures, and components selected from the results, theinspectors confirmed that the in-plant configuration was accurate and acceptably

categorized, and for systems, structures, and components selected within the plant, theinspectors confirmed that the categorization result in program documents was

appropriate. The in-plant areas and systems reviewed included the following:*Reactor Building;*Turbine Building;

• Intake Structure;

• Ventilation Stack;

• Diesel Generator Building;

• Diesel Fuel Oil Building;

• Fire Protection System;

• Isolation Condenser System;

• Hardened Vent System;

• Nitrogen Supply System;

• Instrument Air System; and

• Service Water System.The inspectors determined the personnel involved in the process were knowledgeableand appropriately trained, and that the applicant had implemented an acceptablemethod of scoping and screening of non-safety related systems, structures, andcomponents. a.2. ProgramsOne-Time Inspection ProgramThe One-Time Inspection Program is a new aging management program intended toverify the effectiveness of other aging management programs, including Water

Chemistry, Closed Cycle Cooling Water Systems, and Fuel Oil Chemistry Programs, by

reviewing various aging effects for impact. Where corrosion resistant materials and/or

non-corrosive environments exist, the One-Time Inspection Program is intended to

verify that an aging management program is not needed during extended operations byconfirming that aging effects are not occurring or are occurring in a manner that does

not affect the safety function of systems, structures, and components within the scopeof the application. Non-destructive evaluation will be performed by qualified personnelusing procedures and processes consistent with the American Society of Mechanical

Engineers Boiler and Pressure Vessel Code (ASME) and 10 CFR 50, Appendix B. The

3EnclosureOne-Time Inspection Program will be implemented prior to the period of ext

endedoperation. The inspectors reviewed the program description, implementation plan, and inspectionsample basis, and discussed the planned activities with the responsible staff.For the One-Time Inspection Program, the inspectors concluded the applicantperformed adequate evaluations and reviews of industry experience and plant history to

determine an acceptable approach to identifying, assessing and managing any aging

effects detected. The applicant developed adequate guidance for implementation ofthe One-Time Inspection Program. Bolting IntegrityThe Bolting Integrity Program is an existing program credited with managing the loss ofmaterial, cracking, and loss of prestress aging effects in safety-related bolting at Oyster

Creek. The aging effects are managed by visual inspection for leakage during systempressure tests, normal plant operation, and periodic system maintenance, and repairedin accordance with maintenance procedures and the ASME Code.The inspectors reviewed the program basis document, implementing procedures,documented reviews, and a bolting-related apparent cause evaluation, and interviewed

the responsible plant personnel regarding these documents. In addition, the inspectors

walked down portions of the Standby Liquid Control, Isolation Condenser, Control Rod

Drive, and Reactor Building Closed Cooling Water Systems to confirm that the program

had maintained acceptable bolting conditions. For the Bolting Integrity Program, the inspectors concluded that the applicant hadperformed adequate evaluations as well as industry experience and historical reviews to

determine the aging effects are managed by the Bolting Integrity Program. The

applicant provided adequate guidance to ensure the aging effects are appropriately

managed. Buried Piping InspectionThe Buried Piping Inspection Program is an existing program credited with managingthe loss of material aging effects on the external surfaces of piping in a soil

environment, including the service water, emergency service water, and condensate

transfer systems. The aging effects are managed by preventive measures, i.e.,coatings, wrapping, and condition monitoring measures, including visual inspections and

periodic system pressure testing. As described in Appendix B, Part 1.26 of theapplication, the applicant plans to enhance the program by augmenting the visualinspections prior to extended operations and performing periodic visual inspections, and

to include additional piping, such as the fire protection system.

4EnclosureThe inspectors reviewed the program basis document, system drawings, implementingprocedures, and documented reviews, and interviewed the responsible plant personnel

regarding these documents. Also, the inspectors walked down the service water and

emergency service water systems in the vicinity of buried piping.For the Buried Piping Inspection Program, the inspectors concluded that the applicanthad performed adequate evaluations as well as industry experience and historical

reviews to determine the aging effects managed by the Buried Piping Inspection

Program. The applicant provided adequate guidance to ensure the aging effects are

appropriately managed. Flow-Accelerated Corrosion ProgramThe Flow-Accelerated Corrosion Program is an existing program credited with managingthe corrosion aging effects in all carbon steel piping and components containing high-

energy fluids at Oyster Creek Generating Station. The aging effects are managed byusing ultrasonic and radiographic testing to detect wall thinning and by predicting wear

rates to support the proactive replacement of system piping. In addition, the programprovides for the performance of follow-up inspections to confirm predictions and to

determine the need for repairs or replacements as necessary.The inspectors reviewed the piping ultrasonic testing wall thickness results fromprevious inspections and reviewed the CHECWORKS computer analysis of the future

wall thickness forecasts. The inspector also reviewed recent changes to the

CHECWORKS model to ensure previously identified deficiencies have been corrected.

The inspectors noted that recent replacements, initiated as a result of this program,

were implemented preventively due to identified flow-accelerated corrosion. The

replacement piping material was more resistant to corrosion than the original piping

material.For the Flow-Accelerated Corrosion Program, the inspectors concluded the applicantconducted adequate evaluations as well as industry experience and historical reviews

and, as a consequence, the effects of aging will be reasonably managed by theproposed program. Water Chemistry ProgramThe Water Chemistry Program is an existing program credited with managing theeffects of aging on piping, piping components, piping elements, and systems, such asthe condensate and feedwater, and condensate storage tank in Oyster CreekGenerating Station. The aging effects are managed by monitoring and control ofreactor water chemistry to minimize contaminant concentration and mitigate loss of

material due to general, crevice and pitting corrosion and cracking caused by stress

corrosion cracking.

5EnclosureWater chemistry control is administered in accordance with the Boiling Water ReactorVessel and Internals Project guideline BWRVIP-29 and Electric Power Research

Institute guideline EPRI TR-103515. The inspectors reviewed the chemistry procedures

and sampling results to confirm that the guidance contained in BWRVIP-29 and EPRI

TR-103515 was being implemented.For the Water Chemistry Program, the inspectors concluded the applicant hadconducted adequate evaluations as well as industry experience and historical reviews to

determine aging effects managed by an aging management program. The applicant

provided adequate guidance to ensure aging effects are appropriately managed. Closed-Cycle Cooling Water Systems ProgramThe Closed-Cycle Cooling Water Systems Program is an existing program credited withmanaging loss of material, cracking, and buildup-of-deposit aging effects in components

exposed to closed-cycle cooling water environments at the Oyster Creek GeneratingStation. Systems within the scope of the closed-cycle cooling water program include theturbine building closed cooling, reactor building closed cooling, and emergency diesel

generator closed cooling water systems. The aging effects are managed by monitoringand control of cooling water chemistry, performing surveillance tests, and throughperiodic inspection of system components in a manner consistent with EPRI TR-107396guidelines.The inspectors observed cleaning of the turbine closed-cooling water heat exchangerand performed a walkdown of

the system with plant personnel. In addition, theinspectors reviewed closed-cycle cooling water chemistry procedures and reviewed pastchemistry sample results to confirm that the requirements of EPRI TR-107396 are being

met.For the Closed-Cycle Cooling Water Systems Program, the inspectors concluded theapplicant had conducted adequate evaluations as well as industry experience and

historical reviews to determine aging effects managed by an aging management

program. The applicant provided adequate guidance to ensure aging effects are

appropriately managed. 10 CFR Part 50, Appendix J ProgramThe 10 CFR Part 50, Appendix J Program is an existing program credited withmanaging the aging degradation of pressure retaining boundaries of piping and

components of the various systems penetrating the containment at the Oyster CreekGenerating Station. In addition, the program also detects age related degradation inmaterial properties of gaskets, o-rings, and packing materials for the primary

containment pressure boundary access points. The aging effects are managed by

performing containment leak rate tests to assure that leakage through primary

containment and systems and components penetrating primary containment does notexceed allowable leakage limits specified in the Technical Specifications.

6EnclosureThe inspectors reviewed Oyster Creek's procedures for leak rate testing. In addition,the inspectors reviewed corrective actions for components that did not meet leak rate

test acceptance criteria. The inspectors noted that corrective actions taken to repair

these components were acceptable.For the 10 CFR Part 50, Appendix J Program, the inspectors concluded the applicanthad conducted adequate evaluations as well as industry experience and historical

reviews to determine aging effects managed by an aging management program. The

applicant provided adequate guidance to ensure aging effects are appropriately

managed. Fuel Oil Chemistry ProgramThe Fuel Oil Chemistry Program is an existing program that will be modified for thepurpose of managing the affects of pitting and corrosion in the diesel fuel oil tank at the

Oyster Creek Generating Station. The aging effects are managed by the addition ofbiocides and corrosion inhibitors to minimize biological activity and mitigate corrosion,

periodic cleaning, and applying coating to the internal surfaces of the tank.The inspectors reviewed the schedule for implementation of the enhancements. Theinspectors reviewed recent sample results and tank thickness measurements to verify

that results were within the acceptable range.For the Fuel Oil Chemistry Program, the inspectors concluded the applicant hadconducted adequate evaluations as well as industry experience and historical reviews to

determine aging effects managed by an aging management program. The applicant

provided adequate guidance to ensure aging effects are appropriately managed. Boiling Water Reactor Feedwater Nozzle ProgramThe Boiling Water Reactor Feedwater Nozzle Program is an existing program that

willbe modified to implement the recommendations of the Boiling Water Owners GroupLicensing Topical Report: General Electric NE-523-A71-0594. These enhancements

willbe implemented prior to entering the period of extended operation per Oyster CreekAssignment Report AR# 00330592, A.1.05 Commitment (BWR Feedwater Nozzle). The

program is credited with managing the aging effects of cracking in the feedwater

nozzles. The program is administered by the station in-service inspection plan ER-OC-

330-1001, "ISI Program Plan Fourth Ten-Year Inspection Interval," and implemented by

station procedure ER-AA-330-002, "In-service Inspection of Section XI Welds and

Components". The station in-service inspection program incorporates the requirements

of the ASME Code. The aging effects are managed by periodic ultrasonic testing

inspections of critical regions of the feedwater nozzles. The ultrasonic test inspections

are performed at intervals not exceeding ten years and was embraced in an NRC safetyevaluation.

7EnclosureInspections performed in 1977 identified cracks in the Oyster Creek nozzles. Thesecracks were repaired. The inspectors reviewed plant modification #166-76-4,"Feedwater Nozzle Cladding Removal and Sparger Replacement" and reviewed

selected ultrasonic testing examination reports of the feedwater nozzles. To minimize

thermal cycling and fatigue induced cracking, the thermal sleeves were modified to a

piston design. Subsequent inspections found no indications in the feedwater nozzles.

The inspectors reviewed Focused Area Self-Assessment Report Oyster Creek Inservice

Inspection Program, completed in June 2004. The inspectors determined the feedwater

nozzle program at Oyster Creek effectively monitored the feedwater nozzles for

cracking.For the Boiling Water Reactor Feedwater Nozzle Program, the inspectors concluded theapplicant had conducted adequate evaluations as well as industry experience and

historical reviews to determine aging effects managed by an aging management

program. The applicant provided adequate guidance to ensure aging effects are

appropriately managed. Boiling Water Reactor Stress Corrosion Cracking ProgramThe Boiling Water Reactor Stress Corrosion Cracking Program is an existing agingmanagement program credited with managing crack initiation and growth due to

intergranular stress corrosion cracking in stainless steel and nickel alloy reactor coolant

pressure boundary piping, welds, components and piping four inches and larger nominal

pipe size exposed to reactor coolant above 200F. The aging effects are managed bypreventive measures which include monitoring and controlling water impurities byimproved water chemistry control activities and by providing replacement stainless steel

components in a solution annealed condition with a maximum carbon content of 0.035%

wt. and a minimum ferrite level of 7.5%. Inspection and flaw evaluations are conducted

in accordance with Oyster Creek in-service inspection program plan ER-OC-330-1001,

"ISI Program Plan Fourth Ten-Year Inspection Interval" and Oyster Creek's augmented

inspection program for IGSCC ER-OC-330-1002, "IGSCC Inspection Plan Fourth Ten-

Year Inspection Interval," which incorporates the technical basis and guidance described

in NUREG-0313, NRC Generic Letter 88-01, and staff-reviewed Boiling Water ReactorVessel Internal Inspection Program BWRVIP-75. The inspectors noted that where pre-emptive piping replacement was accomplished thereplacement piping material used was more resistant to intergranular stress corrosion

cracking than the original piping material. The applicant replaced the followi

ng syst empiping material with intergranular stress corrosion cracking resistant material: 1) all isolation condenser large bore piping outside the drywell from the drywellpenetrations to the isolation condensers during refueling outage 1R13 in 1991; 2) all piping within the four isolation condenser drywell penetrations and the tworeactor water cleanup system drywell penetrations which contained welds thatwere not inspectible;3) the head cooling spray nozzle assembly, the 4 inch tee and flange of thereactor vent line.

8EnclosureTo further mitigate the initiation and propagation of intergranular stress corrosioncracking the applicant implemented hydrogen water chemistry during cycle 12 in 1990and noble metals chemical additions during 1R19 refueling outage in 2002.

Additionally, all accessible welds susceptible to intergranular stress corrosion cracking

in reactor coolant boundary piping systems inside the drywell (except the reactor watercleanup system) were stress improved. The Boiling Water Reactor stress corrosion cracking aging management program usesultrasonic testing to detect intergranular stress corrosion cracking flaws in the reactor

coolant boundary piping prior to loss of intended functions of the components. Of the

380 welds included in the scope of Generic Letter 88-01, Oyster Creek identified, during

the period the program was implemented, there were 11 welds with indications of

intergranular stress corrosion cracking. Nine welds have been repaired with full

structural overlays (four in the core spray system, four in the reactor recirculationsystem, and one in the shutdown cooling system). Two reactor recirculation systemwelds, which were both stress improved before initial inspections had indications of

intergranular stress corrosion cracking, remained in service without repair. Both of

these welds in the reactor recirculation system have been re-examined in 2002 and2004 using the Improved Performance Demonstration Initiative ultrasonic test

examination technique and the welds did not exhibit any indication of intergranular

stress corrosion cracking. No new indications of intergranular stress corrosion cracking

have been detected by inspections during the past six refueling outages. As a result of

the implemented preventive measures to mitigate intergranular stress corrosion cracking

Oyster Creek has no indications of intergranular stress corrosion cracking at this time.

Therefore the inspectors determined that the Boiling Water Reactor Stress CorrosionProgram at Oyster Creek has been effective in monitoring and mitigating intergranular

stress corrosion cracking in the reactor coolant boundary piping systems. For the Boiling Water Reactor Stress Corrosion Cracking Program, the inspectorsconcluded the applicant had conducted adequate evaluations as well as industry

experience and historical reviews to determine aging effects managed by an aging

management program. The applicant provided adequate guidance to ensure aging

effects are appropriately managed. Periodic Inspection ProgramThe Periodic Inspection Program is a new program under development at Oyster Creekthat consists of periodic inspections of selected systems in the scope of license renewalthat require periodic monitoring of aging effects, and are not covered by other existing

periodic monitoring programs to verify the integrity of the systems and confirm theabsence of identified aging effects. The Periodic Inspection Program manages the

aging effect of change in material properties, loss of material and reduction of heat

transfer for systems, components, and environments. The aging effects are managedby periodic condition monitoring examinations performed at susceptible locations in the

systems, int

ended to assure that existing environmental conditions are not causingmaterial degradation that could result in a loss of system intended functions. The initialperiodic inspections of this new aging management program will be implemented

near

9Enclosurethe end of the current operating term but prior to the period of extended operation. Subsequent periodic inspections will be performed on a frequency not to exceed onceevery ten years.The Periodic Inspection Program provides inspection criteria, requires evaluation of theinspection results, and provides recommendations for additional inspections, as

necessary. Inspections will be performed in accordance with station procedures that arebased on applicable codes and standards. Inspection methods may include visual

examinations VT-1 or VT-3 of disassembled components or volumetric non-destructive

examination techniques. Some of the implementing procedures for the Periodic

Inspection Program were reviewed by the inspectors, including existing nondestructive

examination procedures ER-OC-330-1001, ISI Program Plan "Fourth Ten-Year

Inspection Interval," ER-AA-35-014, "VT-1 Visual Examinations," ER-AA-335-016, "VT-3

Visual Examination of Component Supports and Attachments," and ER-AA-335-032,

"Ultrasonic Through Wall Sizing in Pipe Welds". A periodic inspection table, which was

in draft at the time of this inspection, is a listing of sele

cted systems and components tobe periodically inspected to verify the integrity of the system and confirm t

he absence ofidentified aging effects was also reviewed. Based on review of the implementing

documents and procedures, the inspectors determined that the Periodic InspectionProgram, when implemented at Oyster Creek, will provide assurance that systems andcomponents are routinely inspected for age related degradation of change in material

properties, loss of material and reduction of heat transfer for systems, components, andenvironments, and

will adequately manage the identified aging effects.For the Periodic Inspection Program, the inspectors concluded the applicant hadconducted adequate evaluations as well as industry experience and historical reviews to

determine aging effects managed by an aging management program. The applicant

provided adequate guidance to ensure aging effects are appropriately managed. Wooden Utility Pole ProgramThe Wooden Utility Pole Program is a new program credited with managing the agingeffects of loss of material and change in material properties in all wooden utility poleswhich support an intended function for the offsite power systems at the Oyster CreekGenerating Station. The aging effects are managed by inspection of wooden poles

every ten years by a qualified inspector.The team reviewed program bases documents and industry guidance. The inspectorsalso conducted interviews and performed walkdowns with plant personnel. During the

walkdown, one pole (JC 514A L) was noted to be degraded. The applicant was able to

show that the condition had been previously analyzed and that plans are in place to

adequately reinforce the pole.For the Wooden Utility Pole Program, the inspectors concluded the applicant hadconducted adequate evaluations as well as industry experience and historical reviews to

determine aging effects managed by the Wooden Utility Pole Program. The applicantprovided adequate draft guidance to ensure aging effects will be appropriatelymanaged.

10EnclosurePeriodic Testing of Containment Spray NozzlesThe Containment Spray Nozzle Program is an existing program credited withdemonstrating that the drywell and torus spray nozzles are not blocked by debris or

corrosion products. Carbon steel piping upstream of the drywell and torus spray nozzles

is subject to possible general corrosion that could result in plugging nozzles with rust.

Periodic air tests verify that the drywell and torus spray nozzles are free from plugging

and are therefore available to provide the steam quenching functions of the nozzles.The team conducted interviews and reviewed program bases documents and previoustest results. The team noted that the existing program has been effective at identifyingand correcting degraded conditions. For the Periodic Testing of Containment Spray Nozzles Program, the inspectorsconcluded the applicant had conducted adequate evaluations as well as industry

experience and historical reviews to determine aging effects managed by the

Containment Spray Nozzle Program. The applicant provided adequate guidance to

ensure aging effects are appropriately managed. Inaccessible Medium-Voltage Cables Not Subject to 10 CFR 50.49 EnvironmentalQualification RequirementsThe Inaccessible Medium-Voltage Cables Not Subject to 10 CFR 50.49 EnvironmentalQualification Requirements Program is a new program developed for the purpose of

aging management credited with managing the moisture related aging effects in

medium-voltage cable systems at the Oyster Creek Generating Station. The agingeffects are managed by cable testing and periodic inspection of manholes. The team reviewed program bases documents and industry guidance. The inspectorsalso conducted interviews and performed walkdowns with plant personnel. The

manhole inspection frequency was initially established at the NUREG-1801,Revision 1,"Generic Aging Lessons Learned (GALL) Report," recommended two-year

frequency based on Oyster Creek's operating experience that does not indicate a trend

or recurrence of cable submergence in manholes. However, NRC inspectors identified,approximately 2 inches of water in the manhole selected by the NRC team forinspection. Consequently, the applicant entered this issue into the corrective action

system (CA #IR 469998, #IR 471363) and documented the need to re-evaluate theadequacy of the manhole inspection frequency. Due to several medium-voltage cable failures in Oyster Creek's operating experience, amedium-voltage cable testing program is currently in place. Because of the limited

success of the previous DC step voltage testing method, Oyster Creek has begun

implementing a new method of cable testing provided by DTE Energy for most of the

medium-voltage cables. NUREG 1801 (XI.E3) specifies the test method should bestate-of-the-art at the time the test is performed. Although the new DTE Energy testingmethod is not yet recognized as an industry standard, it is a form of partial discharge

testing (partial discharge testing is one of the recognized standards specifically listed in

11Enclosurethe NUREG-1801), and the applicant expects formal acceptance of the new testingmethod as an industry standard prior to extended operation.The applicant has agreed to maintain the current testing frequency limit of six years inLRCR 289 for the first six years, after which the frequency may be re-evaluated and extended up to ten years. This change will provide sufficient time for successfuloperating experience prior to expanding to the NUREG 1801 recommended ten yearfrequency.For the Inaccessible Medium-Voltage Cables Not Subject to 10 CFR 50.49Environmental Qualification Requirements Program, the inspectors concluded the

applicant had conducted adequate evaluations as well as industry experience and

historical reviews to determine aging effects managed by the Inaccessible Medium-

Voltage Cables Not Subject to 10 CFR 50.49 Environmental Qualification Requirements

Program. The applicant provided adequate guidance to ensure aging effects are

appropriately managed. Electrical Cables and Connections Not Subject to 10 CFR 50.49 EnvironmentalQualification RequirementsThe Electrical Cables and Connections Not Subject to 10 CFR 50.49 EnvironmentalQualification Requirements Program is a new program credited with managing the heat,radiation, and moisture aging effects in non-environmentally qualified electrical cables

and connections in Oyster Creek Generating Station. Connections include splices,

terminal blo

cks, connectors, and fuse blocks. The aging effects are managed byperiodic inspections. The team reviewed program bases documents, a draft implementing procedure andindustry guidance. The inspectors also conducted interviews and performed walkdowns

with plant personnel. Inspections will be done of all accessible cables and connectionsin adverse localized environments. This aging management program focuses on a

representative sample of accessible cables and connections with sampling structured to

include key areas of concern. Plant locations containing cables within scope that do not

include adverse general or localized conditions may be excluded from inspections based

on engineering evaluations. Because there were several examples of polyvinyl chloride cable insulation bleeding inOyster Creek's operating experience, the applicant agreed to specifically include

polyvinyl chloride cable insulation bleeding as an aging effect to be addressed in this

program. Although polyvinyl chloride cable insulation bleeding has not led to any

equipment degradation at Oyster Creek, there have been instances cited in

NRC'sInformation Notices 91-20 and 94-78 where polyvinyl chloride insulation bleeding under

unfavorable configurations caused hardened plasticizer to degrade equipment. As a

consequence of the NRC's review, the applicant entered this issue into their correctiveaction system (AR 00472707) in order to evaluate the current extent-of-condition ofpolyvinyl chloride cable insulation bleeding and determine if their original screening of

this aging affect should be revised.

12EnclosureFor the Electrical Cables and Connections Not Subject to 10 CFR 50.49 EnvironmentalQualification Requirements Program, the inspectors concluded the applicant hadconducted adequate evaluations as well as industry experience and historical reviews to

determine aging effects managed by the Electrical Cables and Connections Not Subject

to 10 CFR 50.49 Environmental Qualification Requirements Program. The applicant

provided adequate draft guidance to ensure aging effects are appropriately managed.Electrical Cables and Connections Not Subject to 10 CFR 50.49 EnvironmentalQualification Requirements Used in Instrument CircuitsThe Electrical Cables and Connections Not Subject to 10 CFR 50.49 EnvironmentalQualification Requirements Used in Instrument Circuits Program is an existing program

modified for the purpose of aging management that manages aging of the cables of the

Intermediate Range Monitoring, Local Power Range Monitoring/Average Power Range

Monitoring, Reactor Building High Radiation Monitoring, and Air Ejector Off-Gas

Radiation Monitoring systems that are sensitive instrumentation circuits with low-levelsignals and are located in areas where the cables and connections could be exposed to

adverse localized environments caused by heat, radiation, or moisture. The aging

effects are managed by calibration, current/voltage, and time domain reflectometry

testing. The current program will be enhanced to include a review of the calibration andcable testing results for cable aging degradation.The team reviewed program bases documents, draft implementing procedure andindustry guidance. The inspectors also conducted interviews and performed walkdowns

with plant personnel.For the Electrical Cables and Connections Not Subject to 10 CFR 50.49 EnvironmentalQualification Requirements Used in Instrument Circuits Program, the inspectors

concluded the applicant had conducted adequate evaluations as well as industry

experience and historical reviews to determine aging effects managed by the Electrical

Cables and Connections Not Subject to 10 CFR 50.49 Environmental Qualification

Requirements Used in Instrument Circuits Program. The applicant provided adequate

draft guidance to ensure aging effects are appropriately managed.Fire Protection ProgramThe Fire Protection Program is an existing program modified for the purpose of agingmanagement credited with managing the fire barrier function aging effects in fire

protection systems and a diesel-driven fire pump inspection program. The aging effectsare managed by periodic inspection of fire barrier penetration seals, fire barrier walls,

ceilings, floors, and all fire rated doors. The program is credited with managing loss of

material aging effects in fuel oil lines of the diesel driven fire pump through periodic

testing of the pump. This aging management program will also manage the agingeffects of in-scope carbon dioxide and halon suppression systems, once enhancementsare made to periodically inspect these systems.

13EnclosureThe inspectors reviewed the Fire Protection Program as well as supporting documentsto verify the effectiveness of the Fire Protection Program. The inspectors also

conducted interviews and performed walkdowns of various fire protection systems withplant personnel to observe the effectiveness of the existing Fire Protection Program.

Enhancements to the existing program include guidance to identify fire barrier

degradation, surface integrity and clearance on fire doors inspected every two years, fire

pump diesel fuel supply system external surface corrosion examinations, and externalcorrosion and damage inspections for halon and low-pressure carbon dioxide fire

suppression systems. The inspectors noted an acceptable exception in the applicationof the NUREG-1801 guidance for 6-month periodicity on visual inspection and functionaltesting of halon and carbon dioxide fire suppressions. Oyster Creek Generating Station

performs in-depth operational tests and inspections on an 18-month periodicity. The

applicant does perform a weekly tank/charge check and a monthly valve position

alignment check and will include visual inspections of external surfaces as anenhancement prior to the period of extended operation.For the Fire Protection Program, the inspectors concluded the applicant had conductedadequate evaluations as well as industry experience and historical reviews to determine

aging effects managed by the fire protection program. The applicant has provided

adequate guidance to ensure aging effects are appropriately managed. Fire Water System ProgramThe Fire Water System Program is an existing program modified for the purpose ofaging management credited with managing the loss of material, microbiological

influenced corrosion, and biofouling aging effects in fire water systems at Oyster CreekGenerating Station. The aging effects are managed by periodic maintenance, testing,and inspection of system piping and components in accordance with codes andstandards. The inspectors reviewed program bases documents, completed testing and

maintenance procedures, corrective action reports, design documents, and industry

guidance. The inspectors also conducted interviews and performed walkdowns of the

fire water system with plant personnel. The fire water system is maintained in apressurized state which provides the applicant with constant system integrity status. The piping internals are routinely inspected at various locations throughout

the systemfor loss of material and biofouling. The following enhancements have been noted:Sprinkler head inspections in accordance with NFPA 25 "Standard for theInspection, Testing, and Maintenance of Water-Based Fire Protection Systems"

(1998 Edition).Samples will be submitted to a testing laboratory prior to being in service 50years.Inclusion of inspection of selected portions of the fire protection system pipinglocated aboveground and exposed to water, by non-intrusive volumetric

examinations.Performance of water sampling for the presence of microbiological corrosionevery 5 years.

14EnclosureInclusion of visual inspection of the water storage tank heater pressure boundarycomponents during the periodic tank internal inspection.For the Fire Water System Program, the inspectors concluded the applicant hadconducted adequate evaluations, as well as industry experience and historical reviews

to determine aging effects managed by the fire water system program. The applicantprovided an acceptable plan to implement adequate guidance and terms to ensure

aging effects are appropriately managed. Periodic Inspection of Ventilation Systems ProgramThe Periodic Inspection of Ventilation Systems Program is an existing program atOyster Creek Generating Station modified for the purpose of aging management. Theprogram is credited with managing loss of material, changes in material properties, and

degradation of heat transfer in ventilation systems in the scope of license renewal(flexible connections, fan and filter housings, and access door seals). Instrument piping

and valves, restricting orifices and flow elements, thermowells, and Standby Gas

Treatment System ducting exposed to soil or sand will be added to the scope asenhancements to the program. The aging effects are managed by periodic inspections

that will be condition monitoring examinations performed at susceptible locations in thesystems, int

ended to assure that existing environmental conditions are not causingmaterial degradation that could result in a loss of system intended functions. The inspectors reviewed program bases documents, completed testing andmaintenance procedures, corrective action reports, design documents, and industry

guidance. The inspectors also conducted interviews and performed walkdowns of

accessible portions of Standby Gas Treatment and Reactor Building Ventilation Systems

with plant personnel.Complete visual inspections and performance tests of all ventilation systems in scopeare performed during system preventive maintenance activities on a frequency not toexceed five years. This includes system leakage and filter efficiency tests for StandbyGas Treatment, Reactor Building and Control Room Ventilation systems. An additionalnoted enhancement includes adding specific guidance to inspect for loss of material and

material property changes. For the Periodic Inspection of Ventilation Systems Program, the inspectors concludedthe applicant had conducted adequate evaluations as well as industry experience and

historical reviews to determine aging effects managed by an aging management

program. The applicant provided adequate guidance to ensure aging effects are

appropriately managed. Periodic Inspection - Forked River Combustion TurbineThe Periodic Inspection - Forked River Combustion Turbine program is a new programcredited with addressing the two Forked River Combustion Turbine power plant

components in the scope of license renewal that require periodic monitoring of aging

15Enclosureeffects, and are not covered by other aging management programs. In the applicant'sresponse to the NRC's requests for additional information, RAI 2.5.1.19-1, datedOctober 12, 2005 and November 11, 2005, the applicant expanded the single agingmanagement for the Forked River Combustion Turbine to twelve aging management

programs. This periodic inspection program is one of twelve programs that monitor the

aging effects of the Forked River Combustion Turbine.The Periodic Inspection - Forked River Combustion Turbine aging management programmanages the aging effect of change in material properties, loss of material and reduction

of heat transfer for systems, components, and environments. The aging effects aremanaged by periodic inspections that will be condition monitoring examinationsperformed at susceptible locations in the systems, intended to assure that existingenvironmental conditions are not causing material degradation that could result in a loss

of system intended functions. These inspections will be performed on a periodicity not toexceed once every 10 years and will coincide with major combustion turbinemaintenance inspections.The two Forked River Combustion Turbines are owned, operated, and maintained byFirstEnergy, under contract to supply station blackout services to Oyster Creek

Generating Station. The inspectors reviewed program bases documents, maintenancerule performance data, walkdown reports, and action logs. Applicable portions of the

Interconnect and Station Blackout Agreements were reviewed. The inspectors also

conducted interviews and performed walkdowns with Oyster Creek Generating Station

and FirstEnergy personnel of the Forked River Combustion Turbine facility and portionsof its switchyard. The inspectors observed maintenance activities conducted by General

Electric for FirstEnergy on Forked River Combustion Turbine #2 during a minor outage. Though the Forked River Combustion Turbines are operated and maintained byFirstEnergy, Oyster Creek Generating Station assigns a system engineer to monitor theirperformance via monthly data sets and logs received from the onsite FirstEnergy

engineers. Significant events and maintenance on the Forked River Combustion Turbine

are logged and evaluated by the Oyster Creek system engineer for further action.At the time of this inspection, the implementing procedures for this program were notdeveloped. Hence, the aging management program elements have not been negotiatedwith FirstEnergy to be added into the Station Blackout Agreement. The Office of Nuclear

Reactor Regulation accepted AmerGen's response to 2.5.1.15-1 and 2.5.1.19-1 andrequests for additional information. Based on discussions with applicant personnel and

reviews of supporting documents, the inspectors concluded that the applicant has plans

to develop adequate guidance and terms for implementation of the Periodic Inspection -

Forked River Combustion Turbine Program. AmerGen will negotiate those terms into thestation blackout agreement.For the Periodic Inspection - Forked River Combustion Turbine Program, the inspectorsconcluded the applicant had conducted adequate evaluations as well as industry

experience and historical reviews to determine aging effects managed by an aging

management program. The applicant provided an acceptable plan to implement

adequate guidance and terms to ensure aging effects are appropriately managed.

16EnclosureASME,Section XI, Subsection IWE ProgramThe ASME,Section XI, Subsection IWE Program is an existing program modified forthe purpose of aging management credited with managing the aging effects in drywell

containment systems in Oyster Creek Generating Station. ASME Section XI,Subsection IWE provides for inspection of primary containment components and the

containment vacuum breakers system piping and components. It covers steelcontainment shells and their integral attachments; containment hatc

hes and airlocks,seals and gaskets, containment vacuum breakers system piping and components, andpressure retaining bolting. The aging effects are managed by periodic visual

inspections, and periodic ultrasonic testing wall thickness measurements. Additionally,

the applicant will conduct monitoring of leakage from the drywell sand bed region drainsgoing forward, as an additional method to detect conditions favorable for corrosion to

occur. Only the visual and ultrasonic examinations are given credit for managing the

affects of aging. The inspectors reviewed all of the licensee's ultrasonic thickness testing inspectionresults for the condition of the drywell from 1983 through 2002, evaluations and

calculations of corrosion rates and projections of wall thickness for several locations on

the drywell. Also, the inspectors reviewed video records of the sand bed region

condition and the removal of the sand from the sand bed region. The inspectors

reviewed the structural analysis performed to confirm the structural integrity of the

drywell after the amount of corrosion had been determined. The inspectors reviewed

the most recently completed visual inspection results of the drywell sand bed exterior

coating and the UT measurements from higher elevations of the drywell.For the ASME,Section XI, Subsection IWE Program, the inspectors concluded theapplicant had conducted adequate evaluations as well as industry experience and

historical reviews to determine aging effects managed by the ASME,Section XI,

Subsection IWE Program. The applicant provided adequate guidance to ensure aging

effects are appropriately managed, pending resolution of Safety Evaluation Report

Open Items OI 4.7.2-1.1 through OI 4.7.1-1.4, and OI 4.7.2-3.Protective Coating Monitoring and Maintenance ProgramThe Protective Coating Monitoring and Maintenance Program is an existing programcredited with managing the aging effects on the internal and external surfaces of the

torus and the condition of the drywell in the sand bed region in systems in Oyster CreekGenerating Station. The aging effects are managed by visual inspections of the

protective coatings on each component, and examination, evaluation and repair of all

coating defects observed. The inspectors reviewed the past inspection results in each area to understand whatconditions are being documented, the method of evaluation of recorded indications, the

repair methods used to fix any damaged or degraded coating. The inspectors also

looked at the licensee's cause determination for the underlying corrosion phenomena

and actions being taken to monitor the condition.

17EnclosureThe team concluded that as long as the coating integrity was maintained by thisprogram, the presence of water, as indicated by collection from the former sandbed

area drains, would not affect the rate of corrosion of the drywell at the former sandbed

area.For the Protective Coating Monitoring and Maintenance Program, the inspectorsconcluded the applicant had conducted adequate evaluations as well as industry

experience and historical reviews to determine aging effects managed by the Protective

Coating Monitoring and Maintenance Program. The applicant provided adequate

guidance to ensure aging effects are appropriately managed. Above-Ground Outdoor Tank Monitoring ProgramThe Above-Ground Outdoor Tank Monitoring Program is a new program credited withmanaging the aging effects on above ground steel tanks in systems at the OysterCreek Generating Station. The aging effects will be managed by periodic visualinspections, some nondestructive evaluation inspections based upon maintenance

history and industry experience. The inspectors reviewed the Oyster Creek Generation Station template used to guideand control this inspection effort, conducted field walkdowns of four of the tanks

covered by the program and reviewed the industry operating experience which the

licensee has used to prepare this inspection program.For the Above-Ground Outdoor Tank Monitoring Program, the inspectors concluded theapplicant had conducted adequate evaluations as well as industry experience and

historical reviews to determine aging effects managed by the Above Ground Outdoor

Tank Monitoring Program. The applicant provided adequate guidance to ensure aging

effects are appropriately managed. ASME Section XI, Subsection IWFThe ASME Section XI, Subsection IWF Program is an existing program credited withmanaging the aging effects in the ASME Section XI, Subsection IWF. Subsection IWF

provides for periodic visual examination of ASME Section XI Class 1, 2, 3 and MC

components and piping support members for loss of mechanical function and loss of

material. Bolting is also included with these components, inspecting for loss of material

and for loss of preload by inspecting for missing, detached, or loosened bolts.The aging effects are managed by periodic visual examinations for corrosion and lossof material in structural members, loss of preload in bolting; missing, detached, or

loosened members or bolts; and any degradation of protective coatings. The program

has been enhanced by including additional MC components in the approved ASME

Section XI, Inservice Inspection program.

18EnclosureThe inspectors reviewed the program description, program basis documents, thecurrently approved ASME Section XI, Subsection IWF program, and the results of

previous inspections and examinations. The documents reviewed and discussions with

cognizant individuals indicated the operating experience of the In-service Inspection

program at Oyster Creek, which includes ASME Section XI, Subsection IWF aging

management activities, has not shown any adverse trend. Periodic self-assessments of

the program have been performed to identify the areas that need improvement tomaintain the quality and integrity of the program. The proposed aging management

program based on the ASME Section XI, Subsection IWF, is generally consistent with

the elements of XI.S3 of NUREG-1801 with some exceptions; e.g., NUREG 1801specifies ASME Section XI, 2001edition, including the 2002 and 2003 addenda,

whereas, the station program is based on ASME Section XI, 1995 edition with 1996

addenda, an acceptable alternate edition of the code. The enhancements includeadditional MC supports and inspection of underwater supports.For the ASME Section XI, Subsection IWF Program, the inspectors concluded theapplicant had conducted adequate evaluations as well as industry experience and

historical reviews to determine aging effects managed by an aging management

program. The applicant provided adequate guidance to ensure aging effects are

appropriately managed. Masonry Wall ProgramThe Masonry Wall Program is credited with managing the aging effects in masonrywalls at the Oyster Creek Generating Station as part of the Structural MonitoringProgram. The aging effects are managed by a program of inspection of masonry walls

for cracking on a frequency of four years to assure that the established evaluation basis

for each masonry wall remains valid during the period of extended operation.The inspectors reviewed the program description, program basis documents, thecurrently approved station procedures, the results of prior inspections, discussions with

cognizant personnel, and a walkthrough visual examination of accessible masonry walls

to assess the effectiveness of the current program. The scope of the program includes

all masonry walls that perform intended functions in accordance with 10 CFR 54.4, and

were covered by I. E.Bulletin 80-11. The inspections are implemented though station procedures. Maintenance history hasrevealed minor degradation of masonry block walls; but none that could impact their

intended function. In response to I.E.Bulletin 80-11, "Masonry Wall Design," and

Information Notice 87-67, "Lessons Learned from Regional Inspections of Licensee

Actions in Response to I.E.Bulletin 80-11," various actions have been taken. Actions

have included program enhancements, follow-up inspections to substantiate masonry

wall analyses and classifications, and the development of procedures for tracking and

recording changes to the walls. These actions have addressed all concerns raised by

I.E.Bulletin 80-11 and Information Notice 87-67, namely unanalyzed conditions,

improper assumptions, improper classification, and lack of procedural controls. A

review of operating experience indicates that the program is effective for managing

aging effects of masonry walls.

19EnclosureFor the Masonry Wall Program, the inspectors concluded the applicant had conductedadequate evaluations as well as industry experience and historical reviews to determine

aging effects managed by an aging program. The applicant provided adequate

guidance to ensure aging effects are appropriately managed. Structures Monitoring ProgramThe Structures Monitoring Program is an existing program that has been modified, andwill be further modified, for the purpose of aging management of structures andstructural components, including structural bolting within the scope of license renewal at

Oyster Creek Station. The program was developed based on Regulatory Guide 1.160,Revision 2, "Monitoring the Effectiveness of Maintenance at Nuclear Power Plants," and

NUMARC 93-01 Revision 2, "Industry Guidelines for Monitoring the Effectiveness of

Maintenance at Nuclear Power Plants," to satisfy the requirement of 10 CFR 50.65,

"Requirements for Monitoring the Effectiveness of Maintenance at Nuclear Power

Plants". The scope of the program also includes condition monitoring of masonry walls andwater-control structures as described in the Masonry Wall Program and in the RG 1.127, and Inspection of Water-Control Structures Associated With Nuclear Power

Plants aging management program. The enhanced program includes structures that

are not monitored under the current term but require monitoring during the period of

extended operation. Aging effects are managed by periodic visual inspections by

qualified personnel to monitor structures and components for applicable aging effects.

Specifically, concrete structures are inspected for loss of material, cracking, and a

change in material properties. Steel components are inspected for loss of material due

to corrosion. Masonry walls are inspected for cracking, and elastomers will bemonitored for a change in material properties. Earthen structures associated with

water-control structures and the Fire Pond Dam will be inspected for loss of materialand loss of form. Component supports will be inspected for loss of material, reductionor loss of isolation function, and reduction in anchor capacity due to local concrete

degradation. Exposed surfaces of bolting are monitored for loss of material, due to corrosion, loosenuts, missing bolts, or other indications of loss of preload. The scope of the program

will be enhanced to include structures that are not monitored under the current term butrequire monitoring during the period of extended operation. The inspectors reviewed the program description, program basis documents, thecurrently approved station procedures, the results of prior inspections, discussions with

cognizant personnel, and a walkthrough visual examination of accessible structural

items, including reinforced concrete and structural steel members, components and

systems to assess the effectiveness of the current program. The scope of the programalso includes all masonry walls that perform intended functions in accordance with

10 CFR 54.4, and were covered by I. E.Bulletin 80-11. The inspections included a

review of station procedures, maintenance history, inspection findings and followup of

inspection findings, and current inspection schedules. Inspection frequency is every

20Enclosurefour years; except for submerged portions of water-control structures, which will beinspected when the structures are dewatered, or on a frequency not to exceed ten

years. The program contains provisions for more frequent inspections to ensure that

observed conditions that have the potential for impacting an intended function areevaluated or corrected in accordance with the corrective action process. The

Structures Monitoring Program is consistent with the ten elements of aging

management program XI.S6, "Structures Monitoring Program," specified in NUREG-1801.For the Structures Monitoring Program, the inspectors concluded the applicant hadconducted adequate evaluations as well as industry experience and historical reviews to

determine aging effects managed by an aging management program. The applicant

provided adequate guidance to ensure aging effects are appropriately managed. Inspection of Water Control StructuresThe Inspection of Water Control Structures Program is an existing program modified forthe purpose of the aging management program credited with managing the aging

effects in Water Control Structure systems at the Oyster Creek Generating Station. The aging effects are managed by periodic inspections of the water control structures

for structural and hydraulic degradation, and potential loss of function of intended

service. The Water Control Structure Program is a subpart of the main Structures

Monitoring Program. It is based on the guidance provided in RG 1.127 and ACI 349.3R

and will provide for periodic inspection of the Intake Structure and Canal, the Fire PondDam, and the Dilution structure. The program will be used to manage loss of material,cracking, and change in material properties for concrete components, loss of material

and change in material properties for wooden components, and loss of material, and

loss of form of the dam, and the canal slopes. Inspection frequency is every four years;

except for submerged portions of the structures, which will be inspected w

hen thestructures are de-watered, or on a frequency not to exceed ten years. The program

willbe enhanced to ensure that water-control structures aging effects are adequately

managed during the period of extended operation.The inspectors reviewed the program description, program basis documents, thecurrently approved station procedures, the results of prior inspections, discussions with

cognizant personnel, and a walkthrough visual examination of accessible water control

structures, including com

ponents and systems to assess the effectiveness of thecurrent program. As the Water Control Structures Monitoring Program is a subpart of

the larger Structures Monitoring Program, this review was performed in conjunction with

the comprehensive review of the main Structures Monitoring Program. Inspection of

Water-Control Structures Associated with Nuclear Power Plants program is consistent

with the ten elements of aging management program.For the Inspection of Water Control Structures Program, the inspectors concluded theapplicant had conducted adequate evaluations as well as industry experience and

historical reviews to determine aging effects managed by an aging management

program. The applicant provided adequate guidance to ensure aging effects are

appropriately managed.

21EnclosureMetal Fatigue of Reactor Coolant Pressure BoundaryThe Metal Fatigue of Reactor Coolant Pressure Boundary Aging Management Programmonitors select components in the reactor coolant pressure boundary by tracking and

evaluating contributing plant events. The Metal Fatigue of Reactor Coolant Pressure

Boundary program monitors operating transients and, by way of a computer program,

calculates up-to-date fatigue usage factors.The design basis metal fatigue analyses for the reactor coolant pressure boundary areconsidered time limited aging analysis for the purposes of license renewal. The Metal

Fatigue of Reactor Coolant Pressure Boundary Program provides an analytical basis for

confirming that the number of cycles, established by the analysis of record, will not beexceeded before the end of the period of extended operation. In order to determinecumulative usage factors more accurately, the program will implement FatigueProfatigue monitoring software. FatiguePro calculates cumulative fatigue using both

cycle-based and stress-based monitoring. This provides an analytical basis forconfirming that the number of cycles established by the analysis of record will not beexceeded before the end of the period of extended operation.For the Metal Fatigue of Reactor Coolant Pressure Boundary Aging ManagementProgram, the inspectors reviewed the program including the basis calculations, ongoing

monitoring, corrective actions, limiting components, and current cumulative usage

factors for the limiting components. The applicant provided adequate guidance to

ensure aging effects are appropriately managed. Isolation Condenser System ReviewThe Oyster Creek license renewal application listed a number of plant systems withinthe scope of license renewal. From this list the inspectors selected the isolation

condenser system for a focused review to determine whether the applicant's agingmanagement programs were adequate to effectively manage aging effects related to

this component. The following aging management programs are credited for managing

aging effects of the isolation condenser system: ASME Section XI In-serviceInspection, Subsection IWB, IWC, and IWD; Bolting Integrity; BWR Stress Corrosion

Cracking; One Time Inspection; Structures Monitoring Program; and, Water Chemistry.

The inspectors focused on the loss of material aging effect to determine how it would

be managed by the identified programs applied specifically to the Isolation Condenser

System.Although the Oyster Creek 10 CFR 50, Appendix K, design basis event analysis, nolonger takes credit for the Isolation Condenser it is very important for post-accident heat

removal and mitigation of event consequences. It ranks very high on the probabilisticrisk worth for this reason. Because of its risk importance the inspectors reviewed the

aging management programs given credit for managing the affects of aging in the

system.

22EnclosureThe Isolation Condenser System contains safety-related components relied upon toremain functional during and following design basis events. For example the primary

coolant boundary must be maintained through the condenser. Additionally the failure of

nonsafety-related structures and components in the Isolation Condenser System could

potentially prevent the satisfactory accomplishment of a safety-related function. The

isolation condenser also performs functions that support fire protection and station

blackout. AmerGen is committed, in their application documents, to maintaining the waterenvironment of the secondary side because the integrity of the heat exchanger tubescan be affected from both the inside and outside. Additionally, the heat exchangershell, and therefore, the secondary water environment, is part of the One-Time Aging

Management program because it is required to maintain structural integrity during a

design basis earthquake to support the heat exchanger tubing and the attached reactor

coolant/steam line piping.The applicant proposed using the ASME Section XI In-service Inspection, SubsectionsIWB, IWC, and IWD aging management program with the water chemistry aging

management program to manage loss of material of the Isolation Condensers. The

inspectors reviewed the Oyster Creek in-service inspection program procedure ER-OC-

330-1001, ISI Program Plan Fourth Ten-Year Inspection Interval to verify that it was

modified to include inspections of the isolation condenser tube side components, eddy

current testing of the tubes, and inspection (VT or UT) of the tube sheet and channel

head to ensure that degradation is not occurring and the components intended functionwill be maintained. The inspectors reviewed selected NDE reports of isolationcondenser system piping and components, where degradation would result, to verifycompliance with ASME Section XI Code.The inspectors reviewed the UT wall thickness data sheet 96-023-03 from 1R16refueling outage which documented shell thickness measurements of the "B" Isolation

Condenser. The UT results indicate that the shell thickness was over 0.350 inches in

most cases with one reading at 0.312 inches. The vendor drawing 1691-655-20

indicates the shell thickness is 0.375 inches with 0.100 inches corrosion allowance with

a minimum of 0.275 inches. Therefore, the "B" Isolation Condenser meets the originaldesign specifications. The inspectors noted that coating inspections performed by the

applicant of the inside shell surface of the "B" Isolation Condenser during 1R16 in 1996

blistering of the coating was observed in most of the submerged sections. The coating

on the inside shell of the isolation condensers is not credited in the aging managementprograms.Based on discussions with applicant personnel and reviews of the One-time AgingManagement Program basis documents, the inspectors determined the applicant has

elected to perform a one-time aging management program inspection of the shell of

isolation condenser prior to entering extended plant operations.

23Enclosure b.ObservationThe inspectors identified an observation related to the monitoring of liquid leakage fromthe former drywell sand bed region related to the current operating license period. Thisobservation was determined not to be safety significant and has been entered into the

applicant's ongoing corrective acti

on system.A current commitment for monitoring the sand bed drains is in a staff Safety EvaluationReport transmitted by letter November 1, 1995. This Safety Evaluation Report

requested a commitment to perform inspections "3 months after the discovery of any

water leakage". Subsequent correspondence from General Public Utilities NuclearCorporation the licensee, at the time, clarified the commitment after discussions withthe staff. The commitment made and accepted by the staff in a February 15, 1996,

letter was to perform an evaluation of the impact of any leakage during power

operations and conduct additional inspections of the drywell approximately 3 months

after discovery of the water leakage if the evaluation determines that it is warranted. This commitment was not meant to apply to minor leakage from normal refueling

activities.During the inspection, the NRC team requested a walkdown of the torus room. AmerGen staff walked down the torus room prior to the NRC team making entry. Water

collection jugs, fed by tubing from the former drywell sand bed drains, were emptied

prior to the NRC's walkdown, without taking samples of the water in the jugs orrecording water levels. The fact that water was present in the jugs meant that leakage

had been occurring. The applicant informed the NRC team that the bottles

had beenimproperly emptied without measurement or analysis. Upon further investigation, the

applicant could not find documentation that showed prior surveillance of the waterdrains had been completed. AmerGen staff also could not find documented evidence

that strippable coating of the refueling channel had been applied. This strippable

coating is used as a measure to limit or prevent water leakage during refueling

operations.The applicant stated that, although there was no formal leakage monitoring in place,there has been no previous reported evidence of leakage from the former sand bed

drains. Issue Report #348545 was submitted into the corrective action process when

the missed commitment and the improper emptying of the bottles were discovered.

This corrective action will capture the commitment in the applicant's computerizedscheduling process so that the required actions will be automatically prompted. Because there was no previously reported leakage, the applicant did not investigate thesource of leakage, take corrective actions, evaluate the impact of leakage, or perform

additional drywell inspections. The applicant further stated that a number of actions had been taken to alleviate theprevious water leakage problem since discovery of the consequent drywell shell

corrosion in the early 1990's. Some of the significant actions consisted of inspections

of the reactor cavity wall, remote visual inspection of the trough area below the reactor

cavity bellows seal area, and subsequent repair of the trough area and clearing of its

drain. Clearing of the trough drain and repair of the trough routed any leakage away

from the drywell shell. In addition, AmerGen believes that the strippable coating was

24Enclosureapplied to the reactor cavity walls before the reactor cavity is filled with water as part ofrefueling activities to minimize the likelihood of leakage into the trough area. The license renewal application does not take credit for the use of the strippablecoating, or the monitoring of the water leakage in managing the aging affects on the

liner. As long as the coating of the exterior surface of the former sand bed area is

maintained, any amount of water can be present and have no affect on the corrosion

rate. The thickness of the cylindrical portion of the liner is managed using ultrasonic

testing and this program will capture any changes in corrosion rate due to water in theliner gap. AmerGen has taken corrective actions to ensure, in the future, the drains are

monitored, and the strippable coating is applied. c.Overall FindingsThe inspection verified that there is an adequate approach to monitor and control theeffects of aging so that the intended function(s) of systems, structures, andcomponents, for which an aging management review is required, will be maintainedconsistent with the current licensing basis during the period of extended operation. Theinspection verified documentation, procedures, guidance, and personnel, appropriately

supported the license renewal application.40A6 Meetings, Including ExitThe inspectors presented the inspection results to Mr. T. Rausch, Oyster CreekGenerating Station Vice President, and other members of the licensee's staff in a

meeting that was open for public observation on September 13, 2006. The licenseehad no objections to the NRC observations. No proprietary information was provi

ded tothe inspectors during this inspection. The State of New Jersey, Department of

Environmental Protection attended the exit meeting, and made a statement at themeeting concerning the observation associated with the monitoring of liquid leakage

from the former drywell sandbed drains. In addition, they stated that a letter concerning

this issue was sent to the NRC Region I Regional Administrator dated September 13,2006. A copy of this letter is available in the NRC ADAMS document managementsystem under ML062630218.

A-1AttachmentATTACHMENTSUPPLEMENTAL INFORMATIONKEY POINTS OF CONTACTLicensee PersonnelJ. CamireSystem ManagerL. CorsiMechanical Engineer, LR Project

M. GallagherVice-President, License Renewal

J. HufnagelLicensing Lead, LR Project

K. MugglestonMechanical Engineer, LR Project

A. OuaouCivil Engineer, LR Project

F. PolaskiLicense Renewal Manager

T. QuintenzSite Lead Engineer, LR Project

D. WarfelTechnical Lead, LR Project

R. Francis App J. Program Manager

K. Muggleston Licensing

S. Getz, License Renewal

L. Corsi License Renewal

R. GayleyFAC Program Manager

J. WatleyCCCW System Engi

neerC. RothTBCCW System Engineer

R. ArtzChemist

M. MillerLicense RenewalT. TrettelFire Protection System Engineer

J. YuenSystem Engineer - Ventilation

C. MickloLicense Renewal

J. EschFirstEnergy Engineer

R. BonelliFirstEnergy Engineer

R. SkelskeySystem Engineer - FRCT

M. FilipponeSystem Manager

E. JohnsonSystem Manager

R. PruthiSystem Manager

S. SchwartzSystem Manager

D. SpamerSenior Engineer, Electrical

A-2AttachmentLIST OF DOCUMENTS REVIEWEDDrawingsComplete Set of License Renewal Drawings:LR-BR-2002, Rev. 0LR-BR-2003, Rev. 0

LR-BR-2004, Rev. 0

LR-BR-2005, Rev. 0

LR-BR-2006, Rev. 0

LR-BR-2007, Rev. 0

LR-BR-2008, Rev. 0

LR-BR-2009, Rev. 0

LR-BR-2010, Rev. 0

LR-BR-2011, Rev. 0

LR-BR-2012, Rev. 0

LR-BR-2013, Rev. 0

LR-BR-2014, Rev. 0

LR-BR-2015, Rev. 0

LR-BR-M0012, Rev. 0

LR-FP-SE-5419, Rev. 0

LR-GE-107C5339, Rev. 0

LR-GE-148F262, Rev. 0

LR-GE-148F437, Rev. 0

LR-GE-148F444, Rev. 0

LR-GE-148F711 Rev. 0

LR-GE-148F712, Rev. 0

LR-GE-148F723, Rev. 0

LR-GE-148F740, Rev. 0

LR-GE-197E871, Rev. 0

LR-GE-234R166, Rev. 0

LR-GE-237E487, Rev. 0

LR-GE-237E756, Rev. 0

LR-GE-237E798, Rev. 0

LR-GE-713E802, Rev. 0

LR-GE-865D741, Rev. 0

LR-GE-885D781 Rev. 0

LR-GU-3E-243-21-1000, Rev. 0

LR-GU-3E-551-21-1000, Rev. 0

LR-GU-3E-551-21-1001, Rev. 0

LR-GU-3E-666-21-1000, Rev. 0

LR-GU-3E-822-21-1000, Rev. 0

LR-GU-3E-861-21-1000, Rev. 0

LR-GU-3E-861-21-1001, Rev. 0

LR-GU-3E-861-21-1002, Rev. 0

LR-GU-3E-862-21-1000, Rev. 0

A-3AttachmentLR-GU-3E-871-21-1000, Rev. 0LR-JC-147434, Rev. 0

LR-JC-19479, Rev. 0

LR-JC-19616, Rev. 0

LR-JC-19629, Rev. 0

LR-OC-010520, Rev. 0

LR-SN-13432.19, Rev. 0Other DrawingsDrawing 4059-2, Sheet 2 or 3, Reactor Bldg. First Floor At Elev. 23' 6", Sections & Details -SH.2Drawing 3E-SK-5-85, 1986 Drywell Data UT Location Plan

Drawing BE-SK-S-89, Revision 0, 10/16/89; Ultrasonic Testing Drywell Level 30'2" - 67'5"M0123, Post Accident Sampling Isometric, Rev. 2

M0124, Post Accident Sampling Isometric, Rev. 2

M0278, Diesel Fuel Oil Storage Tank Isometric, Rev. 0GU 3E-000-A3-002, Sheet 7, Rev.1, Isometric Composite Various Systems IGSCC WeldHistory Foster Wheeler Drawing1691-655-20, Outline & Section of Emergency Condenser, Rev. F

Drawing 4059-2, Sheet 2 or 3, Reactor Bldg. First Floor At Elev. 23' 6", Sections & Details -SH.2Drawing 3E-SK-5-85, 1986 Drywell Data UT Location Plan

Drawing BE-SK-S-89, Revision 0, 10/16/89; Ultrasonic Testing Drywell Level 30'2" - 67'5"ProceduresMA-AA-723-500, Inspection of Non-EQ Cables and Connections for Managing AdverseLocalized Environments, Draft Rev 2A.

621.3.005, High Radiation Monitor Calibration, Draft Rev 48A.

621.3.002, Air Ejector Off Gas Radiation Monitor Check Source Functional Test, Draft Rev

26A.

2400-SMI-3623.09, Calibration and Operation of the LPRM Diagnostic System, Rev 11.

2400-SMI-3623.08, IRM Detector Current-Voltage (I/V) Testing, Rev 6.

2400-SMI-3623.03, IRM, SRM, LPRM, Characterization Trending and Diagnostics, Rev 7.

2400-SME-3780.05, Power Factor Testing of 5kV Cables, Rev 2.

2400-SME-3780.06, Dielectric Testing for 2.3kV and 5kV Cables and Equipment, Rev 8.

Exelon Technical Specification for Distribution System Wood Pole Inspection and Remediation,Dated 1/1/05.ECR OC 05-00275-00: Revise C-1302-187-E310-037, Revision 2

ER-AA-330-007

ER-AA-335-018

ER-AA-330, Revision 3: Conduct Of Inservice Inspection Activities

ER-AA-330-007, Revision 3: Visual Examination Of Section XI Class MC Surfaces And ClassCC Liners

A-4AttachmentER-AA-330-018, Revision 2: General, VT-1, VT-1C, VT-3 And VT-3C, Visual Examination OfASME Class MC And CC Containment Surfaces And Components2400-GMM-3900.52, Revision 3: Inspection And Torquing Of Bolted Connections

SM-AA-300, Revision 0; Procurement Engineering Support Activities

WO R2064827-06, Disassemble Reactor Vessel For Refuel Outage, Prepare Areas & ApplyCavity Coating, 11/1/06WO R2068582-03, Perform Reactor Vessel Reassembly, Remove Cavity Coating And DeconCavity, 11/1/06Procedure No. 666.5.007, Revision 16; Primary Containment Integrated Leak Rate TestPP-03, Criteria for Scoping Systems and Structures Relied upon to Demonstrate Compliancewith 10 CFR 54.4 (a)(2), Rev. 3PP-04, Systems and Structures Relied upon to Demonstrate Compliance with 10 CFR 50.63 -Station Blackout, Rev. 4PP-05, Systems and Structures Relied upon to Demonstrate Compliance with 10 CFR 50.62 -ATWS, Rev. 1PP-13, Abnormal Operating Transients, Rev. 2

PP-15, Standard Materials, Environment, and Aging Effects, Rev. 5

Inspection Sample Basis, Aug. 16, 2005

License Renewal Project Level Instruction 5 (PLI-5), Aging Management Reviews, Rev. 5

2400-GMM-3900.52, Inspection and Torquing of Bolted Connections, Rev. 3

2400-SMM-3900.04, System Pressure Test Procedure (ASME XI), Rev. 8

ER-AA-330-008, Protective Coatings, Rev. 3

ER-AA-2030, Attachment 4, System Walkdown Standards, Rev. 3

SA-AA-117, Excavation, Trenching, and Shoring, Rev. 3

SA-AA-117, Excavation, Trenching, and Shoring, Rev. 4b

SP-1302-12-261, Specification for Pipe Integrity Inspection Program, Rev. 7

SP-9000-06-004, Specification for Application and Repair of Service Level III Coatings, Rev. 0101.2, Oyster Creek Fire Protection Program, Rev. 54

CC-AA-211, Fire Protection Program, Rev. 1

645.6.003, Fire Hose Station, Hose House and Fire Hydrant Inspection, Rev. 17645.6.007, Fire Protection System Flush, Rev. 15

645.6.011, Deluge and Sprinkler System Inspection, Rev. 10

645.6.013, Fire Suppression System Halon Functional Test, Rev. 19

645.6.026, Fire Damper Inspection, Rev. 11

645.6.017, Fire Barrier Penetration Surveillance, Rev. 10ER-OC-330-1001, ISI Program Plan Fourth Ten-Year Inspection Interval (Draft)

OC-2, IGSCC Inspection Plan Fourth Ten-Year Inspection Interval, Rev. 1

ER-OC-330-1002, IGSCC Inspection Plan Fourth Ten-Year Inspection Interval (Draft)

ER-AA-330-002, In-service Inspection of Section XI Welds and Components, Rev. 5a

ER-AA-330-009, ASME Section XI Repair/Replacement Program, Rev. 4a

ER-AA-380, Rev. 3, "Primary Containment Leakage Rate Testing Program"

ER-OC-380, Rev. 0, "Oyster Creek Containment Leakage Rate Testing Program"

MA-AA-723-500, 50-Year Sample Testing of Fire Water System Sprinkler Heads, Rev. 0

(Draft)

New Oyster Creek PM Task defined in AR 00330592.20, Wall Thickness Measurements of FireWater Systems, March 2006 (Draft)

A-5AttachmentR0801533-Annual, Recurring work task for Fire Pond Screens & Rake Clean and Lubricate(System 176)Oyster Creek Generating Station Procedure No. 665.5.020, Rev. 19, "Integrated Local LeakRate Test Summary"Oyster Creek Generating Station Procedure No. 327.1, Rev. 31, "Fuel Oil Receipt and FuelHandling Procedure"Oyster Creek Generating Station Procedure No. 828.7, Rev. 22, "Secondary Systems Analysis:Plant Oil"ER-AA-430, Rev. 1, "Conduct of Flow Accelerated Flow Accelerated Corrosion Activities"

ER-AA-430-1001, Rev. 1, "Guidelines for Flow Accelerated Corrosion Activities"

CY-OC-120-110, Rev. 0, "Chemistry Limits and Frequencies"

CY-AA-120-400, Rev. 8, "Closed Cooling Water Chemistry"

CY-AB-120-1000, Rev. 2, "BWR Chemistry Optimization"

CY-AB-120-1100, Rev. 3, "Reactor Water Hydrogen Water Chemistry, Noble Chem and ZincInjection"CY-AB-120-320, Rev. 2, "Control Rod Drive Water Chemistry"

CY-AB-120-310, Rev. 2, "Suppression Pool/Torus Chemistry"

CY-AB-120-300, Rev. 5, "Spent Fuel Pool"

CY-AB-120-200, Rev. 4, "Storage Tanks Chemistry"

CY-AB-120-130, Rev. 4, "BWR Shutdown Chemistry"

CY-AB-120-120, Rev. 4, "BWR Startup Chemistry"

CY-AB-120-100, Rev. 8, "Condensate and Feedwater Chemistry"

CY-AB-120-100, Rev. 7, "Reactor Water Chemistry"

CY-OC-120-1107, Rev. 0, "Fuel Oil Sample and Analysis Schedule"

ECR OC 05-00275-00: Revise C-1302-187-E310-037, Revision 2

ER-AA-330-007

ER-AA-335-018

ER-AA-330, Revision 3: Conduct Of Inservice Inspection Activities

ER-AA-330-007, Revision 3: Visual Examination Of Section XI Class MC Surfaces And ClassCC LinersER-AA-330-018, Revision 2: General, VT-1, VT-1C, VT-3 And VT-3C, Visual Examination OfASME Class MC And CC Containment Surfaces And Components2400-GMM-3900.52, Revision 3: Inspection And Torquing Of Bolted Connections

SM-AA-300, Revision 0; Procurement Engineering Support Activities

WO R2064827-06, Disassemble Reactor Vessel For Refuel Outage, Prepare Areas & ApplyCavity Coating, 11/1/06WO R2068582-03, Perform Reactor Vessel Reassembly, Remove Cavity Coating And DeconCavity, 11/1/06Procedure No. 666.5.007, Revision 16; Primary Containment Integrated Leak Rate TestPM0001AC (RTWO R0800287) Control Room HVAC Sys B Inspection, Draft Revision

PM01279M (RTWO R0802279) Lubricate SGTS Fan EF-1-8, Draft Revision

ST 654.3.004 Control Room HVAC 'System A' Flow and Differential Pressure Test, DraftRevisionST 651.4.001 Standby Gas Treatment System Test, Draft Revision

PM Draft for AR00330592.40-Measure wall thickness for SGTS buried exhaust ducts/trains A &B, dated March 13, 2006ST 678.4.004 Station Blackout Combustion Turbine - Test, Rev. 7

A-6AttachmentAging Management Review Technical Basis DocumentsOC-AMR--2.3.3.17, Hardened Vent System, Rev. 0DocumentsOC-AMR-2.3.1.3, Rev. 0, Isolation Condenser SystemOC-AMR--2.3.3.15 Vol 1, AMR Technical Basis Document - Fire Protection System, March

2006OC-AMR--2.3.3.15 Vol 2, AMR Technical Basis Document - Fire Protection System, March

2006OCLR Tracking Item AMP-213 response, Fire Protection System B.1.19 Operating Experiencereview to support frequency of visual and functional testing of halon and CO2 Fire

Suppression Systems, dated January 24, 2006 OCLR Tracking Database Open Item 1571, "OC-AMR--2.3.3.15 Fire Protection TableIncomplete," dated February 01, 2006Interconnection Agreement (Partial) for the Oyster Creek Nuclear Generating Station betweenAmerGen Energy Company LLC and Jersey Central Power & Light Company d/b/a

GPU Energy - Schedule A: Interconnection Facilities, dated October 15, 1999Station Blackout Agreement Between GPU Energy and AmerGen Energy Company, L.L.C,dated April 14, 2000Closed Cycle Cooling Water Chemistry Assessment: Oyster Creek Nuclear Generating StationFinal ReportReport of NRC Information Requests Concerning Oyster Creek License Renewal Application,Topic: Closed Cycle Cooling WaterBWRVIP-130: BWR Vessel and Internals Project - BWR Water Chemistry Guidelines, 2004RevisionNFPA-25, Standard for the Inspection, Testing and Maintenance of Water-Based FireProtection Systems, 1998 EditionAM-2003-07, Corporate Engineering Oversight Self-Assessment Report, "Oyster Creek FlowAccelerated Corrosion Program," February 2003EPRI NSAC-202L-R2, "Recommendation for an Effective Flow-Accelerated CorrosionProgram," April 1999EPIR TR-109623, Rev. 2003, "Erosion, Corrosion, and Flow Accelerated Corrosion"

SP-1302-12-237, Rev. 11, "Nuclear Safety Related Pipe Wall Thinning Inspections for OysterCreek Nuclear Generating Station Erosion/Corrosion Program"TDR #943, Rev. 3, "Oyster Creek Flow Accelerated Corrosion Inspection History"

Focus Area Self-Assessment Report, "Reactor Water Chemistry Control," April 2004

NEI 03-08 "Guidelines for the Management of Materials Issue, May 2003

EPRI BWRVIP-62: BWR Vessel and Internal Project Technical Basis for Inspection Relief forTDR-1048, Technical Data Report-SGTS Duct Failure in the Tunnel, Rev. 0EPRI 1007933, Aging Assessment Field Guide, Dec 2003

BWR Internals Components with Hydrogen Injection (TR-108705) - Final Report, December

1998System 743, SBO Combustion Turbine and Support System OC-7 Functional FailureDefinition, dated April 24, 2002

A-7AttachmentASME Code Case -597Oyster Creek UFSAR, Section 6.2: Containment Systems

Video Tape #1; Bay 7, 0-62 Wall, 9/26/92; Bay 3, 701-739 Heavy Scale

Video Tape #2; Bay 11 & 17,Coating Video Exam, 8/9/96

Video Tape #3; Bay 3, 2/26 & 2/27/92

Video Tape #4; Core Bore Drill Drywell LinerVideo Tape #5; Bay 9, 2/20/92, 10:51 AM, No Drywell Wall

Video Tape #6; Bay 9, 2/18 & 2/19/92

Video Tape #7; Bay 9 & Bay 7, 2/21 & 2/24/92; Bay 7, 600-695, 705 Wall Condition; Bay 3,2/25/92 w. Arauera 721 Rota Router F804 TUD Guide Tube; Vacuuming from guide

tube Reban 45-56Video Tape #8; Bay 9, 2/13/92, No drywell wall

Video Tape #9; Bay 4, 2/28 & 3/2/92

Video Tape #10; 2/11/92 Inspection Bay 11, 2/13/92, Bay 11 Rota Router in Drain 11, Bay 70-62 Wall, 9/26/92Video Tape #11; Drywell Liner Sample Areas Plug #'s 1, 2, 3, 4, 5, 6,& 7, Bay 7System Manager Walkdowns of Service Water System, completed Sept. 24, 2005 & Dec. 1, 2005Operating Experience Review - Hardened Vent - System 822, Rev. 0

Topical Report 116, Oyster Creek Underground Piping Program Description and Status, Rev. 1

Topical Report 140, Emergency Service Water & Service Water System Piping Plan, Rev. 2

Technical Data Report 829, Pipe Integrity Inspection Program, Rev. 4

System & Structure Scoping Form - Torus Water Storage and Transfer System, Rev. 1

System & Structure Scoping Form - Source Range Monitoring, Rev. 0

Assessment of Structural Support at SR/NSR InterfacesIR & CR CR

AR 00330592.24.01 to .22AR 00441639

AR 002114568IR 469998IR 471363Program Basis DocumentsPBD-AMP-B.1.5, Rev. 0, BWR Feedwater NozzlePBD-AMP-B.1.7, Rev. 2, BWR Stress Corrosion Cracking

PBD-AMP-B.1.11, Rev. 0, Flow Accelerated Corrosion

PBD-AMP-B.1.14, Rev. 0, Closed Cycle Cooling Water Systems

PBD-AMP-B.1.19, Program Basis Document - Fire Protection System, March 2006

PBD-AMP-B.1.19, Program Proof Document - Fire Protection System, March 2006

PBD-AMP-B.1.20, Program Basis Document - Fire Water System, March 2006

PBD-AMP-B.1.20, Program Proof Document - Fire Water System, March 2006

A-8AttachmentPBD-AMP-B.1.29, Rev. 0, 10 CFR Part 50, Appendix JPBD-AMP-B.1.02, Rev. 0, Water Chemistry

PBD-AMP-B.2.5, Rev. 0, Periodic Inspection Program

PBD-AMP-B.2.5a, Rev. 0, Periodic Inspection Program-FRCT

PBD-AMP-B.22, Rev. 0, Fuel Oil Chemistry

PBD-AMP-B.2.04, Program Basis Document - Periodic Inspection of Ventilation Systems,Rev. 0Program Basis Document, PBD-AMP-B.1.27, Revision 0, ASME Section XI, Subsection IWE

Program Basis Document, PBD-AMP-B.1.33, Revision 0, Protective Coating Monitoring AndMaintenance ProgramProgram Basis Document, PBD-AMP-B.1.21, Aboveground Steel Tanks

PBD-AMP-B.1.12, Bolting Integrity, Rev. 0

PBD-AMP-B.1.13, Open Cycle Cooling Water System, Rev. 0

PBD-AMP-B.1.24, One-Time Inspection, Rev. 0

PBD-AMP-B.1.26, Buried Piping Inspection, Rev. 0System Health ReportsIn-service Inspection Program 1

st , 2 nd , 3 rd & 4 th Quarter 2005 ReportsOyster Creek Appendix J Program, 4

th Qtr 2005 System Health ReportFlow Accelerated Corrosion Program Controlling Document: ER-AA-430, 4

th Qtr. 2003 SystemHealth ReportFRCT Walkdown Report, dated October 17-19, 2005

System 743, CT-1 & CT-2 two year Maintenance Rule Performance data, dated March 2006Calculations13432.46-Z-012, Pipe Supports Design - Instrument Air and Nitrogen, Rev. 0C-1302-187-8610-030 "Statistical Analyses of Drywell Thickness Data thru September 1996"

C-1302-187-5300-028, Rev. 0, "Statistical Analyses of Drywell Thickness Data thru September

1994"C-1302-87-5300-021, Rev. 0, "Statistical Analyses of Drywell Thickness thru May 1992"

030681, Rev. 0, CHECWORK Flow Accelerated Corrosion Model, August 4, 2003

010663-02, Rev. 1, Flow Accelerated Corrosion Susceptible Non-Modeled Analysis, August 4, 2003Oyster Creek Nuclear Power Plant, Unit no. 1; Primary Containment Design Report

TDR 277, Revision 0; Oyster Creek Pressure Suppression Chamber Materials CoatingEvaluation, 7/10/85TDR 851, Revision 0; Assessment Of Oyster Creek Drywell Shell, 12/27/88

TDR 854, Revision 1; Drywell Sand Bed Region Corrosion Assessment, 4/22/87

TDR 948, Revision 1; Statistical Analysis Of Drywell Thickness Data, 2/1/89

TDR 922, Revision 1; 8/5/88, Drywell Upper Elevation - Wall Thinning

TDR 1080, Revision 0; Oyster Creek - Torus Internal Coating

TDR 948, Revision 1, 2/1/89; Statistical Analysis Of Drywell Thickness Data

TDR 854, Revision 1, 4/2/87; Drywell Sand Bed Region Corrosion Assessment

A-9AttachmentCalculation C-1302-187-5300-008, Revision 0, Statistical Analysis Of Drywell Thickness DataThru 2/8/90Calculation C-1302-187-5300-005, Revision 0,2/1/89; Statistical Analysis Of Drywell ThicknessData Thru 12/31/88Calculation C-1302-187-5300-011, Revision 1,6/13/90; Statistical Analysis Of DrywellThickness Data Thru 4/24/90Calculation C-1302-187-5300-017, Revision 0, Statistical Analysis Of Drywell Thickness DataThru May 1991Calculation C-1302-187-5300-021, Revision 0, Statistical Analysis Of Drywell Thickness DataThru May 1992Calculation C-1302-187-5300-015, Revision 0; Statistical Analysis Of Drywell Thickness DataThru March 1991Calculation C-1302-187-5300-016, Revision 0; OCDW Projected Thickness Using Data Thru

3/3/91Calculation C-1302-187-5300-022, Revision 0; OCDW Projected Thickness Using Data Thru

5/31/92Calculation C-1302-187-5300-025, Revision 0; Statistical Analysis Of Drywell Thickness DataThru December 1992Calculation C-1302-187-5300-025, Revision 1; Statistical Analysis Of Drywell Thickness DataThru December 1992Calculation C-1302-187-5300-028, Revision 0; Statistical Analysis Of Drywell Thickness DataThru September 1994Calculation C-1302-187-310-037, Revision 2; Statistical Analysis Of Drywell Vessel ThicknessData Thru September 2000Calculation C-1302-187-E310-037, Revision 1; Statistical Analysis Of Drywell Vessel ThicknessData Thru September 2000Calculation C-1302-241-E610-081, Revision 2; Suction Strainer Debris Generation andTransport, 10/5/98Calculation C-1302-187-5320-024, Revision 0; OC Drywell Ext. UT Evaluation in Sandbed, 4/16/93Document 990-2174, Letter Report On Additional Sandbed Analyses, GE Materials Monitoring& Structural Analysis Services, 12/11/92TDR 1108, Revision 0; Oyster Creek Drywell Vessel Corrosion Mitigation

CC-AA-309-1001, Revision 0, Oyster Creek Torus Corrosion Allowable Pit Depth; CalculationC-1302-187-E310-038Engineering Evaluation 82-74-9, Oyster Creek Torus Shell Thickness, 7/15/76

Engineering Evaluation 82-74-4, Oyster Creek Torus Shell Thickness, 3/4/76

Calculation C-1302-187-E310-038, Revision 0; Oyster Creek Torus Corrosion Allowable PitDepthCalculation C-1302-187-5360-006, Revision 0; O. C. Drywell - Projected Thickness Thru June1992, 1/27/89Calculation C-1302-187-8610-003, Revision 0; Statistical Analysis of Drywell Thickness Datathru September 1996ECR OC 05-00275-000, Revise C-1302-187-E310-037 Revision 1 To Revision 2

ER 84-006-00, Oyster Creek, Torus Corrosion Pitting and Missing Structural Welds

A-10AttachmentSpecificationsIsolation Condenser "B" Inspection and Re-coating, Rev. 0, 2/29/1996Specification 100579-000, 8/3/77; Specification For Coating The Exterior Of The Torus OysterCreek Nuclear Generating Station, Toms River, New JerseySpecification SP-1302-06-009, Revision 3, 7/25/91; Specification For Application And RepairOf Service Level I Coatings On Ferrous Metal Surfaces; Oyster Creek Nuclear

Generating Station, Toms River, New JerseyEPRI TR-109937, Guideline on Nuclear Safety-Related Coatings, April 1998

Specification IS-328227-005, Revision 12: Functional Requirements For Drywell ContainmentVessel Thickness ExaminationSpecification IS-402950-001; Functional Requirements For Augmented Drywell Inspection

Specification SP-1302-08-002, Revision 1; Inspection Of The Torus Coating, 2/17/83Specification SP-1302-52-094, Revision 1; Drywell Shell Coating Touch-Up

Specification SP-1302-52-120; Inspection And Localized Repair Of The Torus And VentSystem CoatingSpecification SP-1302-32-035, Revision 0; Inspection And Minor Repair Of Coating OnConcrete & Drywell Shell Surfaces In The Sandbed RegionSpecification 9000-06-003, Revision 4; Application And Repair Of Service Level II And BalanceOf Plant CoatingsSpecification #125-75-10, Torus Shell Welding Repair, 6/13/77

Specification OCIS 328001-001, Installation Specification For Torus Coating, Oyster CreekNuclear Generating Station Pressure Suppression Chamber, 6/28/83Specification SP-1302-52-120, Revision 2, 10/03/02; Specification For Inspection AndLocalized Repair Of The Torus And Vent System CoatingSafety EvaluationsSafety Evaluation SE-000243-002, Revision 14Safety Evaluation 000243-002, Revision 0: Drywell Shell Plate Thickness Reduction At TheBase Sand Cushion Entrenchment RegionSafety Evaluation 402950-005, Revision 3: Removal Of Sand From Drywell Sand Bed

Safety Evaluation 315403-019, Revision 1: Drywell Design Pressure Reduction - Tech SpecChangeSafety Evaluation 000243-002, Revision 14, 8/2/95: Drywell Steel Shell Plate ThicknessReductionSafety Evaluation 000187-004, Revision 0: Inspection/Repair Of Torus/Vent System Coating

Safety Evaluation 000187-001, Revision 1, 1/14/91: Evaluation Of Blistered Torus CoatingSP-1302-06-013, Post-Fire Safe Shutdown Program Requirements at Oyster Creek NuclearGenerating Station, Rev. 1Safety Evaluation, SE-000822-023, Safety Evaluation - Repair of SGTS Duct at the Stack,Rev. 0

A-11AttachmentNRC Documents

NRC Regulatory Guide 1.147NRC Ltr. C321-95-2235/5000-95; Oyster Creek Nuclear Generating Station (OCNGS) DocketNo. 50-219 Facility Operating License No. DPR-19, Drywell Corrosion MonitoringProgramNRC Information Notice 89-79: Degraded Coatings And Corrosion Of Steel ContainmentVesselsNRC Information Notice 89-79, Supplement 1: Degraded Coatings And Corrosion Of SteelContainment VesselsNRC Information Notice 97-10: Liner Plate Corrosion In Concrete Containments

NRC Generic Letter 98-04; Potential for Degradation of the Emergency Core Cooling Systemand the Containment Spray System After a Loss-Of-Cooling Accident Because of

Construction and Protective Coating Deficiencies and Foreign Material in Containment,

7/14/98NRC Ltr. Dated 1/5/87; Docket No. 50-219; December 10, 1986, Meeting With GPU NuclearCorporation (GPUN) To Discuss Corrosion Of The Outer Surface Of The Drywell ShellNRC Inspection Report No. 50-219/87-27NRC Ltr. Dated 10/16/90, Docket No. 50-219; Drywell Corrosion Program - Oyster CreekNuclear Generating StationNRC Inspection Report No. 50-219/90-21NRC Information Notice 86-99, Supplement 1: Degradation Of Steel ContainmentsNRC Ltr. Dated 11/1/95, Docket No. 50-219; Drywell Corrosion Program - Oyster CreekNuclear Generating StationNUREG-1522 Assessment of Inservice Conditions of Safety-Related Nuclear Plant Structures, 6/95NRC Ltr. Dated 12/29/86, Docket No. 50-219; Interim Operation For Cycle 12 FollowingCorrosion Of The Outer Surface Of The Drywell Shell (TAC 64016)NRC Ltr. Dated 9/22/87, Docket No. 50-219; Licensee Actions Taken And Action Plans ForMitigating The Corrosive Attack On The Drywell Sheel Of The Oyster Creek Nuclear

Generating Station (TAC 65448)NRC Ltr. Dated 9/13/93, Docket No. 50-219; Issuance Of License Amendment No. 165 -Change In Containment Drywell Design Pressure of 62 psig To New Design Pressure

of 44 psigNUREG-6706 Capacity of Steel and Concrete Containment Vessels With Corrosion Damage, 2/01NUREG-0661 Safety Evaluation Report Mark I Containment Long-Term Program, 7/80Licensee LettersAmerGen Ltr. 2130-05-20037, Oyster Creek Generating Station Refueling Outage 20 (1R20)Inservice Inspection (ISI) Summary ReportGPUN Ltr. 5000-86-1116, 12/18/86: Oyster Creek Nuclear Generating Station Docket No.50-219, Licensing No. DPR-16, Oyster Creek Drywell ContainmentGPUN Ltr. 5/12/87: Oyster Creek Nuclear Generating Station Docket No. Generic Letter 87-05GPUN Ltr. 5200-87-0061, 5/29/87: Oyster Creek Nuclear Generating Station Docket No.; NRCMeeting 6/11/87

A-12AttachmentGPUN Ltr. 5000-89-1717, 2/9/89: Oyster Creek Nuclear Generating Station Docket No,License No. DPR-16; Drywell ContainmentGPUN Ltr. 5000-90-1995, 12/5/90: Oyster Creek Nuclear Generating Station Docket No.50-219, License No. DPR-16, Oyster Creek Drywell ContainmentGPUN Ltr. 5000-95-2235, 9/15/95: Oyster Creek Nuclear Generating Station Docket No.50-219, License No. DPR-16, Drywell Corrosion Monitoring ProgramGPUN Ltr. 1940-99-20661, 12/17/99: Oyster Creek Nuclear Generating Station Docket No.50-219, ASME XI Relief RequestsJersey Central Power & Light Company Ltr. EA-76-686, 7/16/76: Oyster Creek NuclearGenerating Station Docket No. 50-219, Oyster Creek Torus Shell Thickness EvaluationGPUN Ltr. C321-93-2153, 5/25/93; Oyster Creek Nuclear Generating Statio Docket No. 50-219Reactor Containment Building Integrated Leak Rate TestGPU Nuclear SDBD-OC-243(MPR), Revision 11; Design Basis Document For ContainmentSystem Oyster Creek Nuclear Generating StationApplicant Response Letter for NRC RAI 2.5.1.19-1, dated October 12, 2005Applicant Supplemental Response Letter for NRC RAI 2.5.1.19-1, dated November 11, 2005Vendor DocumentsCondition Assessment of Cable Circuits at Exelon AmerGen Oyster Creek Nuclear PowerPlant, Dated 6/1/05Condition Assessment of Cable Circuits at Exelon AmerGen Oyster Creek Nuclear PowerPlant, Dated 8/4/04VM -OC-5001, Care and Operation of Isolation Condensers, Rev. 2

Oyster Creek Nuclear Power Plant Unit No. 1, Primary Containment Design Report, preparedby Ralph M. Parsons Company for GEFinal Inspection Report, Torus Coating Inspection and Repair and ECCS Suction StrainerReplacement; S.G. Pinney & AssociatesMPR-1322, Revision 0, Results of Painting Process Qualification Tests For the Drywell Exteriorin the Sand Bed Area at Oyster CreekGE Evaluation No. 87-178-003, Revision 1; Corrosion Evaluation Of The Oyster Creek Drywell, 3/6/87Final Report Summary Of Torus Decontamination Underwater Inspection And Coating Repair,12R Outage, MCF Job 9401; by S.G. Pinney & Associates, Inc., 4/21/89Final Report, Exelon/AmerGen, Oyster Creek Nuclear Generating Station, 1R19 RefuelingOutage, Torus Desludging, Torus Coating And Corrosion Inspection, Torus Coating

Repair; Underwater Construction Corporation, 12/2/2002Final Engineering Report, No. FER-7047, Revision 0; GPU Nuclear, Oyster Creek NuclearGenerating Station, 1R13 Coating And Corrosion Inspection Report, Torus ImmersionAnd Vent Header; Underwater Engineering Services, Inc., 7/29/91Final Engineering Report, Torus Coating Inspection And Repair and ECCS Suction StrainerReplacement, GPU Nuclear, Oyster Creek Nuclear Generating Station, by S.G. Pinney

& Associates, Inc., 12/22/98MPR Calculation 83-179-001, Revision 0; Oyster Creek Torus Shell Thickness Margin ForFatigue Loading

A-13AttachmentS. G. Pinney Report 990-2587, 12/16/96; Design Basis Accident (DBA) and Irradiation Testingof Coating Repair Materials for Use in Boiling Water Reactor Suppression ChamberImmersion AreasGE Technical Report TR-7377-1, Justification For Use Of Section III, Subsection NE, GuidanceIn Evaluating The Oyster Creek Drywell, November 1990DRF #00664, Index No. 9-1, Revision 0; An ASME Section III Evaluation Of Oyster CreekDrywell Part I Stress Analysis, November 1990DRF #00664, Index No. 9-2, Revision 0; An ASME Section III Evaluation Of Oyster CreekDrywell Part II Stability Analysis, November

1990DRF #00664, Index No. 9-3, Revision 0; An ASME Section III Evaluation Of Oyster CreekDrywell For Without Sand Case, Part I Stress Analysis, February 1991DRF #00664, Index N0. 9-4, Revision 2; An ASME Section III Evaluation Of Oyster CreekDrywell For Without Sand Case; Part 2 Stability Analysis, November

1992SGPAI Procedure QCP-10-2-OCNGS-7101, Revision 2, 11/30/92; Underwater Coating RepairWork OrdersC2012115C2003517

A/R # A2101209

C2009903, DTE Testing of Medium Voltage Cables, Dated 6/20/05

C2008036, DTE Testing of Medium Voltage Cables, Dated 6/30/05

R2046003, Radiation Monitor Functional Test, Dated 12/21/05

R2071072, High Radiation Monitor Calibration and Test, Dated 10/6/05

R2073609, NI Cable Test Data Review, Dated 9/1/05

R0807890, IRM/SRM Characterization Trending and Diagnostics, Dated 12/2/04

R0808284, Containment Spray Nozzle Verification, Dated 10/21/0200543366, Containment Spray Nozzle Test, Dated 11/9/00

00034392, Engineering Evaluation of Containment Spray Nozzle #6, Dated 1/4/93Corrective Action ProgramO2004-2340O2005-2249

O2003-0799

O2003-2454

O2003-2493

O2004-0990

O2004-2304

O2004-1542

O2002-1842

O2000-0309

O2001-0634

O2000-1531

O2000-1429

O2000-0401

O2000-0634O2005-1445O2005-0265

O2000-1772

O2004-3586

O2004-3437

O2000-1429

O2000-1355

O2002-1564

O2004-3442

O2005-1350

O2000-1578

O2000-1607

O2003-1903

O2003-0488

O2002-1280O2003-0318O2004-0200

O2005-1152

O2004-3745

O2004-3550

O2003-1865

O2003-2076

O2005-2249

O2003-0799

O2003-2454

O2003-2493

O2004-0990

O2004-2304

O2004-1542

O2002-1842O2000-0309O2001-0634

O2000-1531

O2000-1429

O2000-0401

O2000-0634

O2005-1445

O2005-0265

O2000-1772

O2004-3586

O2004-3437

O2000-1429

O2000-0609

O2004-2153

O2005-1772

A-14AttachmentO2003-1000O2004-0313

O2004-1644

O2003-1308

O2004-1314

O2002-1937

O2000-1788

A2097892 A2107513

A2073455 00472707*00472141*

00471363*

00469998*

00471867*

00472346

00470325

00472090

00472346

00470325

00472090

00461639

00348545**As a result of this inspectionWO R0806127-01WO R2027889-01

WO R2071967-06CAP O2003-2586, #2 Diesel-Driven Fire Pump Cooling Water Line pin-hole leaksCAP O2002-0916, Water leakage from base of Fire Hydrant #9

CAP O2005-2288, Debris in SGTS #1 Filter TrainAging Management ProgramsPBD-AMP-B.1.27, Revision 0, ASME Section XI, Subsection IWEPBD-AMP-B.1.33, Revision 0, Protective Coating Monitoring And Maintenance Program

PBD-AMP-B.1.21, Aboveground Steel Tanks

PBD-AMP-B.1.34, Electrical Cables and Connections not Subject to 10 CFR 50.49

Environmental Qualification Requirements, Rev 0

PBD-AMP-B.2.01, Periodic Testing of Containment Spray Nozzles, Rev 0

PBD-AMP-B.1.35, Electrical Cables and Connections not Subject to 10 CFR 50.49

Environmental Qualification Requirements used in Instrumentation Circuits, Rev 0

A-15AttachmentPBD-AMP-B.1.36, Inaccessible Medium-Voltage Cables not Subject to 10 CFR 50.49Environmental Qualification Requirements, Rev 0PBD-AMP-B.2.06, Wooden Utility Pole Program, Rev 0License Renewal Change RequestsLRCR 291LRCR 290

LRCR 289LIST OF ACRONYMSADAMSAgency-wide Documents Access and Management SystemASMEAmerican Society Mechanical Engineers

PARSPublicly Available Records

GALLGeneric Aging Lessons Learned Report